Short-term hydro scheduling and hydro unit commitment of pumped storage hydropower plant with multiple variable-speed units
The increasing need for flexible resources in power systems with high renewable penetra- tion motivates exploring how variable-speed technology can enhance the flexibility and efficiency of Pumped Storage Hydropower (PSH) plants by allowing continuous power regulation in pumping mode. This thesis ad...
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| Tipo de recurso: | tesis de maestría |
| Fecha de publicación: | 2025 |
| País: | España |
| Institución: | Universitat Politècnica de Catalunya (UPC) |
| Repositorio: | UPCommons. Portal del coneixement obert de la UPC |
| OAI Identifier: | oai:upcommons.upc.edu:2117/441725 |
| Acceso en línea: | https://hdl.handle.net/2117/441725 |
| Access Level: | acceso embargado |
| Palabra clave: | Nonlinear programming Electric power Water-power Pumped storage hydropower (PSH), Variable-speed, short-term hydro scheduling (STHS), Hydro unit commitment (HUC), Nonlinear programming (NLP), Mixed-integer linear programming (MILP), Electricity markets Programació no lineal Energia elèctrica Energia hidràulica Àrees temàtiques de la UPC::Energies |
| Sumario: | The increasing need for flexible resources in power systems with high renewable penetra- tion motivates exploring how variable-speed technology can enhance the flexibility and efficiency of Pumped Storage Hydropower (PSH) plants by allowing continuous power regulation in pumping mode. This thesis addresses the Short-Term Hydro Scheduling (STHS) and Hydro Unit Commitment (HUC) problems for a PSH plant with multiple variable-speed units. The proposed two-stage methodology includes a Nonlinear Pro- gramming (NLP) formulation for plant-level STHS, followed by a Mixed-Integer Linear Programming (MILP) HUC model. A key contribution is the exploitation of the fact that the presence of variable-speed units creates a continuous region of head and power combinations where the plant can operate at nearly constant and maximum overall efficiency. This justifies using an aggregated plant-based model in the STHS, allowing for the explicit treatment of nonlinear hydraulic characteristics while avoiding the complexity associated with binary variables. Crucially, this decomposition enables the inclusion of technical and operational features that would otherwise result in a large and computationally demanding single optimiza- tion problem. In particular, the HUC model introduces an innovative layer of operational decision-making by considering each unit’s operating mode (turbine or pump, fixed or variable-speed) as decision variables, capturing the trade-off between efficiency and flex- ibility when using full power converters (FPC). However, the decomposition introduces some loss of accuracy, especially in representing spinning reserves and participation in secondary regulation markets. The models are validated using fictitious data inspired by realistic PSH plants in Spain. The results confirm the validity of the methodology and its potential to enhance opera- tional flexibility in future grid scenarios. |
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