M. Shahidehpour

King Abdulaziz University, Djidda, Makkah, Saudi Arabia

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Publications (181)249.47 Total impact

  • Wei Tian, Zuyi Li, Mohammad Shahidehpour
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    ABSTRACT: A review of renewable energy development and policy in Illinois indicates that the state's renewable portfolio standard appears to have enabled significant job creation and economic development opportunities as well as environmental benefits. Hourly simulations for the year 2011 suggest that the integration of wind, measured by its impact on locational marginal prices, will play a dramatic role in reducing energy prices in Illinois.
    The Electricity Journal 03/2014;
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    L. Che, M. Khodayar, M. Shahidehpour
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    ABSTRACT: Distributed energy resources (DERs) offer on-site generation at consumption points, which are expected to change the conventional concept of central power generation. DER integration reduces transmission losses and enhances the operation reliability of distribution systems. However, distribution systems are traditionally designed as passive networks in which large DER penetrations representing bidirectional power flows and topology-dependent fault currents could affect protection devices, cause danger to the maintenance personnel, and result in uncontrollable under-/overvoltage and frequency. IEEE Standard 1547 requires DER units to stop energizing the distribution system when the system is de-energized due to faults.
    Electrification Magazine, IEEE. 01/2014; 2(1):66-80.
  • Saeed Kamalinia, Mohammad Shahidehpour, Lei Wu
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    ABSTRACT: This study investigates the role of sustainable energy volatility in a market participant’s competitive expansion planning problem. The incomplete information non-cooperative game-theoretic method is utilized in which each generation company (GENCO) perceives strategies of other market participants in order to make a decision on its strategic generation capacity expansion. Sustainable generation incentives, carbon emission penalties, and fuel price forecast errors are considered in the strategic decisions. The market clearing process for energy and reserves is simulated by each GENCO for deriving generation expansion decisions. A merit criterion (i.e., the utility value) is proposed for a more realistic calculation of the expected payoff of a GENCO with sustainable energy resources. Finally, the impact of transmission constraints is investigated on the GENCO’s expansion planning decision. The case studies illustrate the effectiveness of the proposed method.
    Applied Energy. 01/2014; 133:112–120.
  • Y. Jiang, J. Liu, W. Tian, M. Shahidehpour, M. Krishnamurthy
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    ABSTRACT: N Enormous amount of energy is generated by railway cars when applying regenerative braking in train stations. This article discusses the methods for absorbing, storing, and using the energy produced by regenerative braking. Two methods are proposed: 1) regenerative energy is fed back to the distribution grid for supplying stationary loads at train stations and 2) regenerative energy is used to charge railway car-mounted storage containers, which can also supply stationary loads or be transported elsewhere for supplying remote loads. The working principles and topological structures of the two methods are introduced. In addition, main circuits and corresponding control systems are simulated, and analyses are conducted to validate the proposed methods for train stations in China.
    Electrification Magazine, IEEE. 01/2014; 2(3):39-48.
  • M.E. Khodayar, M. Shahidehpour
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    ABSTRACT: This letter presents the solution framework for calculating multi-participant Nash equilibria in a transmission-constrained electricity market. The proposed framework, which is generally applicable to various gaming conditions in electricity markets, is used here for non-cooperative complete information game between market participants with discrete bidding strategies. The example in this letter shows the effectiveness of the proposed framework in finding the Nash equilibrium.
    IEEE Transactions on Power Systems 01/2014; 29(2):986-987. · 2.92 Impact Factor
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    ABSTRACT: The integration of high-voltage direct-current (dc) transmission lines in conventional alternating-current (ac) systems would affect the indirect measurement of phasor measurement unit (PMU) devices since the concept of phasors would not correspond to dc transmission circuits. The optimal PMU placement problem in ac/dc systems subjected to the system observability is presented in this paper by applying a mixed-integer programming model. In practice, the cost of each PMU is variable as a function of PMU measurement channels. This attribute is incorporated in the proposed model as well. In addition, the number of PMU measurement channels is deemed to be technically limited; thus, the common assumption concerning allocation of one PMU device to a single node is relaxed. The objective in the proposed optimization model is to minimize the total installation cost of PMUs when considering the observability of ac/dc transmission systems in the base case and contingency conditions. Numerical analyses are conducted for the IEEE standard test systems and a large-scale system, and the results are discussed.
