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Stochastic optimization model for the weekly scheduling of a hydropower system in day-ahead and secondary regulation reserve markets
dc.contributor.author | Chazarra Jover, Manuel | es-ES |
dc.contributor.author | García González, Javier | es-ES |
dc.contributor.author | Pérez-Díaz, Juan I. | es-ES |
dc.contributor.author | Arteseros, Montserrat | es-ES |
dc.date.accessioned | 2016-01-15T11:14:22Z | |
dc.date.available | 2016-01-15T11:14:22Z | |
dc.date.issued | 2016-01-01 | es_ES |
dc.identifier.issn | 0378-7796 | es_ES |
dc.identifier.uri | https:doi.org10.1016j.epsr.2015.08.014 | es_ES |
dc.description | Artículos en revistas | es_ES |
dc.description.abstract | es-ES | |
dc.description.abstract | Hydropower stands out for its fast response ability and flexible operation, playing a predominant role in the provision of regulation reserves. As hydro power is an energy-constrained generation technology, it needs to be protected against any possible deployment of the scheduled reserves. However, the few models that formulate a detailed hourly co-optimization of energy and regulation reserves, neglect infeasibilities that could be derived from the requested reserves in real-time. As the regulation reserve market is becoming increasingly important, hydro producers can no longer neglect such effect. This paper presents a stochastic optimization model to find the optimal hourly schedule of a set of hydraulically coupled hydropower plants to obtain the weekly operation that simultaneously maximizes the expected profit in both energy and regulation reserves markets. The model is formulated for a price-taker agent, and it considers a very detailed representation of the system including minimum-maximum water flows, net head dependency, and fractional water travel time. The main contribution is that the obtained solution protects a multi-reservoir system against risk of water and storage unavailability due to the uncertainty in real-time use of regulation-up and down reserves, respectively, and that the reserves deem the net head dependency. The paper presents a realistic case study where the proposed formulation has been tested successfully with real data from the Spanish electricity market. | en-GB |
dc.format.mimetype | application/pdf | es_ES |
dc.language.iso | en-GB | es_ES |
dc.rights | es_ES | |
dc.rights.uri | es_ES | |
dc.source | Revista: Electric Power Systems Research, Periodo: 1, Volumen: online, Número: , Página inicial: 67, Página final: 77 | es_ES |
dc.subject.other | Instituto de Investigación Tecnológica (IIT) | es_ES |
dc.title | Stochastic optimization model for the weekly scheduling of a hydropower system in day-ahead and secondary regulation reserve markets | es_ES |
dc.type | info:eu-repo/semantics/article | es_ES |
dc.description.version | info:eu-repo/semantics/publishedVersion | es_ES |
dc.rights.accessRights | info:eu-repo/semantics/restrictedAccess | es_ES |
dc.keywords | es-ES | |
dc.keywords | Day-ahead electricity market; Secondary regulation reserve market; Stochastic programming; Cascaded reservoir system | en-GB |
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