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Vulnerability mitigation is the solution for creating resilient distribution networks aims to prevent the uncontrollable outage propagation. This paper presents a new resilience index as a powerful tool to enhance the resilience of distribution systems against extreme hurricane events. The suggested framework provides a comparative study for optimal feeder routing problem and HV substation placement from the cost and resilience viewpoints. Once, the network is planned based on cost minimization, and then the proposed resilience index is calculated for the planned network. Finally, the network is planned based on resilience enhancement and afterward the planned network's cost is calculated. In case of resilient-based planning, the studied area is divided into small sites with different wind speed to evaluate the geospatial characteristics of hurricane and a fragility index is calculated for each distribution network component located at each sites. Both cost- and resilient- based networks are planned using deterministic and probabilistic approaches. In deterministic approach, network planning is done according to the worst prediction, the highest wind speed. But in probabilistic one, some scenarios with specified probability are defined for wind speed. Results show that, fragility index is high when considering worst prediction, so this less probable scenario needs higher investments. In this regards, scenario based planning, can lead to the best compromised solution considering cost and resilience which the obtained results validate the accuracy of the modellings and efficiency of the proposed method.
Masoumeh Karimi; Sajad Najafi Ravadanegh; Mahmoud-Reza Haghifam. A Study on Resilient and Cost-Based Design in Power Distribution Network against Severe Hurricane. International Journal of Critical Infrastructure Protection 2021, 100469 .
AMA StyleMasoumeh Karimi, Sajad Najafi Ravadanegh, Mahmoud-Reza Haghifam. A Study on Resilient and Cost-Based Design in Power Distribution Network against Severe Hurricane. International Journal of Critical Infrastructure Protection. 2021; ():100469.
Chicago/Turabian StyleMasoumeh Karimi; Sajad Najafi Ravadanegh; Mahmoud-Reza Haghifam. 2021. "A Study on Resilient and Cost-Based Design in Power Distribution Network against Severe Hurricane." International Journal of Critical Infrastructure Protection , no. : 100469.
An effective way to improve distribution system reliability is to place switches and protective equipment in the optimal location. Commonly, in the placement problem, the use of equipment in the designated location is assumed to be possible. But in practice, to establish protection coordination between the equipment, it is necessary to remove or relocate some of the equipment. This paper aims to increase distribution companies' profits and reduce customer interruption costs through a feasible solution. A new hybrid method for equipment placement has been proposed that simultaneously solves the protection coordination problem. While determining the optimal number and location of reclosers and sectionalizers, the proposed method ensures protection coordination between equipment (new and existing devices). Furthermore, to achieve a more realistic and accurate model, factors such as equipment malfunction, fault types (transient and permanent), and the relationship between these faults have been carefully considered to formulate the proposed method. In this method, to solve the optimization problems related to equipment placement and protection coordination, genetic algorithm, and linear programming in MATLAB software have been used, respectively. A real‐life distribution network has been utilized to evaluate the proposed method, and the results show the capability and robustness of this method.
Majid Safari; Mahmoud‐Reza Haghifam; Mansoureh Zangiabadi. A hybrid method for recloser and sectionalizer placement in distribution networks considering protection coordination, fault type and equipment malfunction. IET Generation, Transmission & Distribution 2021, 15, 2176 -2190.
AMA StyleMajid Safari, Mahmoud‐Reza Haghifam, Mansoureh Zangiabadi. A hybrid method for recloser and sectionalizer placement in distribution networks considering protection coordination, fault type and equipment malfunction. IET Generation, Transmission & Distribution. 2021; 15 (15):2176-2190.
Chicago/Turabian StyleMajid Safari; Mahmoud‐Reza Haghifam; Mansoureh Zangiabadi. 2021. "A hybrid method for recloser and sectionalizer placement in distribution networks considering protection coordination, fault type and equipment malfunction." IET Generation, Transmission & Distribution 15, no. 15: 2176-2190.