    IEEE Transactions on Power Delivery 01/2014; 29(1):345-352. · 1.52 Impact Factor
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    ABSTRACT: The dynamic state estimation (DSE) applied to power systems with synchrophasor measurements would estimate the system's true state based on measurements and predictions. In this application, as phasor measurement units (PMUs) are not deployed at all power system buses, state predictions would enhance the redundancy of DSE input data. The significance of predicted and measured data in DSE is affected by their confidence levels, which are inversely proportional to the corresponding variances. In practice, power system states may undergo drastic changes during hourly load fluctuations, component outages, or network switchings. In such conditions, the inclusion of predicted values could degrade the power system state estimation. This paper presents a mixed-integer programming formulation of DSE that is capable of simultaneously discarding predicted values whenever sudden changes in the system state are detected. This feature enhances the DSE computation and will not require iterative executions. The proposed model accommodates system-wide synchronized measurements of PMUs, which could be of interest to smart grid applications in energy management systems. The voltage phasors at buses without PMUs are calculated via voltage and current measurements of adjacent buses, which are referred to as indirect measurements. The guide to the expression of uncertainty in measurement is used for computing the confidence level of indirect measurements based on uncertainties associated with PMU measurements as well as with transmission line parameters. Simulation studies are conducted on an illustrative three-bus example and the IEEE 57-bus power system, and the performance of the proposed model is thoroughly discussed.
    IEEE Transactions on Instrumentation and Measurement 01/2014; 63(2):352-363. · 1.71 Impact Factor
  • S. Kamalinia, L. Wu, M. Shahidehpour
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    ABSTRACT: This paper presents a stochastic security-constrained unit commitment (SCUC) model for the optimal midterm and flexible allocations of hydro and natural gas systems when accommodating a large integration of wind energy. Random errors in forecasting the hourly wind, natural water inflow, and electric load as well as random outages of power system components are modeled in scenarios via the Monte Carlo (MC) simulation. The proposed optimization model is formulated as a two-stage stochastic problem, where short-term and midterm generation resource optimizations are investigated in the first and the second stages, respectively. The reliability criteria including the loss of load expectation (LOLE) and load curtailment limits are incorporated into the midterm stochastic SCUC problem, where electric power and natural gas network constraints are checked. Numerical experiments signify the effectiveness of the proposed method for the midterm optimal scheduling of water and natural gas flexibilities when integrating wind energy resources.
    IEEE Transactions on Sustainable Energy 01/2014; 5(4):1070-1079. · 3.84 Impact Factor
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    Masood Parvania, Mahmud Foruhi-Firuzabad, Mohammad Shahidehpour
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    ABSTRACT: Electric energy storage (EES) installations in power systems are migrating from large centralized systems to more distributed installations for microgrid applications. This trend signifies modular EES installations for the local control of buildings and processes. A centralized EES system is often dispatched by grid operators for increasing the overall efficiency and enhancing the security of power systems. The distributed EES (DEES) is locally managed by aggregators to maximize the local impact of EES, before the aggregators’ adjusted load profiles are submitted to grid operators for the day-ahead scheduling. In this paper, we present and analyze two models for the hourly scheduling of centralized and distributed EES systems in day-ahead electricity markets. The proposed models take into account specific characteristics and intertemporal constraints of EES systems in transmission-constrained power systems. The proposed models are applied to a 6-bus system and the IEEE-RTS, and the results are presented to compare impacts of utilizing the two EES models on system operations and quantify operation benefits of EES in power systems.
