期刊
APPLIED ENERGY
卷 309, 期 -, 页码 -出版社
ELSEVIER SCI LTD
DOI: 10.1016/j.apenergy.2021.118467
关键词
Hydro-wind-PV complementary system; Day-ahead generation scheduling; Operational risks; Power delivery requirement; Multi-objective optimization
资金
- National Natural Science Founda-tion of China [52009098, U1965202]
- Postdoctoral Innovative Talent Foundation of China [BX20200276]
- Postdoctoral Science Foundation of China [2020M673453]
- Natural Science Foundation of Shaanxi Provincial Education Department, China [20JK0806]
- China Three Gorges Corporation Research Project [202103528]
This study proposes a risk-averse day-ahead generation scheduling approach for hydro-wind-photovoltaic complementary systems (HWPCSs). By considering the steady requirement of power delivery and forecast uncertainties, the proposed approach can significantly reduce the comprehensive risk and improve power transmission efficiency.
Optimizing day-ahead generation schedules of hydro-wind-photovoltaic (PV) complementary systems (HWPCSs) can help to promote the accommodation of wind and solar energies. However, it is challenging to formulate appropriate generation schedules for the large HWPCS that contains cascade hydropower plants, in particular, a steady requirement of power delivery is considered in the optimization model. To further improve complementary performance of the large HWPCS, we propose a risk-averse day-ahead generation scheduling approach that considers the steady requirement of power delivery. First, a representative scenario set is used to characterize forecast uncertainties of the wind and PV power. Then, a multi-objective optimal generation scheduling model with consideration of the operational risks of electricity curtailment and power shortage is proposed. Finally, a two-layer nested optimization framework is designed to derive the system's generation schedule. The clean energy base in the upper Yellow River basin, China was selected as a case study. The results show that: (1) forecast uncertainties of wind and PV power are more likely to induce power shortage risk in summer and autumn, but to induce electricity curtailment risk in spring and winter; (2) without using extra constraint handling strategies, the proposed approach could directly yield a stair-shaped power delivery curve, which is good for long-distance power transmission applications; and (3) compared with a traditional method without considering the operational risks, the proposed generation scheduling approach could significantly reduce the comprehensive risk rate by 65% on average, while the cascade hydropower production and peak shaving performance are satisfactory. Therefore, the proposed approach is effective in guiding the day-ahead generation scheduling of the HWPCSs that contain cascade hydropower plants.
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