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Shaghayegh Zalzar
Department of Energy, Politecnico di Torino, Turin, Italy

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Research article
Published: 23 October 2019 in Energy Policy
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The European Commission has set a target of establishing an integrated Europe-wide electricity market for day-ahead and intraday transactions. However, there are still many open questions on the potential benefits of a Europe-wide intraday market integration and the harmonizing market rules. This paper intends to provide a precise insight into the potential impacts of EU policies regarding integrating electricity markets on market efficiency and on different market players with the aim of supporting policy makers to increase the penetration of renewables in a cost efficient manner. In this paper, we investigate and compare the current option of regional intraday electricity market with the option of an integrated Europe-wide one, with reference to the three European test cases with high renewable penetration: the Iberian electricity market including Spain and Portugal, the Italian electricity market including Italy and Slovenia, and the electricity market of Germany. We consider two 2030 scenarios: (i) the regional/local intraday electricity market, and (ii) the integration of the current regional intraday market of the test cases into a single intraday market in Europe. The two scenarios are modelled through stochastic Monte Carlo simulation, considering uncertainty on electricity demand, wind and solar power. The performance of the intraday market under the two options are compared in terms of generation cost, electricity prices, producer’ surplus, and load expenditure inside the European test cases. The simulation results lead to the conclusion that integrating to a Europe-wide intraday electricity market is not advantageous for power producers inside the European countries with high share of variable renewable generation, in terms of annual generation surplus. However, from the customers’ point of view, intraday market integration is beneficial, leading to lower cost to loads. Furthermore, it is shown that the flexibility provided by the installed capacity of hydro pumped-storage generators within Europe, by 2030, eliminates the planned curtailment of renewable energy sources in day-ahead and intraday markets and confines the impact of market integration on the market performance indicators.

ACS Style

Shaghayegh Zalzar; Ettore Bompard; Arturs Purvins; Marcelo Masera. The impacts of an integrated European adjustment market for electricity under high share of renewables. Energy Policy 2019, 136, 111055 .

AMA Style

Shaghayegh Zalzar, Ettore Bompard, Arturs Purvins, Marcelo Masera. The impacts of an integrated European adjustment market for electricity under high share of renewables. Energy Policy. 2019; 136 ():111055.

Chicago/Turabian Style

Shaghayegh Zalzar; Ettore Bompard; Arturs Purvins; Marcelo Masera. 2019. "The impacts of an integrated European adjustment market for electricity under high share of renewables." Energy Policy 136, no. : 111055.

Journal article
Published: 06 May 2019 in Sustainability
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In this paper, a direct power control (DPC) technique is proposed for matrix converter-fed grid-connected doubly fed induction generators (DFIGs). In contrast to what has been investigated in the past for direct torque control (DTC) or DPC of matrix converter-fed DFIGs, the active and reactive powers are regulated in a fixed switching frequency using indirect space vector modulation (ISVM) technique. Hence, designing input filters for matrix converters (MCs) becomes convenient. In addition, the reactive component of input side of MC is controlled which leads to reduction of distortion in grid current waveform. Also, an extensive discussion is addressed for nonlinear voltage errors of MC that may cause inaccurate power control. Simulation results done in MATLAB/Simulink show the effectiveness of the proposed method.

ACS Style

Arzhang Yousefi-Talouki; Shaghayegh Zalzar; Edris Pouresmaeil. Direct Power Control of Matrix Converter-Fed DFIG with Fixed Switching Frequency. Sustainability 2019, 11, 2604 .

AMA Style

Arzhang Yousefi-Talouki, Shaghayegh Zalzar, Edris Pouresmaeil. Direct Power Control of Matrix Converter-Fed DFIG with Fixed Switching Frequency. Sustainability. 2019; 11 (9):2604.

Chicago/Turabian Style

Arzhang Yousefi-Talouki; Shaghayegh Zalzar; Edris Pouresmaeil. 2019. "Direct Power Control of Matrix Converter-Fed DFIG with Fixed Switching Frequency." Sustainability 11, no. 9: 2604.