Reliability improvement is a fundamental issue in electric distribution network (EDN) operation. In this regard, providing the most efficient maintenance policy can dramatically assist the electric utility companies in reducing the failure rate of EDN components. In the present study, a novel probabilistic reliability‐centred maintenance (RCM) approach is proposed in which the reliability level of the EDN components are evaluated according to the three‐state Markov model (MM). Using the MM, this study presents a trade‐off between the corrective maintenance and the preventive maintenance (PM) actions and finally determines the precedence of EDN components in PM financial resource allocation. Through the method presented in this study, the financial resources of the PM are economically allocated with regards to economic parameters such as customer outage costs and budget constraints. The efficacy of the proposed RCM approach is evaluated through the implementation of the RCM approach on bus number four of the well‐known Roy Billinton test system.
Habib Allah Ravaghi Ardabili; Mahmoud‐Reza Haghifam; Seyyed Mostafa Abedi. A probabilistic reliability‐centred maintenance approach for electrical distribution networks. IET Generation, Transmission & Distribution 2020, 15, 1070 -1080.
AMA StyleHabib Allah Ravaghi Ardabili, Mahmoud‐Reza Haghifam, Seyyed Mostafa Abedi. A probabilistic reliability‐centred maintenance approach for electrical distribution networks. IET Generation, Transmission & Distribution. 2020; 15 (6):1070-1080.
Chicago/Turabian StyleHabib Allah Ravaghi Ardabili; Mahmoud‐Reza Haghifam; Seyyed Mostafa Abedi. 2020. "A probabilistic reliability‐centred maintenance approach for electrical distribution networks." IET Generation, Transmission & Distribution 15, no. 6: 1070-1080.
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.
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 StyleMojtaba 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 StyleMojtaba 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.
Resect severe economic losses caused by distribution system equipment outage have highlighted the importance of improving the system resiliency and reliability. In active distribution networks (ADNs), the distributed energy resources (DERs) managed by dynamic isolated microgrids in contingency mode provide an alternative approach to enhance the system resiliency and continue supplying critical loads after equipment outage. How to incorporate this ADNs capability into a short-term DERs scheduling is a challenging issue. In response to this challenge, in this paper, a two stage risk based decision making framework for operation of ADNs is proposed to coordinate 24-h DERs’ scheduling and outage management scheme, in a way to be immune against contingency by creating optimal dynamic multi-micrigrid, micro-turbine and energy storage island operating and load shed plan. The first stage is the normal operation condition that operation cost should be minimized considering of the uncertainties of renewable resources, the electricity price and customers loads. The second stage is the operation in contingency condition. In the second stage, the main objective is to keep the shed load at minimum level. Numerical results and sensitivity analysis from modified 33-bus IEEE network are further discussed to demonstrate the efficiency of the solution approach.
M. Zadsar; S.Sina. Sebtahmadi; M. Kazemi; S.M.M. Larimi; M.R. Haghifam. Two stage risk based decision making for operation of smart grid by optimal dynamic multi-microgrid. International Journal of Electrical Power & Energy Systems 2020, 118, 105791 .
AMA StyleM. Zadsar, S.Sina. Sebtahmadi, M. Kazemi, S.M.M. Larimi, M.R. Haghifam. Two stage risk based decision making for operation of smart grid by optimal dynamic multi-microgrid. International Journal of Electrical Power & Energy Systems. 2020; 118 ():105791.
Chicago/Turabian StyleM. Zadsar; S.Sina. Sebtahmadi; M. Kazemi; S.M.M. Larimi; M.R. Haghifam. 2020. "Two stage risk based decision making for operation of smart grid by optimal dynamic multi-microgrid." International Journal of Electrical Power & Energy Systems 118, no. : 105791.
Distribution networks are energy sectors that usually deal with residential energy consumers whose expectations associated with voltage quality and other relevant issues should be taken into account. There are various factors that might threaten reliable/economic performance of the distribution networks. In this paper, optimal reconfiguration of distribution systems is studied under a multi-objective optimization model to enhance reliability and minimize power losses of distribution networks. The developed multi-objective model is solved with epsilon-constrained (EPC) method and the trade-off conditions are achieved with min-max fuzzy satisfying (MMFF) technique. Demand response services (DRSs) including time-of-use (TOU) mechanism are proposed to make the energy consumers capable of revising their energy usage pattern. The proposed framework is investigated regarding the IEEE 33-bus test system in general algebraic modeling systems (GAMS) and the results validating the effectiveness of the proposed model are presented and compared. According to the obtained results, after reconfiguring the distribution system under the proposed model, loss of power in the system is reduced and reliability of a system associated with energy not supplied (ENS) index is improved. After proposing DRS and having the consumers motivated to change their consumption pattern, the obtained values for the mentioned targets are more suitable.