    IEEE Transactions on Sustainable Energy 01/2014; · 3.84 Impact Factor
  • H. Wu, M. Shahidehpour
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    ABSTRACT: This paper proposes a constrained ordinal optimization (COO) based method for solving the scenario-based stochastic security constrained unit commitment problem. The basic idea is to sample a large number of candidate unit commitment (UC) solutions by a crude model and then use an accurate model on a small selected subset to find good enough UC solutions over all scenarios. To facilitate the proposed method, a feasibility model is utilized that applies analytical conditions for identifying the feasibility of UCs. A blind picking approach based on the feasibility model is incorporated in the COO-based method for seeking good enough solutions. Numerical tests are performed on a modified IEEE 118-bus system with a high penetration of wind energy, in which hourly forecast errors of wind speed and loads and random outages of system components are considered. The simulation results show the validity and the effectiveness of the proposed method. Comparative evaluations of the proposed COO-based method with mixed-integer linear programming solvers are considered in this paper.
    IEEE Transactions on Sustainable Energy 01/2014; 5(2):379-388. · 3.84 Impact Factor
  • H. Wu, M. Shahidehpour, Z. Li, W. Tian
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    ABSTRACT: This paper proposes a day-ahead stochastic scheduling model in electricity markets. The model considers hourly forecast errors of system loads and variable renewable sources as well as random outages of power system components. A chance-constrained stochastic programming formulation with economic and reliability metrics is presented for the day-ahead scheduling. Reserve requirements and line flow limits are formulated as chance constraints in which power system reliability requirements are to be satisfied with a presumed level of high probability. The chance-constrained stochastic programming formulation is converted into a linear deterministic problem and a decomposition-based method is utilized to solve the day-ahead scheduling problem. Numerical tests are performed and the results are analyzed for a modified 31-bus system and an IEEE 118-bus system. The results show the viability of the proposed formulation for the day-ahead stochastic scheduling. Comparative evaluations of the proposed chance-constrained method and the Monte Carlo simulation (MCS) method are presented in the paper.
    IEEE Transactions on Power Systems 01/2014; 29(4):1583-1591. · 2.92 Impact Factor
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    Liang Che, M. Khodayar, M. Shahidehpour
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    ABSTRACT: Electricity infrastructure is the cornerstone of every industrialized nation in the world. As the utility grid ages and the demand for electricity grows, the impact of major interruptions of the electricity infrastructure will be more intense. Costly power outages throughout the world caused by natural disasters such as floods and hurricanes have highlighted the importance of reinforcing the electricity infrastructure. A recent study conducted for the U.S. Department of Energy indicated that sustained power interruptions (those lasting more than 5 min) in the United States incur costs of more than US$26 billion dollars annually. Power outages caused by Hurricanes Sandy and Katrina in the United States threw into notice the crucial role of smart grid technology and the need for further investments in more comprehensive data communication and distribution management systems, distributed energy resources, energy storage facilities, additional automation, and further migration toward decentralized operations for the largely centralized power grid.
    IEEE Power and Energy Magazine 01/2014; 12(1):70-81. · 1.58 Impact Factor
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    Masood Parvania, Mahmud Fotuhi-Firuzabad, Mohammad Shahidehpour
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    ABSTRACT: This paper presents a hierarchical demand response (DR) bidding framework in the day-ahead energy markets which integrates customer DR preferences and characteristics in the ISO’s market clearing process. In the proposed framework, load aggregators submit aggregated DR offers to the ISO which would centrally optimize final decisions on aggregators’ DR contributions in wholesale markets. The hourly load reduction strategies include load shifting and curtailment and the use of onsite generation and energy storage systems. The ISO applies mixed-integer linear programming (MILP) to the solution of the proposed DR model in the day-ahead market clearing problem. The proposed model is implemented using a 6-bus system and the IEEE-RTS, and several studies are conducted to demonstrate the merits of the proposed DR model.
