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The active role of distribution system operators (DSOs) coordinated with the transmission system operator (TSO) is highlighted by increasing the competition of new parties in energy markets. Besides, combined heat and power (CHP) units are the primary heat supplier in district heating systems, and their electricity production is strongly coupled with heat productions. This paper evaluates an integrated model for scheduling electricity and heat with considering TSO–DSO cooperation to increase the operating efficiency in the day-ahead horizon. Also, this paper considers the cooperation of the electrical TSO, electrical DSOs, and district heating systems’ operators. The proposed model facilitates energy transactions between systems by considering intermediary variables. The share of each market party is calculated using intermediary variables and locational marginal prices of electrical and heating systems, and the values are compared to the cases with the isolated operating of energy systems. Also, the model considers thermal energy storage systems (TESs) and the heat transaction capability between neighbor systems, and the feasible convex region is used for the operation of CHP units. The DC power flow equations are used at the transmission level, while the AC power flow is used for distribution grids. The AC power flow equations are relaxed into the second-order cone programming (SOCP) formulation, which results in a mixed-integer second-order cone programming (MISOCP) problem. The proposed model is applied to the modified IEEE 24-bus test system, which contains electrical and heating systems at the distribution level. The result shows that the proposed model successfully reduces the operational costs and energy prices compared to the isolated scheduling of energy systems. Also, the model facilitates energy trading between market parties.
Mahdi Habibi; Vahid Vahidinasab; Mohammad Sadegh Sepasian. Value of integrated electricity and heat scheduling with considering TSO–DSO cooperation. International Journal of Electrical Power & Energy Systems 2021, 135, 107526 .
AMA StyleMahdi Habibi, Vahid Vahidinasab, Mohammad Sadegh Sepasian. Value of integrated electricity and heat scheduling with considering TSO–DSO cooperation. International Journal of Electrical Power & Energy Systems. 2021; 135 ():107526.
Chicago/Turabian StyleMahdi Habibi; Vahid Vahidinasab; Mohammad Sadegh Sepasian. 2021. "Value of integrated electricity and heat scheduling with considering TSO–DSO cooperation." International Journal of Electrical Power & Energy Systems 135, no. : 107526.
While a lot of countries put renewable energy sources at the heart of their decarbonization strategies with directed incentive mechanisms, the variability of the renewable energy sources, remains a major challenge for electricity system operators in ensuring the security of supply. This challenge is particularly onerous when there is a coincidence between this variability and congestion of the tie-lines. Renewable generation spillage often leads to constraints being placed on the output of renewable energy sources. This situation causes a significant cost for electricity system operators due to the need for constraint payments to be made to renewable generations. These increased costs will ultimately be recovered from energy customers. Maintaining the balance in the aforementioned decarbonization, security of supply and affordability is a challenge that constitutes the energy trilemma. The integration of electric power systems with other energy infrastructures, e.g., natural gas, could be a promising solution for achieving a balanced performance in the energy trilemma, controlling the fluctuation of renewable energy sources, and increasing the flexibility of the integrated systems. Considering this, a hybrid bridging-operational framework based on the vector-bridging system concept is proposed. Also, a day-ahead integrated scheduling model is proposed that optimizes the integrated operation by considering the constraint payment costs in a linear optimization model. Simulation results on a large test system indicated that the hybrid bridging-operational framework could reduce the total cost of the congested system by 65% and release up to 10% of the pipeline capacities while harvesting the wind generation and removing constraint payments to wind generators.
Vahid Vahidinasab; Mahdi Habibi; Behnam Mohammadi-Ivatloo; Phil Taylor. Value of regional constraint management services of vector-bridging systems in a heavily constrained network. Applied Energy 2021, 301, 117421 .
AMA StyleVahid Vahidinasab, Mahdi Habibi, Behnam Mohammadi-Ivatloo, Phil Taylor. Value of regional constraint management services of vector-bridging systems in a heavily constrained network. Applied Energy. 2021; 301 ():117421.
Chicago/Turabian StyleVahid Vahidinasab; Mahdi Habibi; Behnam Mohammadi-Ivatloo; Phil Taylor. 2021. "Value of regional constraint management services of vector-bridging systems in a heavily constrained network." Applied Energy 301, no. : 117421.