M.A. Tavakoli Ghazi Jahani; P. Nazarian; A. Safari; M.R. Haghifam. Multi-objective optimization model for optimal reconfiguration of distribution networks with demand response services. Sustainable Cities and Society 2019, 47, 101514 .
AMA StyleM.A. Tavakoli Ghazi Jahani, P. Nazarian, A. Safari, M.R. Haghifam. Multi-objective optimization model for optimal reconfiguration of distribution networks with demand response services. Sustainable Cities and Society. 2019; 47 ():101514.
Chicago/Turabian StyleM.A. Tavakoli Ghazi Jahani; P. Nazarian; A. Safari; M.R. Haghifam. 2019. "Multi-objective optimization model for optimal reconfiguration of distribution networks with demand response services." Sustainable Cities and Society 47, no. : 101514.
This paper presents a robust nonlinear integrated controller to improve stability of hybrid AC/DC micro-grids under islanding mode. The proposed controller includes two independent controllers where each one is responsible to control one part of the system. First controller will improve the stability of input DC/DC converter. Using this controller, the voltage of DC bus is fully stabilized such that when a large disturbance occurs, its voltage will become constant without any significant dynamic. The necessity of DC bus regulation which has not been considered in previous studies, is imminent as it not only improves voltage stability of the micro-grid but also protects consumers which are directly connected to the DC bus, against voltage variations. Frequency stability of the micro-grid is provided by the second proposed controller which is applied to output DC/AC converter of the micro-grid. Adaptive method is used to make the controllers proposed in this paper, robust. Duty cycle of converters switches are adjusted such that voltage and frequency of the micro-grid are set on the desired value in minimum possible time under transient disturbances and uncertainty of the loads as well as micro-sources characteristics.
Reza Pejmanfar; Mahmoud Reza Haghifam; Soodabeh Soleymani; Babak Tavassoli. Large Signal Stabilization of Hybrid AC/DC Micro-Grids Using Nonlinear Robust Controller. Energies 2017, 10, 1985 .
AMA StyleReza Pejmanfar, Mahmoud Reza Haghifam, Soodabeh Soleymani, Babak Tavassoli. Large Signal Stabilization of Hybrid AC/DC Micro-Grids Using Nonlinear Robust Controller. Energies. 2017; 10 (12):1985.
Chicago/Turabian StyleReza Pejmanfar; Mahmoud Reza Haghifam; Soodabeh Soleymani; Babak Tavassoli. 2017. "Large Signal Stabilization of Hybrid AC/DC Micro-Grids Using Nonlinear Robust Controller." Energies 10, no. 12: 1985.
The neoteric AC/DC distribution networks are becoming more practical and cost-effective for several reasons such as high penetration of DC distributed generations (DGs) and also ever-increasing growth of sensitive DC electronic loads. Using these networks eliminates some required conversion stages which result in reduced costs and better power quality and reliability. This paper evaluates the economic efficiency of hybrid AC/DC distribution systems compared with conventional AC ones. For this purpose, a conceptual methodology for AC/DC distribution system planning is developed for making a fair comparison between AC and AC/DC distribution systems costs. The proposed methodology determines the optimal AC/DC distribution substation location and size and AC/DC feeder routing, as well as length and capacity of AC/DC feeders in both low-voltage and medium-voltage sides. The cost function comprises of investment and operational costs, including costs of construction, reliability, and loss. The proposed AC/DC planning approach is implemented in a region with no pre-assigned distribution system in different cases, and results are compared in both AC and AC/DC planning scenarios. Numerical results reveal that using hybrid AC/DC distribution systems in comparison with commonly used AC ones can lead to reduced total costs in the presence of sensitive loads and also high penetration of DGs.