    IEEE Transactions on Power Systems 01/2014; · 2.92 Impact Factor
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    L. Che, M. Shahidehpour
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    ABSTRACT: The additional deployment of distributed energy resources (DERs) has attracted further attention to dc microgrid applications. The objective of the study is to discuss the possibilities and the merits of adopting a dc control system for enhancing the economics and the resilient operation of a dc microgrid, and to test the proposed hierarchical control strategy that applies to a dc microgrid. This paper provides case studies in which an existing microgrid at the Illinois Institute of Technology (IIT) is operated as a dc microgrid and the results for each case are compared with the ac model. The structure, components, and control strategies of IIT dc microgrids are discussed and the economic operation of a grid-connected dc microgrid through tertiary control, as well as islanding, load restoration, and resynchronization of the dc microgrid are simulated. The dc microgrid simulation results are compared with those of an ac microgrid, which demonstrate that the proposed coordinated dc strategy for the optimal operation of DERs is an effective way of ensuring the resilient response of dc microgrid to emergencies and its economic operation at steady state.
    IEEE Transactions on Smart Grid 01/2014; 5(5):2517-2526.
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    Masood Parvania, Mahmud Fotuhi-Firuzabad, Mohammad Shahidehpour
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    ABSTRACT: Advancements in smart grid technologies have made it possible to apply various options and strategies for the optimization of demand response (DR) in electricity markets. DR aggregation would accumulate potential DR schedules and constraints offered by small- and medium-sized customers for the participation in wholesale electricity markets. Despite various advantages offered by the hourly DR in electricity markets, practical market tools that can optimize the economic options available to DR aggregators and market participants are not readily attainable. In this context, this paper presents an optimization framework for the DR aggregation in wholesale electricity markets. The proposed study focuses on the modeling strategies for energy markets. In the proposed model, DR aggregators offer customers various contracts for load curtailment, load shifting, utilization of onsite generation, and energy storage systems as possible strategies for hourly load reductions. The aggregation of DR contracts is considered in the proposed price-based self-scheduling optimization model to determine optimal DR schedules for participants in day-ahead energy markets. The proposed model is examined on a sample DR aggregator and the numerical results are discussed in the paper.
    IEEE Transactions on Smart Grid 12/2013; 4(4):1957-1965.
  • Shouxiang Wang, Zhixin Li, Lei Wu, M. Shahidehpour, Zuyi Li
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    ABSTRACT: This paper proposes a series of new metrics for the reliability and economic assessment of microgrids in distribution system. These metrics include reliability parameters for a microgrid in the islanded mode, indices indicating distributed generation (DG) and load characteristics in the microgrid, microgrid economic indices, and customer based microgrid reliability indices. A two-step Monte Carlo simulation (MCS) method is proposed to assess the reliability and economics of a microgrid with intermittent DGs as well as the reliability of distribution system with microgrids. An application in IEEE-RBTS shows the effectiveness of the reliability and economic assessment technique with the proposed metrics, which can provide scientific and comparative information for the design and operation of microgrids.
    IEEE Transactions on Power Systems 01/2013; 28(3):2852-2861. · 2.92 Impact Factor
  • A. Khodaei, M. Shahidehpour
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    ABSTRACT: This paper presents an algorithm for the microgrid planning as an alternative to the co-optimization of generation and transmission expansion planning in electric power systems. The integration of microgrids in distribution systems will offer a decentralized control of local resources for satisfying the network reliability and the power quality required by local loads. The objective in this paper is to minimize the total system planning cost comprising investment and operation costs of local microgrids, the co-optimized planning of large generating units and transmission lines, and the expected cost of unserved energy. The cost of unserved energy reflects the cost of load shedding which is added to the objective function for reliability considerations. The microgrid-based co-optimization planning problem is decomposed into a planning problem and annual reliability subproblem. The optimal integer planning decisions calculated in the planning problem will be examined against the system reliability limits in the subproblem and the planning decisions will be revised using proper feasibility cuts if the annual reliability limits are violated. Numerical simulations demonstrate the effectiveness of the proposed microgrid-based co-optimization planning in power systems and explore the economic and reliability merits of microgrid planning as compared to grid-based generation and transmission upgrades.
