Day-ahead optimal dispatching of multi-source power system. (January 2022)

• Record Type: Journal Article
• Authors: Lu, Mengke; Guan, Jun; Wu, Huahua; Chen, Huizhe; Gu, Wei; Wu, Ye; Ling, ChengXiang; Zhang, Linqiang
• Is Part Of: Renewable energy. Volume 183(2022)
• Page Start: 435
• Page End: 446
• Publication Date: 2022-01
• Subjects: Power system -- Optimal dispatch -- Cascade hydropower system -- Pumped storage -- Renewable energy resources; Renewable energy sources -- Periodicals; Power resources -- Periodicals; Énergies renouvelables -- Périodiques; Ressources énergétiques -- Périodiques; 333.794
• DOI: 10.1016/j.renene.2021.10.093
• Languages: English
• ISSNs: 0960-1481

Abstract

Abstract: In this paper, the day-ahead optimal dispatching model of power system that is combined by wind-photovoltaic-hydropower-thermal-pumped storage is established. Firstly, according to the characteristics of the short-term hydropower system dispatching problem, a new mathematical model of the cascade hydropower group system with pumped storage power stations is proposed. The coordinated optimized dispatching model of the hydropower group system formed by the cascading of pumped storage power plants and conventional hydropower in the power system is studied. Secondly, the opportunity constraint programming model of forecast error reserve is used to deal with the output uncertainty of wind power and photovoltaic. The randomness and intermittency of renewable energy on the stability of the power system are overcame by the combination of wind-photovoltaic-pumped storage. Thirdly, the model for the joint optimal dispatch of short-term wind, photovoltaic, hydropower and thermal power systems with pumped storage is developed with system economics as the goal. Fourthly, the operation volatility coefficient of thermal power units is proposed to study the impact of renewable energy on the operation of thermal power. Finally, an example system is used to verify the correctness of the proposed dispatching optimal scheduling model, and the results prove that the daily dispatch optimization model proposed in this paper can increase the economic efficiency of the power system by 5%, reduce the start-stop times of thermal power units by 36.55%, and reduce the fluctuation coefficient of the unit by 2.8. Highlights: A new mathematical model of the cascade hydropower group system is proposed. The integral flow constraint of lag time in the daily scheduling is considered. The operation volatility coefficient of thermal power units is proposed.