Ali Ghadiri; Mahmoud R. Haghifam; Sayyed Majid Miri Larimi. Comprehensive approach for hybrid AC/DC distribution network planning using genetic algorithm. IET Generation, Transmission & Distribution 2017, 11, 3892 -3902.
AMA StyleAli Ghadiri, Mahmoud R. Haghifam, Sayyed Majid Miri Larimi. Comprehensive approach for hybrid AC/DC distribution network planning using genetic algorithm. IET Generation, Transmission & Distribution. 2017; 11 (16):3892-3902.
Chicago/Turabian StyleAli Ghadiri; Mahmoud R. Haghifam; Sayyed Majid Miri Larimi. 2017. "Comprehensive approach for hybrid AC/DC distribution network planning using genetic algorithm." IET Generation, Transmission & Distribution 11, no. 16: 3892-3902.
Amin Mohsenzadeh; Samaneh Pazouki; Shahab Ardalan; Mahmoud-Reza Haghifam. Optimal placing and sizing of parking lots including different levels of charging stations in electric distribution networks. International Journal of Ambient Energy 2017, 39, 743 -750.
AMA StyleAmin Mohsenzadeh, Samaneh Pazouki, Shahab Ardalan, Mahmoud-Reza Haghifam. Optimal placing and sizing of parking lots including different levels of charging stations in electric distribution networks. International Journal of Ambient Energy. 2017; 39 (7):743-750.
Chicago/Turabian StyleAmin Mohsenzadeh; Samaneh Pazouki; Shahab Ardalan; Mahmoud-Reza Haghifam. 2017. "Optimal placing and sizing of parking lots including different levels of charging stations in electric distribution networks." International Journal of Ambient Energy 39, no. 7: 743-750.
Undesired trip operation of zone 3 units of distance relays in power transmission network, during static and dynamic load encroachment can lead to cascading failures and even catastrophic power system blackouts. Stressed conditions such as power flow redistribution and power swing can cause maloperation of the third zone of distance relays. Fast and dependable detection of the symmetrical faults, occurring during these conditions poses an additional challenge. One of the effective methods to avoid the zone 3 contribution in cascading failure propagation is the detection and monitoring of vulnerable relays which are exposed to maloperation in power system stressed conditions. In this study, a new relay ranking index is proposed for real-time identifying the zone 3 of distance relays, most vulnerable to incorrect operation due to load encroachment. A novel synchrophasor data-based monitoring index is also presented for supervision of critical distance relays operation. This index is extracted based on positive-sequence fault component phasors of the current and voltage signals obtained by modern PMUs or GPS based digital relays which have been reconfigured for this application. The proposed monitoring scheme is able to quickly distinguish the fault from load encroachment condition. The performance of the proposed supervisory scheme is evaluated and approved on a nine-bus WSCC system.
Tohid Ghanizadeh Bolandi; Mahmoud Reza Haghifam; Mojtaba Khederzadeh. Real‐time monitoring of zone 3 vulnerable distance relays to prevent maloperation under load encroachment condition. IET Generation, Transmission & Distribution 2017, 11, 1878 -1888.
AMA StyleTohid Ghanizadeh Bolandi, Mahmoud Reza Haghifam, Mojtaba Khederzadeh. Real‐time monitoring of zone 3 vulnerable distance relays to prevent maloperation under load encroachment condition. IET Generation, Transmission & Distribution. 2017; 11 (8):1878-1888.
Chicago/Turabian StyleTohid Ghanizadeh Bolandi; Mahmoud Reza Haghifam; Mojtaba Khederzadeh. 2017. "Real‐time monitoring of zone 3 vulnerable distance relays to prevent maloperation under load encroachment condition." IET Generation, Transmission & Distribution 11, no. 8: 1878-1888.