The electric power system is one of the most important critical infrastructures of a country. Recently, the number of natural and man-made disasters is increased, which can impose extensive damages and costs to the power system. A resilient power system can withstand against, adapt to and recover from these disasters. Power system resilience is quantified by mathematical tools which are called “resilience metrics”. Currently, a lot of resilience metrics are proposed in the power system literature. In this paper, based on the extensive research in the critical infrastructure resilience literature which specifically concentrates on the “area-based” resilience metrics, a new area-based resilience metric is proposed which can measure the power system resilience considering the government policymaker criteria, which are rarely noticed before. The proposed and conventional area-based resilience metrics are evaluated based on the real data from the 2012 Superstorm Sandy in the USA, which led to significant damage to the power distribution system. The simulation results show that the proposed area-based resilience metric is very simple, can successfully address actual power system performance curves and is more meaningful and tangible than the conventional area-based metrics for the government policymaker. The proposed area-based resilience metric has also a general form and can be used for other critical infrastructures.
Habibollah Raoufi; Vahid Vahidinasab. Power system resilience assessment considering critical infrastructure resilience approaches and government policymaker criteria. IET Generation, Transmission & Distribution 2021, 1 .
AMA StyleHabibollah Raoufi, Vahid Vahidinasab. Power system resilience assessment considering critical infrastructure resilience approaches and government policymaker criteria. IET Generation, Transmission & Distribution. 2021; ():1.
Chicago/Turabian StyleHabibollah Raoufi; Vahid Vahidinasab. 2021. "Power system resilience assessment considering critical infrastructure resilience approaches and government policymaker criteria." IET Generation, Transmission & Distribution , no. : 1.
Global electric vehicles (EVs) fleet is expanding at a rapid pace. Considering the uncertain driving pattern of EVs, they are dynamic consumers of electricity and their integration can give rise to operational problems and jeopardize the security of the power system. Under such circumstances, the implementation of demand-side response (DSR) programs is more likely to be an effective solution for reducing the risks of load curtailment or security problems. This study proposes a voltage stability constrained DSR-coordinated planning model for increasing the penetration level of EVs in a distribution system consisting of photovoltaics (PVs), wind turbines (WTs) and responsive loads. The uncertainties of PV/WT generation, the driving pattern of EVs, and load demand are modeled by an improved form of information gap decision theory (IGDT), hereafter called weighted IGDT (WIGDT). Due to the fact that the proposed model is nonlinear and non-convex, a linearization technique is adopted and the proposed model is formulated as a mixed-integer linear programming (MILP), solved using the general algebraic modeling system (GAMS) software. The standard 33-bus distribution test system and a real-world smart distribution network, based in the Isle of Wight in the UK, are used to evaluate the performance of the model.
Vahid Vahidinasab; Saman Nikkhah; Adib Allahham; Damian Giaouris. Boosting integration capacity of electric vehicles: A robust security constrained decision making. International Journal of Electrical Power & Energy Systems 2021, 133, 107229 .
AMA StyleVahid Vahidinasab, Saman Nikkhah, Adib Allahham, Damian Giaouris. Boosting integration capacity of electric vehicles: A robust security constrained decision making. International Journal of Electrical Power & Energy Systems. 2021; 133 ():107229.
Chicago/Turabian StyleVahid Vahidinasab; Saman Nikkhah; Adib Allahham; Damian Giaouris. 2021. "Boosting integration capacity of electric vehicles: A robust security constrained decision making." International Journal of Electrical Power & Energy Systems 133, no. : 107229.
Vahid Vahidinasab; Charalampos (Haris) Patsios; Damian Giaouris; Phil Taylor. Guest Editorial: On the role of energy storage systems in the grid of the future: Selected papers from the 2019 UK Energy Storage Conference. IET Smart Grid 2021, 4, 135 -138.
AMA StyleVahid Vahidinasab, Charalampos (Haris) Patsios, Damian Giaouris, Phil Taylor. Guest Editorial: On the role of energy storage systems in the grid of the future: Selected papers from the 2019 UK Energy Storage Conference. IET Smart Grid. 2021; 4 (2):135-138.
Chicago/Turabian StyleVahid Vahidinasab; Charalampos (Haris) Patsios; Damian Giaouris; Phil Taylor. 2021. "Guest Editorial: On the role of energy storage systems in the grid of the future: Selected papers from the 2019 UK Energy Storage Conference." IET Smart Grid 4, no. 2: 135-138.
The way the world gets its energy is undergoing a rapid transition, driven by both the increased urgency of decarbonizing energy systems and the plummeting costs of renewable energy technologies
Amjad Anvari-Moghaddam; Vahid Vahidinasab; Behnam Mohammadi-Ivatloo; Reza Razzaghi; Fazel Mohammadi. Emerging Technologies for the Energy Systems of the Future. Inventions 2021, 6, 23 .