    IEEE Transactions on Power Systems 01/2013; 28(2):1582-1590. · 2.92 Impact Factor
  • C. Sahin, M. Shahidehpour, I. Erkmen
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    ABSTRACT: This paper presents a stochastic method for the hourly scheduling of optimal reserves when the hourly forecast errors of wind energy and load are considered. The approach utilizes the stochastic security-constrained unit commitment (SCUC) model and a two-stage stochastic programming for the day-ahead scheduling of wind energy and conventional units with N-1 contingencies. The effect of aggregated hourly demand (DR) response is considered as a means of mitigating transmission violations when uncertainties are considered. The proposed mixed-integer programming (MIP) model applies the Monte Carlo method for representing the hourly wind energy and system load forecast errors. A 6-bus, 118-bus, and the Northwest region of Turkish electric power network are considered to demonstrate the effectiveness of the proposed day-ahead stochastic scheduling method in power systems.
    IEEE Transactions on Sustainable Energy 01/2013; 4(1):219-228. · 3.84 Impact Factor
  • Hongyu Wu, M. Shahidehpour, A. Al-Abdulwahab
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    ABSTRACT: This study proposes a stochastic optimisation model for the day-ahead scheduling in power systems, which incorporates the hourly demand response (DR) for managing the variability of renewable energy sources (RES). DR considers physical and operating constraints of the hourly demand for economic and reliability responses. The proposed stochastic day-ahead scheduling algorithm considers random outages of system components and forecast errors for hourly loads and RES. The Monte Carlo simulation is applied to create stochastic security-constrained unit commitment (SCUC) scenarios for the day-ahead scheduling. A general-purpose mixed-integer linear problem software is employed to solve the stochastic SCUC problem. The numerical results demonstrate the benefits of applying DR to the proposed day-ahead scheduling with variable RES.
    IET Generation Transmission & Distribution 01/2013; 7(3):226-234. · 1.41 Impact Factor
  • M.E. Khodayar, L. Abreu, M. Shahidehpour
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    ABSTRACT: This study proposes a coordination methodology for wind and pumped-storage hydro (PS) units in the day-ahead operation planning of power systems. PS units that can store the extra wind energy will improve the dispatchability of variable wind energy for delivering hourly firmed energy to a power grid. With coordination, the PS unit can offset intrahour wind energy imbalances (i.e. deviations from hourly schedules) and minimise wind energy curtailments. The proposed coordination, which is incorporated into the transmission-constrained unit commitment, can be used by a vertically integrated utility or an independent system operator. The concept of intrahour wind energy imbalances and the wind-PS coordination is illustrated using two case studies. The numerical results for the 6-bus and the IEEE 118-bus system include case studies with and without the coordination of PS and wind generation units. The results that include the intrahour variability of real-time wind speed show the applicability of the proposed wind-PS coordination approach to the short-term power system operation.
    IET Generation Transmission & Distribution 01/2013; 7(7):755-765. · 1.41 Impact Factor

Publication Stats

2k Citations
249.47 Total Impact Points

Institutions

  • 2014
    • King Abdulaziz University
      • Department of Electrical and Computer Engineering
      Djidda, Makkah, Saudi Arabia
  • 2001–2014
    • Illinois Institute of Technology
      • Department of Electrical & Computer Engineering
      Chicago, Illinois, United States
  • 2009–2011
    • Sharif University of Technology
      • Department of Electrical Engineering
      Tehrān, Ostan-e Tehran, Iran
  • 2010
    • Universidad Tecnológica de Pereira
      Cartago Viejo, Risaralda, Colombia
  • 2009–2010
    • Gyeongsang National University
      • Department of Electrical Engineering
      Chinju, South Gyeongsang, South Korea
  • 2006–2008
    • Middle East Technical University
      • Department of Electrical and Electronics Engineering
      Ankara, Ankara, Turkey
  • 2004
    • Yarmouk University
      • Department of Computer Engineering
      Irbid, Irbid, Jordan
    • Technical University Darmstadt
      Darmstadt, Hesse, Germany
    • University of British Columbia - Vancouver
      Vancouver, British Columbia, Canada
  • 2003–2004
    • Ferdowsi University Of Mashhad
      • Department of Electrical Engineering
      Mashhad, Razavi Khorasan, Iran