Journal article
Published: 26 July 2018 in Energies
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Currently, the power transmission system of the Baltic states is synchronized with the Integrated/Unified Power System (IPS/UPS), which includes the Russian grid, and the IPS/UPS provides frequency regulation and system security within the Baltic states. Since joining the European Union (EU) in 2004, the Baltic states have been following the EU’s energy policy targets. The Baltics are presently participating in a European electricity market, i.e., the NordPool market, while they are expected to join the pan-European electricity market—the European target model for power market integration. Moreover, from a power grid perspective, EU energy policies intend to desynchronize the power grid of the Baltic states from the IPS/UPS over the coming years. This paper evaluates these policy trends through market impacts, and it complements existing studies on Baltic-IPS/UPS desynchronization in terms of wholesale electricity prices, generation surpluses, primary reserve adequacy, and redispatch costs. Participation of the Baltic states in the integrated pan-European day-ahead electricity market with zonal pricing was modeled for 2030, followed by a national redispatch, with detailed power grid modeling of Baltic states to solve potential intrazonal congestion. The simulation results imply the superiority of the Baltics’ synchronization to continental Europe, compared to the other schemes.

ACS Style

Ettore Bompard; Shaghayegh Zalzar; Tao Huang; Arturs Purvins; Marcelo Masera. Baltic Power Systems’ Integration into the EU Market Coupling under Different Desynchronization Schemes: A Comparative Market Analysis. Energies 2018, 11, 1945 .

AMA Style

Ettore Bompard, Shaghayegh Zalzar, Tao Huang, Arturs Purvins, Marcelo Masera. Baltic Power Systems’ Integration into the EU Market Coupling under Different Desynchronization Schemes: A Comparative Market Analysis. Energies. 2018; 11 (8):1945.

Chicago/Turabian Style

Ettore Bompard; Shaghayegh Zalzar; Tao Huang; Arturs Purvins; Marcelo Masera. 2018. "Baltic Power Systems’ Integration into the EU Market Coupling under Different Desynchronization Schemes: A Comparative Market Analysis." Energies 11, no. 8: 1945.

Journal article
Published: 19 June 2018 in Energies
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Following restructuring of power industry, electricity supply to end-use customers has undergone fundamental changes. In the restructured power system, some of the responsibilities of the vertically integrated distribution companies have been assigned to network managers and retailers. Under the new situation, retailers are in charge of providing electrical energy to electricity consumers who have already signed contract with them. Retailers usually provide the required energy at a variable price, from wholesale electricity markets, forward contracts with energy producers, or distributed energy generators, and sell it at a fixed retail price to its clients. Different strategies are implemented by retailers to reduce the potential financial losses and risks associated with the uncertain nature of wholesale spot electricity market prices and electrical load of the consumers. In this paper, the strategic behavior of retailers in implementing forward contracts, distributed energy sources, and demand-response programs with the aim of increasing their profit and reducing their risk, while keeping their retail prices as low as possible, is investigated. For this purpose, risk management problem of the retailer companies collaborating with wholesale electricity markets, is modeled through bi-level programming approach and a comprehensive framework for retail electricity pricing, considering customers’ constraints, is provided in this paper. In the first level of the proposed bi-level optimization problem, the retailer maximizes its expected profit for a given risk level of profit variability, while in the second level, the customers minimize their consumption costs. The proposed programming problem is modeled as Mixed Integer programming (MIP) problem and can be efficiently solved using available commercial solvers. The simulation results on a test case approve the effectiveness of the proposed demand-response program based on dynamic pricing approach on reducing the retailer’s risk and increasing its profit.

ACS Style

Mahmood Hosseini Imani; Shaghayegh Zalzar; Amir Mosavi; Shahaboddin Shamshirband. Strategic Behavior of Retailers for Risk Reduction and Profit Increment via Distributed Generators and Demand Response Programs. Energies 2018, 11, 1602 .

AMA Style

Mahmood Hosseini Imani, Shaghayegh Zalzar, Amir Mosavi, Shahaboddin Shamshirband. Strategic Behavior of Retailers for Risk Reduction and Profit Increment via Distributed Generators and Demand Response Programs. Energies. 2018; 11 (6):1602.

Chicago/Turabian Style

Mahmood Hosseini Imani; Shaghayegh Zalzar; Amir Mosavi; Shahaboddin Shamshirband. 2018. "Strategic Behavior of Retailers for Risk Reduction and Profit Increment via Distributed Generators and Demand Response Programs." Energies 11, no. 6: 1602.