AMA StyleAmjad Anvari-Moghaddam, Vahid Vahidinasab, Behnam Mohammadi-Ivatloo, Reza Razzaghi, Fazel Mohammadi. Emerging Technologies for the Energy Systems of the Future. Inventions. 2021; 6 (2):23.
Chicago/Turabian StyleAmjad Anvari-Moghaddam; Vahid Vahidinasab; Behnam Mohammadi-Ivatloo; Reza Razzaghi; Fazel Mohammadi. 2021. "Emerging Technologies for the Energy Systems of the Future." Inventions 6, no. 2: 23.
Energy management system (EMS) has a vital role in the operation of a microgrid (MG) in the hourly or minute-by-minute time-scales. EMS coordinates with the other systems such as advanced metering infrastructure (AMI), maintenance scheduling, outage management, distribution management, and weather forecasting systems to gather an extensive amount of data on a real-time horizon. The gathered data is precisely processed to generate appropriate control signals to achieve the predetermined economic or technical goals. However, it is a hierarchical decision making including daily, hourly, and real-time scheduling. In this chapter, the performance of EMS is analyzed in both normal state and contingency conditions. Normal operation mainly focuses on economic aspects, whilst in the contingency state, EMS should guarantee the security of the system. This chapter presents a conceptual explanation on this topic along with the mathematical modelling and some examples.
Seyed Mohsen Hashemi; Vahid Vahidinasab. Energy Management Systems for Microgrids. Numerical Methods for Energy Applications 2021, 61 -95.
AMA StyleSeyed Mohsen Hashemi, Vahid Vahidinasab. Energy Management Systems for Microgrids. Numerical Methods for Energy Applications. 2021; ():61-95.
Chicago/Turabian StyleSeyed Mohsen Hashemi; Vahid Vahidinasab. 2021. "Energy Management Systems for Microgrids." Numerical Methods for Energy Applications , no. : 61-95.
Recently, the provision of the reserve from energy storage systems (ESSs) is introduced as a source for ancillary services to address the uncertainties of renewable power generations. The performance of ESSs is analysed while they are applied as a provider of regulation reserves. It has been revealed that previous stochastic models neglect the impact of corrective dispatches, related to the provision of regulation reserves, on the energy level stored in the ESSs, which can lead to large deviations. This study coordinates the stored energy of ESSs to be feasible regarding the dispatches in the base schedule and rescheduling within scenarios. Also, the wind speed fluctuations are considered as the source of uncertainty, and scenarios of wind energy are generated using the Weibull distribution function. The IEEE 24‐Bus standard test system is applied for the examination of the proposed model. The results show that the proposed model can manage the performance of ESSs in rescheduling within scenarios, while the coordinated reserve provision of ESSs can remove the concerns about insufficient stored energy of ESSs.
M. Habibi; V. Vahidinasab; J. Aghaei; B. Mohammadi‐Ivatloo. Assessment of energy storage systems as a reserve provider in stochastic network constrained unit commitment. IET Smart Grid 2021, 4, 139 -150.
AMA StyleM. Habibi, V. Vahidinasab, J. Aghaei, B. Mohammadi‐Ivatloo. Assessment of energy storage systems as a reserve provider in stochastic network constrained unit commitment. IET Smart Grid. 2021; 4 (2):139-150.
Chicago/Turabian StyleM. Habibi; V. Vahidinasab; J. Aghaei; B. Mohammadi‐Ivatloo. 2021. "Assessment of energy storage systems as a reserve provider in stochastic network constrained unit commitment." IET Smart Grid 4, no. 2: 139-150.
Ensuring the security and quality of supply in a power system after a contingency event is one of the most challenging tasks for an electricity system operator. This work is initiated by this challenge and proposes a solution based on the use of provided reserves by fast generators, storage devices, and wind farms. A coordinated model is proposed in a joint energy and reserves market considering their corresponding cost to ensure the adequacy in the simultaneous deployment of reserves for the different sources of uncertainties. The Benders decomposition approach is used in the modeling of the stochastic security-constrained unit commitment, and considering the large-scale and complex nature of the model, acceleration techniques are suggested to reduce the execution time. The proposed model is tested on the 6-bus and the IEEE 118-bus test systems. Numerical results show that the optimal values of reserves successfully address contingencies in both of the critical and normal periods after the contingencies and the optimal solution is calculated in a reasonable computing time.
