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Annual Assessment of Large-Scale Introduction of Renewable Energy: Modeling of Unit Commitment Schedule for Thermal Power Generators and Pumped Storages

Author

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  • Takashi Mitani

    (Institute of Innovative Research, Tokyo Institute of Technology, Tokyo 152-8550, Japan)

  • Muhammad Aziz

    (Institute of Innovative Research, Tokyo Institute of Technology, Tokyo 152-8550, Japan)

  • Takuya Oda

    (Institute of Innovative Research, Tokyo Institute of Technology, Tokyo 152-8550, Japan)

  • Atsuki Uetsuji

    (Institute of Innovative Research, Tokyo Institute of Technology, Tokyo 152-8550, Japan)

  • Yoko Watanabe

    (Institute of Innovative Research, Tokyo Institute of Technology, Tokyo 152-8550, Japan)

  • Takao Kashiwagi

    (Institute of Innovative Research, Tokyo Institute of Technology, Tokyo 152-8550, Japan)

Abstract

The fast-increasing introduction of renewable energy sources (RESes) leads to some problems in electrical power network due to fluctuating generated power. A power system must be operated with provision of various reserve powers like governor free capacity, load frequency control and spinning reserve. Therefore, the generator’s schedule (unit commitment schedule) should include the consideration of the various power reserves. In addition, it is necessary to calculate the annual operational costs of electric power systems by solving the unit commitment per week of thermal power generators and pumped storages in order to compare and examine the variance of the operational costs and the operating ratio of the generators throughout the year. This study proposes a novel annual analysis for the thermal power generator and pumped storages under a massive introduction of RESes. A weekly unit commitment schedule (start/stop planning) for thermal power generator and pumped storages has been modeled and calculated for one year evaluation. To solve the generator start/stop planning problem, Tabu search and interior point methods are adopted to solve the operation planning for thermal power generators and the output decision for pumped storages, respectively. It is demonstrated that the proposed method can analyze a one-year evaluation within practical time. In addition, by assuming load frequency control (LFC) constraints to cope with photovoltaic ( PV ) output fluctuations, the impact of the intensity of LFC constraints on the operational cost of the thermal power generator has been elucidated. The increment of the operational cost of the power supply with increasing PV introduction amount has been shown in concrete terms.

Suggested Citation

  • Takashi Mitani & Muhammad Aziz & Takuya Oda & Atsuki Uetsuji & Yoko Watanabe & Takao Kashiwagi, 2017. "Annual Assessment of Large-Scale Introduction of Renewable Energy: Modeling of Unit Commitment Schedule for Thermal Power Generators and Pumped Storages," Energies, MDPI, vol. 10(6), pages 1-19, May.
    • Handle: RePEc:gam:jeners:v:10:y:2017:i:6:p:738-:d:99385
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    References listed on IDEAS

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    Cited by:

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    2. Muhammad Huda & Tokimatsu Koji & Muhammad Aziz, 2020. "Techno Economic Analysis of Vehicle to Grid (V2G) Integration as Distributed Energy Resources in Indonesia Power System," Energies, MDPI, vol. 13(5), pages 1-16, March.
    3. Tianyao Zhang & Diyi Chen & Jing Liu & Beibei Xu & Venkateshkumar M, 2020. "A Feasibility Analysis of Controlling a Hybrid Power System over Short Time Intervals," Energies, MDPI, vol. 13(21), pages 1-21, October.
    4. Michel Noussan & Roberta Roberto & Benedetto Nastasi, 2018. "Performance Indicators of Electricity Generation at Country Level—The Case of Italy," Energies, MDPI, vol. 11(3), pages 1-14, March.
    5. Hsin-Wei Chiu & Le-Ren Chang-Chien & Chin-Chung Wu, 2021. "Construction of a Frequency Compliant Unit Commitment Framework Using an Ensemble Learning Technique," Energies, MDPI, vol. 14(2), pages 1-19, January.
    6. Marcin Szott & Szymon Wermiński & Marcin Jarnut & Jacek Kaniewski & Grzegorz Benysek, 2021. "Battery Energy Storage System for Emergency Supply and Improved Reliability of Power Networks," Energies, MDPI, vol. 14(3), pages 1-21, January.
    7. Lu, Mengke & Guan, Jun & Wu, Huahua & Chen, Huizhe & Gu, Wei & Wu, Ye & Ling, ChengXiang & Zhang, Linqiang, 2022. "Day-ahead optimal dispatching of multi-source power system," Renewable Energy, Elsevier, vol. 183(C), pages 435-446.
    8. Ibrahim Ahmad & Ghaeth Fandi & Zdenek Muller & Josef Tlusty, 2019. "Voltage Quality and Power Factor Improvement in Smart Grids Using Controlled DG Units," Energies, MDPI, vol. 12(18), pages 1-18, September.
    9. Lei Zhang & Jian Zhang & Xiaodong Yu & Jiawen Lv & Xiaoying Zhang, 2019. "Transient Simulation for a Pumped Storage Power Plant Considering Pressure Pulsation Based on Field Test," Energies, MDPI, vol. 12(13), pages 1-16, June.

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