Development of renewable energies and DC loads have led microgrids toward the creation of DC networks. The predictions show that the hybrid microgrids will be used widely in the future. This article has studied the voltage stability in the presence of sources of energy storage in AC/DC hybrid networks. However, because the different dynamics of hybrid networks applying centralized and distributed controllers will be faced with different problems, in this study, a multi-agent control for the microgrid has been used. A new structure referred to here as an event-driven microgrid control management (EDMCM) has been developed to control the microgrid. This method increases response speed and accuracy of decision making. Hybrid Network Simulation results confirm the validity of the developed model.
Ahmadali Khatibzadeh; Mohammadreza Besmi; Aminollah Mahabadi; Mahmoud Reza Haghifam. Multi-Agent-Based Controller for Voltage Enhancement in AC/DC Hybrid Microgrid Using Energy Storages. Energies 2017, 10, 169 .
AMA StyleAhmadali Khatibzadeh, Mohammadreza Besmi, Aminollah Mahabadi, Mahmoud Reza Haghifam. Multi-Agent-Based Controller for Voltage Enhancement in AC/DC Hybrid Microgrid Using Energy Storages. Energies. 2017; 10 (2):169.
Chicago/Turabian StyleAhmadali Khatibzadeh; Mohammadreza Besmi; Aminollah Mahabadi; Mahmoud Reza Haghifam. 2017. "Multi-Agent-Based Controller for Voltage Enhancement in AC/DC Hybrid Microgrid Using Energy Storages." Energies 10, no. 2: 169.
This study suggests a method based on stochastic multi-objective modelling for optimally timing, siting and sizing of sub-transmission substationsand medium voltage feeders, distributed generations and capacitors, simultaneously, in order to take more pros of recent developed technologies. Regards to comprehensive impact of uncertainties including: intermittent nature of renewable energy sources, load forecasting and market price errors, some strategies must be devised in order to well incorporate them into the problem. The mentioned problem is modelled by dynamic programming which NSGA-2 is chosen for optimisation purposes and then fuzzy set theory is applied to find the best compromise solution. The proposed scheme aims to minimise substations expansion and installation cost, medium voltage feeders installation and replacement cost, DG units installation and operation cost, capacitors installation cost, cost of purchased energy from the transmission network, active and reactive power losses cost, and connection cost of sub-transmission substations to the upstream network. Besides, risk based modelling of energy not-supplied as an efficient reliability index is incorporated to cost function in order to improve the reliability of the network. Also voltage deviation and voltage stability as the criterion of power quality in distribution networks and emission reduction are treated as independent objective functions.
Masoumeh Karimi; Mahmoud Reza Haghifam. Risk based multi‐objective dynamic expansion planning of sub‐transmission network in order to have eco‐reliability, environmental friendly network with higher power quality. IET Generation, Transmission & Distribution 2017, 11, 261 -271.
AMA StyleMasoumeh Karimi, Mahmoud Reza Haghifam. Risk based multi‐objective dynamic expansion planning of sub‐transmission network in order to have eco‐reliability, environmental friendly network with higher power quality. IET Generation, Transmission & Distribution. 2017; 11 (1):261-271.
Chicago/Turabian StyleMasoumeh Karimi; Mahmoud Reza Haghifam. 2017. "Risk based multi‐objective dynamic expansion planning of sub‐transmission network in order to have eco‐reliability, environmental friendly network with higher power quality." IET Generation, Transmission & Distribution 11, no. 1: 261-271.
Highlights•We propose a risk-based method for placement of transformers in LV networks.•Three different risk strategies are investigated in the planning problem.•Monetary models are introduced for both of economic and technical risks.•The effect of the overload on the transformer's loss of life is modeled. AbstractIn this paper, a new risk-based planning method is proposed which pays more attention to low-probability and high consequences events in LV distribution network. The proposed approach is implemented for planning of LV distribution networks and for optimally determining the size, number, and placement of distribution transformers. In the proposed approach, three different risk strategies are defined for distribution system operator (DSO). They are named risk-seeker, risk-neutral, and risk-averse. While the probabilistic behavior of parameters is not considered by the first one, a risk-neutral DSO considers it and makes decisions based on the expected cost. The risk-averse DSO makes, instead, decision based on the worst possible case. An uncertainty model of the system's variables is based on discrete states, called scenarios. The cost of Distribution System Planning consists of investment cost, maintenance cost, power losses cost, and reliability cost. A transformer overload penalty function is also defined to consider the effect of possible transformers’ overloads during their life time. The proposed approach, applied to a test system consisting of 42 electric load points, can properly reduce the cost of extreme event and therefore, DSO has less concern about these possible situations.