Mahdi Habibi; Vahid Vahidinasab; Mohammad Sadegh Sepasian; Adib Allahham; Damian Giaouris; Phil Taylor; Jamshid Aghaei. Stochastic Procurement of Fast Reserve Services in Renewable Integrated Power Systems. IEEE Access 2021, 9, 30946 -30959.
AMA StyleMahdi Habibi, Vahid Vahidinasab, Mohammad Sadegh Sepasian, Adib Allahham, Damian Giaouris, Phil Taylor, Jamshid Aghaei. Stochastic Procurement of Fast Reserve Services in Renewable Integrated Power Systems. IEEE Access. 2021; 9 (99):30946-30959.
Chicago/Turabian StyleMahdi Habibi; Vahid Vahidinasab; Mohammad Sadegh Sepasian; Adib Allahham; Damian Giaouris; Phil Taylor; Jamshid Aghaei. 2021. "Stochastic Procurement of Fast Reserve Services in Renewable Integrated Power Systems." IEEE Access 9, no. 99: 30946-30959.
The transmission congestion issue from the high penetration of renewable energies places a premium on accurate dynamic line rating (DLR) as a short-term solution for the more efficient exploitation of the existing transmission infrastructure and the efficient and reliable operation of the power grids. Even though the DLR methods produce a worthy estimation of ampacity, they need the placement of measurement devices and communication networks along with the precise calibration of the estimators and the installation of sensors on the conductor surface. Herein, as a viable alternative, the DLR forecasting models with respect to historical meteorological data were developed using ensemble learning algorithms. Several cases were designed to explore the resiliency and accuracy of the proposed method for different forecasting horizons. The result of simulations proved that ensemble learning algorithms can be fruitfully used for the DLR forecasting, even in the presence of severe cyberattacks. The proposed method yielded an approximate capacity increase of 30\% for 400kV lines between Ghadamgah and Binalood wind farms, which is enough to relieve the congestion issue. Experiments revealed the generalizability and reliability of the forecasting models for the DLR at various points of the line without the deployment of measurement devices and communication infrastructures.
Amirhossein Ahmadi; Mojtaba Nabipour; Behnam Mohammadi-Ivatloo; Vahid Vahidinasab. Ensemble Learning-based Dynamic Line Rating Forecasting under Cyberattacks. IEEE Transactions on Power Delivery 2021, PP, 1 -1.
AMA StyleAmirhossein Ahmadi, Mojtaba Nabipour, Behnam Mohammadi-Ivatloo, Vahid Vahidinasab. Ensemble Learning-based Dynamic Line Rating Forecasting under Cyberattacks. IEEE Transactions on Power Delivery. 2021; PP (99):1-1.
Chicago/Turabian StyleAmirhossein Ahmadi; Mojtaba Nabipour; Behnam Mohammadi-Ivatloo; Vahid Vahidinasab. 2021. "Ensemble Learning-based Dynamic Line Rating Forecasting under Cyberattacks." IEEE Transactions on Power Delivery PP, no. 99: 1-1.
In this paper, an arbitrage strategy is proposed for renewable-based microgrids (MGs) to overcome the volatile behavior of renewable energy sources (RESs) such as photovoltaic and wind in a newly emerged business space in which peer-to-peer (P2P) energy trading in transactive energy markets (TEMs) set up between a day ahead market (DAM) and real-time markets (RTMs). To identify arbitrage opportunities created from the price difference between the P2P and real-time trades, a bi-level risk-constrained stochastic programming with interval coefficients (BRSPIC) is presented. In the first stage of the decision-making, scenarios are employed to deal with the DAM prices uncertainties. In the second stage, P2P energy trading competition is modelled by a bi-level programming based on non-cooperative leader-follower games. By getting closer to real-time, interval coefficients are considered in the third stage to cope with the uncertainties of RESs and loads, as well as RTM prices. The conditional value-at-risk (CVaR) is enforced the model to control the risk of profit variability. By using Karush-Kuhn-Tucker (KKT), the BRSPIC is transformed into a single level optimization. Then, it is linearized and solved by a mixed-integer linear programming (MILP) solver. By evaluating the proposed model on a test system, it is evident that the MG increases more than 3.1% of its profit by the arbitrage strategy. By considering CVaR, a fully risk-averse decision decreases the profit of MG by 27%, although it would be so conservative decision.