Conference paper
Published: 01 June 2018 in 2018 IEEE International Conference on Environment and Electrical Engineering and 2018 IEEE Industrial and Commercial Power Systems Europe (EEEIC / I&CPS Europe)
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The existing electricity market designs may be not compatible with high penetration of Variable Renewable Energy Sources (VRE) in power systems and need to be improved to address VREs' variability and uncertainty. VREs require flexibility and additional reserve capacities from conventional power plants to offset their real-time deviation from the forecasted output power. Another important issue regarding VRE market participation is the relatively low market clearing prices which in turn threatens the profitability of conventional generators. To address these issues, this paper contributes in modelling a central framework to provide uncertainty reserve service which is simultaneously optimized with energy procurement in day-ahead market. The uncertainty reserve is remunerated through day-ahead reservation price and real-time activation price. The proposed market clearing mechanism is able to provide fair and competitive supplementary revenue stream for conventional generators, while it ensures adequate reserve capacities in an hourly basis, taking into account network constraints, to address VRE variability and uncertainty.

ACS Style

Shaghayegh Zalzar; Ettore Bompard. A Day-Ahead Joint Energy and Uncertainty Reserve Market Clearing Model to Manage VRE Uncertainty. 2018 IEEE International Conference on Environment and Electrical Engineering and 2018 IEEE Industrial and Commercial Power Systems Europe (EEEIC / I&CPS Europe) 2018, 1 -5.

AMA Style

Shaghayegh Zalzar, Ettore Bompard. A Day-Ahead Joint Energy and Uncertainty Reserve Market Clearing Model to Manage VRE Uncertainty. 2018 IEEE International Conference on Environment and Electrical Engineering and 2018 IEEE Industrial and Commercial Power Systems Europe (EEEIC / I&CPS Europe). 2018; ():1-5.

Chicago/Turabian Style

Shaghayegh Zalzar; Ettore Bompard. 2018. "A Day-Ahead Joint Energy and Uncertainty Reserve Market Clearing Model to Manage VRE Uncertainty." 2018 IEEE International Conference on Environment and Electrical Engineering and 2018 IEEE Industrial and Commercial Power Systems Europe (EEEIC / I&CPS Europe) , no. : 1-5.

Article
Published: 26 September 2016 in International Transactions on Electrical Energy Systems
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In this paper an efficient algorithm for simultaneous scheduling of energy and primary reserve with the presence of smart electric vehicles in the system is discussed. It is proposed that the system operator uses the electric vehicles (EVs) as alternative resources of primary reserve in the power system. The proposed model deals with the effect of generation scheduling on the EV charging schedules and primary reserve capacities. In fact, the amount of primary reserve provided by EVs is highly related to the EV's charging schedules. Therefore, in this paper a smart charging algorithm is also proposed that is based on direct load control of EVs by the system operator. The proposed scheme would be applicable with the lowest intelligence level and will not impose extra investment cost to the EV owners. All the nonlinear constraints included in the primary reserve scheduling are linearized to be solvable by mixed integer linear programming method. A case study on IEEE RTS79 system with 30% EV penetration is used to illustrate the feasibility and acceptable performance of the proposed method. The influence of EVs' participation on operation costs, load curve, and EV bills is discussed.

ACS Style

Shaghayegh Zalzar; Mohammad-Agha Shafiyi; Arzhang Yousefi-Talouki; Mohammad-Sadegh Ghazizadeh. A smart charging algorithm for integration of EVs in providing primary reserve as manageable demand-side resources. International Transactions on Electrical Energy Systems 2016, 27, e2283 .

AMA Style

Shaghayegh Zalzar, Mohammad-Agha Shafiyi, Arzhang Yousefi-Talouki, Mohammad-Sadegh Ghazizadeh. A smart charging algorithm for integration of EVs in providing primary reserve as manageable demand-side resources. International Transactions on Electrical Energy Systems. 2016; 27 (4):e2283.

Chicago/Turabian Style

Shaghayegh Zalzar; Mohammad-Agha Shafiyi; Arzhang Yousefi-Talouki; Mohammad-Sadegh Ghazizadeh. 2016. "A smart charging algorithm for integration of EVs in providing primary reserve as manageable demand-side resources." International Transactions on Electrical Energy Systems 27, no. 4: e2283.