Mostafa Esmaeeli; Ahad Kazemi; Heidarali Shayanfar; Mahmoud-Reza Haghifam; Pierluigi Siano. Risk-based planning of distribution substation considering technical and economic uncertainties. Electric Power Systems Research 2016, 135, 18 -26.
AMA StyleMostafa Esmaeeli, Ahad Kazemi, Heidarali Shayanfar, Mahmoud-Reza Haghifam, Pierluigi Siano. Risk-based planning of distribution substation considering technical and economic uncertainties. Electric Power Systems Research. 2016; 135 ():18-26.
Chicago/Turabian StyleMostafa Esmaeeli; Ahad Kazemi; Heidarali Shayanfar; Mahmoud-Reza Haghifam; Pierluigi Siano. 2016. "Risk-based planning of distribution substation considering technical and economic uncertainties." Electric Power Systems Research 135, no. : 18-26.
This study addresses the adequacy of a generating system considering the impact of operation strategies of storages and hydro energy resources. It is assumed that the installed storage capacity of a system can be assigned for two purposes: first, economical operation which adopts storage to shift electric energy and smooth the load curve; and the second, reliability-based operation, which deploys storage to avoid load curtailments. The economical operation strategy is represented by starting from time domain data and using the load curve modification method to synthesise the overall impact of storage. The reliability-based operation is modelled with a new method based on Markov chain model that considers the dynamic behaviour of storage during time. Moreover, a novel state reduction method is presented for decreasing the number of Markov states in applications to large systems. The effectiveness of the presented methods is evaluated by running several simulation scenarios with results presented on three test systems. The results demonstrate that evaluating the system reliability in the presence of energy storage by considering the frequency and duration of system states is more effective than using methods based on the Capacity Outage Probability Table (COPT).
Mohammad‐Hossein Shariatkhah; Mahmoud‐Reza Haghifam; Gianfranco Chicco; Mohsen Parsa‐Moghaddam. Modelling the operation strategies of storages and hydro resources in adequacy analysis of power systems in presence of wind farms. IET Renewable Power Generation 2016, 10, 1059 -1068.
AMA StyleMohammad‐Hossein Shariatkhah, Mahmoud‐Reza Haghifam, Gianfranco Chicco, Mohsen Parsa‐Moghaddam. Modelling the operation strategies of storages and hydro resources in adequacy analysis of power systems in presence of wind farms. IET Renewable Power Generation. 2016; 10 (8):1059-1068.
Chicago/Turabian StyleMohammad‐Hossein Shariatkhah; Mahmoud‐Reza Haghifam; Gianfranco Chicco; Mohsen Parsa‐Moghaddam. 2016. "Modelling the operation strategies of storages and hydro resources in adequacy analysis of power systems in presence of wind farms." IET Renewable Power Generation 10, no. 8: 1059-1068.
One of the most significant tasks for loss reduction and reliability improvement in active distribution networks is feeder reconfiguration. Uncertainty associated with load, generation and reliability parameters in active distribution network requires distribution system operators (DSOs) to consider risk management in distribution network reconfiguration. On the other hand, by employing several forms of reward/penalty schemes in active distribution networks, DSOs have been exposed to financial risk for providing reliable service to the customers. In such circumstance, DSOs can do network reconfiguration in a way that the minimum cost can be spent in the minimum risk. This study presents risk-based reconfiguration of electric distribution networks in presence of reward/penalty scheme with considering load and generation uncertainty. Scenario theory and particle swarm optimisation are used for risk modelling and optimisation problem solving, respectively. To verify the proposed method, it was implemented in a real distribution network.
Sayyed Majid Miri Larimi; Mahmoud Reza Haghifam; Amin Moradkhani. Risk‐based reconfiguration of active electric distribution networks. IET Generation, Transmission & Distribution 2016, 10, 1006 -1015.