Hossein Nezamabadi; Vahid Vahidinasab. Arbitrage Strategy of Renewable-Based Microgrids via Peer-to-Peer Energy-Trading. IEEE Transactions on Sustainable Energy 2020, 12, 1372 -1382.
AMA StyleHossein Nezamabadi, Vahid Vahidinasab. Arbitrage Strategy of Renewable-Based Microgrids via Peer-to-Peer Energy-Trading. IEEE Transactions on Sustainable Energy. 2020; 12 (2):1372-1382.
Chicago/Turabian StyleHossein Nezamabadi; Vahid Vahidinasab. 2020. "Arbitrage Strategy of Renewable-Based Microgrids via Peer-to-Peer Energy-Trading." IEEE Transactions on Sustainable Energy 12, no. 2: 1372-1382.
Recently, there has been a focus on natural and man-made disasters with a high-impact low-frequency (HILF) property in electric power systems. A power system must be built with “resilience” or the ability to withstand, adapt and recover from disasters. The resilience metrics (RMs) are tools to measure the resilience level of a power system, normally employed for resilience cost–benefit in planning and operation. While numerous RMs have been presented in the power system literature; there is still a lack of comprehensive framework regarding the different types of the RMs in the electric power system, and existing frameworks have essential shortcomings. In this paper, after an extensive overview of the literature, a conceptual framework is suggested to identify the key variables, factors and ideas of RMs in power systems and define their relationships. The proposed framework is compared with the existing ones, and existing power system RMs are also allocated to the framework’s groups to validate the inclusivity and usefulness of the proposed framework, as a tool for academic and industrial researchers to choose the most appropriate RM in different power system problems and pinpoint the potential need for the future metrics.
Habibollah Raoufi; Vahid Vahidinasab; Kamyar Mehran. Power Systems Resilience Metrics: A Comprehensive Review of Challenges and Outlook. Sustainability 2020, 12, 9698 .
AMA StyleHabibollah Raoufi, Vahid Vahidinasab, Kamyar Mehran. Power Systems Resilience Metrics: A Comprehensive Review of Challenges and Outlook. Sustainability. 2020; 12 (22):9698.
Chicago/Turabian StyleHabibollah Raoufi; Vahid Vahidinasab; Kamyar Mehran. 2020. "Power Systems Resilience Metrics: A Comprehensive Review of Challenges and Outlook." Sustainability 12, no. 22: 9698.
This paper proposes a load control module based on the consumers' vulnerability indices to improve the ability of radial microgrid (MG) to deal with line contingencies. This consumer switching module (CSM) increases the operational flexibility and is suitable for the radial MGs, where, a sudden line outage restricts access to the energy resources and deviates the system frequency in the created island. To cope with this condition, CSM can instantly disconnect some of the loads and reconnects them in an appropriate time sequence, considering loads' vulnerabilities. To include the CSM in the short-term operation of MG, with the lowest complexity, a simple four-stage structure is used. At first, the capability of CSM is determined in different islands related to potential line events. Then, the approximate cost function of CSM is applied to the short-term MG operation which is hour-ahead scheduling (HAS) including both the normal and the contingency state operation. Eventually, the determined optimal CSM participation level in each island is allocated to the consumers based on their exact offered price to calculate the load switching sequence. To evaluate the performance of the proposed scheduling manner, the 13-bus and 123-bus IEEE test systems are precisely analyzed considering different simulation scenarios.
Seyed Mohsen Hashemi; Vahid Vahidinasab; Mohammad Sadegh Ghazizadeh; Jamshid Aghaei. Load control mechanism for operation of microgrids in contingency state. IET Generation, Transmission & Distribution 2020, 14, 5407 -5417.
AMA StyleSeyed Mohsen Hashemi, Vahid Vahidinasab, Mohammad Sadegh Ghazizadeh, Jamshid Aghaei. Load control mechanism for operation of microgrids in contingency state. IET Generation, Transmission & Distribution. 2020; 14 (23):5407-5417.
Chicago/Turabian StyleSeyed Mohsen Hashemi; Vahid Vahidinasab; Mohammad Sadegh Ghazizadeh; Jamshid Aghaei. 2020. "Load control mechanism for operation of microgrids in contingency state." IET Generation, Transmission & Distribution 14, no. 23: 5407-5417.
One of the most important aspects of the development of Electric Vehicles (EVs) is the optimal sizing and allocation of charging stations. Due to the interactions between the electricity and transportation systems, the key features of these systems (such as traffic network characteristics, charging demands and power system constraints) should be taken into account for the optimal planning. This paper addressed the optimal sizing and allocation of the fast-charging stations in a distribution network. The traffic flow of EVs is modeled using the User Equilibrium-based Traffic Assignment Model (UETAM). Moreover, a stochastic framework is developed based on the Queuing Theory (QT) to model the load levels (EVs’ charging demand). The objective function of the problem is to minimize the annual investment cost, as well as the energy losses that are optimized through chance-constrained programming. The probabilistic aspects of the proposed problem are modeled by using the point estimation method and Gram-Charlier expansion. Furthermore, the probabilistic dominance criteria are employed in order to compare the uncertain alternatives. Finally, the simulation results are provided for both the distribution and traffic systems to illustrate the performance of the proposed problem.
Raziye Aghapour; Mohammad Sadegh Sepasian; Hamidreza Arasteh; Vahid Vahidinasab; João P.S. Catalão. Probabilistic planning of electric vehicles charging stations in an integrated electricity-transport system. Electric Power Systems Research 2020, 189, 106698 .
AMA StyleRaziye Aghapour, Mohammad Sadegh Sepasian, Hamidreza Arasteh, Vahid Vahidinasab, João P.S. Catalão. Probabilistic planning of electric vehicles charging stations in an integrated electricity-transport system. Electric Power Systems Research. 2020; 189 ():106698.
Chicago/Turabian StyleRaziye Aghapour; Mohammad Sadegh Sepasian; Hamidreza Arasteh; Vahid Vahidinasab; João P.S. Catalão. 2020. "Probabilistic planning of electric vehicles charging stations in an integrated electricity-transport system." Electric Power Systems Research 189, no. : 106698.
This study proposes a two-stage robust optimisation framework to model uncertainties in construction cost, load and renewable power generations (RPGs) in the coordinated transmission and reactive power infrastructure expansion planning problem. The proposed planning model, based on the network AC model and its voltage constraints, is represented as a mixed-integer linear programing problem with the aim of minimising: (i) the construction costs of lines, (ii) installation cost of reactive power resources and (iii) active load shedding as RPGs curtailment. Using the suggested robust optimisation approach, the best expansion plan is obtained even in the worst case of the defined uncertainty sets and the plan robustness level is controlled via parameter definition for the individual uncertainty sets. The Benders decomposition algorithm is used to solve the two-stage problem where the plan security level is also taken into consideration using the N−1 contingency criterion. The standard Garver 6-bus system and the IEEE 24-bus reliability test system are used to validate the proposed robust framework.
Nader Olfatinezhad; Vahid Vahidinasab; Mohammad Ahmadian; Hamidreza Arasteh; Jamshid Aghaei; Kamyar Mehran. Flexible two‐stage robust model for moving the transmission and reactive power infrastructures expansion planning towards power system integration of renewables. IET Renewable Power Generation 2020, 14, 1921 -1932.
AMA StyleNader Olfatinezhad, Vahid Vahidinasab, Mohammad Ahmadian, Hamidreza Arasteh, Jamshid Aghaei, Kamyar Mehran. Flexible two‐stage robust model for moving the transmission and reactive power infrastructures expansion planning towards power system integration of renewables. IET Renewable Power Generation. 2020; 14 (11):1921-1932.
Chicago/Turabian StyleNader Olfatinezhad; Vahid Vahidinasab; Mohammad Ahmadian; Hamidreza Arasteh; Jamshid Aghaei; Kamyar Mehran. 2020. "Flexible two‐stage robust model for moving the transmission and reactive power infrastructures expansion planning towards power system integration of renewables." IET Renewable Power Generation 14, no. 11: 1921-1932.
This paper presents a contingency-based stochastic security-constrained unit commitment to address the integration of wind power producers to the joint energy and reserve markets. The contingency ranking is a popular method for reducing the computation burden of the unit commitment problem, but performing the contingency analysis changes the high-impact events in previous ranking methods. This paper employs an intelligent contingency ranking technique to address the above issue and to find the actual top-ranked outages based on the final solution. Also, energy storage systems are considered to evaluate the impact of the scheduling of storage under uncertainties. Numerical results on a six-bus and the IEEE 118-bus test systems show the effectiveness of the proposed approach. Furthermore, it shows that utilizing both wind farms and storage devices will reduce the total operational cost of the system, while the intelligent contingency ranking analysis and enough reserves ensure the security of power supply.