AMA StyleSayyed Majid Miri Larimi, Mahmoud Reza Haghifam, Amin Moradkhani. Risk‐based reconfiguration of active electric distribution networks. IET Generation, Transmission & Distribution. 2016; 10 (4):1006-1015.
Chicago/Turabian StyleSayyed Majid Miri Larimi; Mahmoud Reza Haghifam; Amin Moradkhani. 2016. "Risk‐based reconfiguration of active electric distribution networks." IET Generation, Transmission & Distribution 10, no. 4: 1006-1015.
With widespread installation of distribution generations (DG) mainly in distribution networks, a fairly incentive scheme is required to better meet the investment and innovation challenge and to drive the innovation needed to deliver a sustainable energy network with value for money to existing and future consumers. This study proposes a new method to determine DG energy price based on its impact on active loss reduction. This method calculates the actual value of each DG in the active loss reduction and according to this value, determines DG energy price, which is named value based pricing. The proposed approach is applied to a market model with two different agents, namely considered as the distribution company (DisCo) and the owner of DG. In this model, the DisCo is considered as the sole owner and operator of a distribution network and can purchase energy from the wholesale electricity market and/or from DG units owned by independent producers. To illustrate the advantages of the proposed method compared with the local marginal pricing(, both methods are implemented in 33-bus distribution network.
Seyyed Majid Miri Larimi; Mahmoud Reza Haghifam; Mansoureh Zangiabadi; Philip Taylor. Value based pricing of distribution generations active power in distribution networks. IET Generation, Transmission & Distribution 2015, 9, 2117 -2125.
AMA StyleSeyyed Majid Miri Larimi, Mahmoud Reza Haghifam, Mansoureh Zangiabadi, Philip Taylor. Value based pricing of distribution generations active power in distribution networks. IET Generation, Transmission & Distribution. 2015; 9 (15):2117-2125.
Chicago/Turabian StyleSeyyed Majid Miri Larimi; Mahmoud Reza Haghifam; Mansoureh Zangiabadi; Philip Taylor. 2015. "Value based pricing of distribution generations active power in distribution networks." IET Generation, Transmission & Distribution 9, no. 15: 2117-2125.
The growing demand for plug-in electric vehicles (PEVs) in the world has driven researchers to pay extra attention to charging stations (CSs) in order to meet supplying needs. Lower emission, convenient charging experience, high performance, and energy security are considered as the significant benefits of the mentioned technology. Despite the aforementioned advantages, inappropriate place and size of CSs have brought new challenges for electric distribution systems. Prominent features of distributed generations (DGs) make this technology appropriate for compensating relevant problems of CSs installation. In this paper, simultaneous optimal planning (placing and sizing) of CSs and DGs is presented to address new challenges. In addition, financial (investment costs), technical (system reliability, power loss, and voltage profile), and environmental (CO2 emission) issues are considered in the proposed objective function. A genetic algorithm is used to solve the optimization problem. Furthermore, the simulation study is carried out on a 33-bus radial distribution network. The simulation results show the effects of installation of CSs in the presence/absence of DGs on total costs, reliability, loss, voltage profile, and emission. Moreover, the effects of increasing PEV's availability are evaluated on the aforementioned terms in the electric distribution network.
Samaneh Pazouki; Amin Mohsenzadeh; Shahab Ardalan; Mahmoud-Reza Haghifam. Simultaneous Planning of PEV Charging Stations and DGs Considering Financial, Technical,and Environmental Effects. Canadian Journal of Electrical and Computer Engineering 2015, 38, 238 -245.
AMA StyleSamaneh Pazouki, Amin Mohsenzadeh, Shahab Ardalan, Mahmoud-Reza Haghifam. Simultaneous Planning of PEV Charging Stations and DGs Considering Financial, Technical,and Environmental Effects. Canadian Journal of Electrical and Computer Engineering. 2015; 38 (3):238-245.