Mahdi Habibi; Vahid Vahidinasab; Abolfazl Pirayesh; Miadreza Shafie-Khah; Joao P. S. Catalao. An Enhanced Contingency-Based Model for Joint Energy and Reserve Markets Operation by Considering Wind and Energy Storage Systems. IEEE Transactions on Industrial Informatics 2020, 17, 3241 -3252.
AMA StyleMahdi Habibi, Vahid Vahidinasab, Abolfazl Pirayesh, Miadreza Shafie-Khah, Joao P. S. Catalao. An Enhanced Contingency-Based Model for Joint Energy and Reserve Markets Operation by Considering Wind and Energy Storage Systems. IEEE Transactions on Industrial Informatics. 2020; 17 (5):3241-3252.
Chicago/Turabian StyleMahdi Habibi; Vahid Vahidinasab; Abolfazl Pirayesh; Miadreza Shafie-Khah; Joao P. S. Catalao. 2020. "An Enhanced Contingency-Based Model for Joint Energy and Reserve Markets Operation by Considering Wind and Energy Storage Systems." IEEE Transactions on Industrial Informatics 17, no. 5: 3241-3252.
This study proposes an integrated framework for coordinated optimisation of the interdependent microgrid (MG) and electric vehicle (EV) fleet entities using the normalised normal constraint approach. By considering the active/reactive power management option of the bidirectional charger enabled EVs in the proposed model, the authors investigate the effectiveness of EV's integration in the presence of the techno-economical objective functions. This work concentrates on the trade-off analysis of two conflicting objectives, including the economic objective of the MG's operation cost minimisation and the technical objective of the MG's voltage deviation. Besides, they consider several uncertainty sources, e.g. wind, EV and solar panel (PV) power provision, as well as market price fluctuations in the proposed model affecting the aforementioned techno-economic trade-off solution. The proposed model is a stochastic multi-objective mixed-integer non-linear programming problem where the authors apply the designed integrated framework on a modified IEEE 18-bus test case in GAMS software. Through numerical results, they demonstrate MG optimal operation changes due to different MGO priorities and study the positive effects of EVs integrated energy management on the bi-objective operation.
Mohammadali Saffari; Mohsen Kia; Vahid Vahidinasab; Kamyar Mehran. Integrated active/reactive power scheduling of interdependent microgrid and EV fleets based on stochastic multi‐objective normalised normal constraint. IET Generation, Transmission & Distribution 2020, 14, 2055 -2064.
AMA StyleMohammadali Saffari, Mohsen Kia, Vahid Vahidinasab, Kamyar Mehran. Integrated active/reactive power scheduling of interdependent microgrid and EV fleets based on stochastic multi‐objective normalised normal constraint. IET Generation, Transmission & Distribution. 2020; 14 (11):2055-2064.
Chicago/Turabian StyleMohammadali Saffari; Mohsen Kia; Vahid Vahidinasab; Kamyar Mehran. 2020. "Integrated active/reactive power scheduling of interdependent microgrid and EV fleets based on stochastic multi‐objective normalised normal constraint." IET Generation, Transmission & Distribution 14, no. 11: 2055-2064.
Planning of the electric distribution networks is complex and about upgrading the system to satisfy the demand and constraints with the best economic plan. The planning alternatives include the expansion of substations, installing new distributed generation (DG) facilities, upgrading distribution feeders, etc. In the modern networks, distribution planners must gain the confidence of the reversibility of the investment where renewable energy resources (RERs) inject clean and cost-effective electrical power to respond to the rising demand and satisfy environmental standards. This paper is an exhaustive review on the distribution network expansion planning (DEP) including the modelling of DEP (possible objective functions, problem constraints, different horizon time, and problem variables), optimization model (single/multi-objective), the expansion of distributed energy resources (DERs), problem uncertainties, etc. We discuss the requirements of integrated energy district master planning to avoid conflicts between the goal of independence of district planning on energy, e.g. heat and electricity, and that of dependencies on the local electric utilities regarding instant power balance and stability services. Finally, we describe the primary future R&D trends in the field of distribution network planning.
Vahid Vahidinasab; Mahdi Tabarzadi; Hamidreza Arasteh; Mohammad Iman Alizadeh; Mohammad Mohammad Beigi; Hamid Reza Sheikhzadeh; Kamyar Mehran; Mohammad Sadegh Sepasian. Overview of Electric Energy Distribution Networks Expansion Planning. IEEE Access 2020, 8, 34750 -34769.
AMA StyleVahid Vahidinasab, Mahdi Tabarzadi, Hamidreza Arasteh, Mohammad Iman Alizadeh, Mohammad Mohammad Beigi, Hamid Reza Sheikhzadeh, Kamyar Mehran, Mohammad Sadegh Sepasian. Overview of Electric Energy Distribution Networks Expansion Planning. IEEE Access. 2020; 8 (99):34750-34769.
Chicago/Turabian StyleVahid Vahidinasab; Mahdi Tabarzadi; Hamidreza Arasteh; Mohammad Iman Alizadeh; Mohammad Mohammad Beigi; Hamid Reza Sheikhzadeh; Kamyar Mehran; Mohammad Sadegh Sepasian. 2020. "Overview of Electric Energy Distribution Networks Expansion Planning." IEEE Access 8, no. 99: 34750-34769.
With the evolution of smart grids, penetration of distributed energy resources (DERs) in the distribution networks has become ever-increasing problem. To improve network reliability, the complexity of the two important aspects of adequacy and security must be well assessed. There is a trade-off between adequacy of DERs, and the distribution network security, i.e. improving the adequacy can reduce the security. In this study, enhancement of the distribution network adequacy and security is proposed. In this regard, capacity of simultaneous reconfiguration and DERs sizing are utilised to improve the adequacy and security of an active distribution network. In the reconfiguration process, graph theory concept is adopted to implement a fast reconfiguration method. Since DERs are active, a combined bus and line security index is used to overcome security concerns of their existence. The IEEE 33-bus distribution network as a widely used standard test system in reconfiguration studies, and a practical 83-bus distribution network of Taiwan Power Company (TPC) which is a part of a real distribution network, are used to test the performance of the proposed method. The simulation results demonstrate the performance of the proposed framework.
Seyed‐Alireza Ahmadi; Vahid Vahidinasab; Mohammad Sadegh Ghazizadeh; Kamyar Mehran; Damian Giaouris; Phil Taylor. Co‐optimising distribution network adequacy and security by simultaneous utilisation of network reconfiguration and distributed energy resources. IET Generation, Transmission & Distribution 2019, 13, 4747 -4755.
AMA StyleSeyed‐Alireza Ahmadi, Vahid Vahidinasab, Mohammad Sadegh Ghazizadeh, Kamyar Mehran, Damian Giaouris, Phil Taylor. Co‐optimising distribution network adequacy and security by simultaneous utilisation of network reconfiguration and distributed energy resources. IET Generation, Transmission & Distribution. 2019; 13 (20):4747-4755.
Chicago/Turabian StyleSeyed‐Alireza Ahmadi; Vahid Vahidinasab; Mohammad Sadegh Ghazizadeh; Kamyar Mehran; Damian Giaouris; Phil Taylor. 2019. "Co‐optimising distribution network adequacy and security by simultaneous utilisation of network reconfiguration and distributed energy resources." IET Generation, Transmission & Distribution 13, no. 20: 4747-4755.
This paper proposes microgrid (MG) bidding strategy in the transactive energy market (TEM), in which market participants are able to negotiate and trade by a new-designed smart contract (SC) in a peer-to-peer way. In such a market, MG can balance its deviations, which are the resultant of the intermittency of the renewable energy sources, and the volatility of the load. In this paper, the uncertainty is handled by interval optimization. By participation in the TEM, the MG bidding problem is a bi-level optimization with interval coefficient, in which the MG’s profit maximizes in the upper level and the rivals’ behaviour in the TEM are modelled in the lower level. In order to solve the aforementioned problem, the proposed model recasts as a single-level interval optimization problem by the Karush-Kuhn-Tucker (KKT) conditions and the interval optimization concept. Simulation results show the applicability of the proposed model and realize the 1.7% increase in the MG profit for a 4-hour duration basis TEM. Scientia Iranica (SCI)
Hossein Nezamabadi; Vahid Vahidinasab. Microgrids Bidding Strategy in a Transactive Energy Market. Scientia Iranica 2019, 1 .
AMA StyleHossein Nezamabadi, Vahid Vahidinasab. Microgrids Bidding Strategy in a Transactive Energy Market. Scientia Iranica. 2019; ():1.
Chicago/Turabian StyleHossein Nezamabadi; Vahid Vahidinasab. 2019. "Microgrids Bidding Strategy in a Transactive Energy Market." Scientia Iranica , no. : 1.