Chicago/Turabian StyleSamaneh Pazouki; Amin Mohsenzadeh; Shahab Ardalan; Mahmoud-Reza Haghifam. 2015. "Simultaneous Planning of PEV Charging Stations and DGs Considering Financial, Technical,and Environmental Effects." Canadian Journal of Electrical and Computer Engineering 38, no. 3: 238-245.
In recent decades, many researches have been focused on the distribution planning, mostly on the medium voltage (MV) level. However, a considerable part of distribution system losses is pertained to low voltage (LV) networks, and the costs of MV networks are comparable with those of LV networks. Therefore, it is necessary to study this subject. In this paper, a new method is presented to determine the optimal placement of distribution transformers. This method determines the optimal location, size, and number of these transformers. A transformer loading above the nameplate rating is allowed without any influence on the relative thermal aging rate. This is carried out during peak hours to benefit from low load currents during off‐peak hours. The proposed approach is applied to a test system consisting of 42 electric load points. It is observed that the proposed planning approach considerably reduces the total cost of the distribution transformer placement as well as the costs of the associated capital and losses. Copyright © 2014 John Wiley & Sons, Ltd.
Mostafa Esmaeeli; Ahad Kazemi; Heydar-Ali Shayanfar; Mahmood-Reza Haghifam. Sizing and placement of distribution substations considering optimal loading of transformers. International Transactions on Electrical Energy Systems 2014, 25, 2897 -2908.
AMA StyleMostafa Esmaeeli, Ahad Kazemi, Heydar-Ali Shayanfar, Mahmood-Reza Haghifam. Sizing and placement of distribution substations considering optimal loading of transformers. International Transactions on Electrical Energy Systems. 2014; 25 (11):2897-2908.
Chicago/Turabian StyleMostafa Esmaeeli; Ahad Kazemi; Heydar-Ali Shayanfar; Mahmood-Reza Haghifam. 2014. "Sizing and placement of distribution substations considering optimal loading of transformers." International Transactions on Electrical Energy Systems 25, no. 11: 2897-2908.
The electric distribution overhead lines are large-scale complex repairable systems that consist of numerous components. To obtain an acceptable level of reliability in overhead lines, an asset management strategy seems to be necessary. An asset management-based maintenance framework is introduced for overhead lines. Based on the proposed framework, a relevant failure rate model is developed, which is able to show the effect of preventive maintenance according to expending cost and other affecting factors. The application procedure of the proposed model is also discussed in overhead line maintenance planning. Five-year historical data of nine feeders are used to assess the proposed maintenance schedule in comparison to utility predefined one.
Amin Moradkhani; Mahmood R. Haghifam; Mohsen Mohammadzadeh. Failure rate modelling of electric distribution overhead lines considering preventive maintenance. IET Generation, Transmission & Distribution 2014, 8, 1028 -1038.
AMA StyleAmin Moradkhani, Mahmood R. Haghifam, Mohsen Mohammadzadeh. Failure rate modelling of electric distribution overhead lines considering preventive maintenance. IET Generation, Transmission & Distribution. 2014; 8 (6):1028-1038.
Chicago/Turabian StyleAmin Moradkhani; Mahmood R. Haghifam; Mohsen Mohammadzadeh. 2014. "Failure rate modelling of electric distribution overhead lines considering preventive maintenance." IET Generation, Transmission & Distribution 8, no. 6: 1028-1038.
Amin Moradkhani; Mahmood R. Haghifam; Mohsen Mohammadzadeh. Failure rate estimation of overhead electric distribution lines considering data deficiency and population variability. International Transactions on Electrical Energy Systems 2014, 25, 1452 -1465.
AMA StyleAmin Moradkhani, Mahmood R. Haghifam, Mohsen Mohammadzadeh. Failure rate estimation of overhead electric distribution lines considering data deficiency and population variability. International Transactions on Electrical Energy Systems. 2014; 25 (8):1452-1465.
Chicago/Turabian StyleAmin Moradkhani; Mahmood R. Haghifam; Mohsen Mohammadzadeh. 2014. "Failure rate estimation of overhead electric distribution lines considering data deficiency and population variability." International Transactions on Electrical Energy Systems 25, no. 8: 1452-1465.