A fondo: Análisis 2018 | In depth: 2018 Analysis www.futurenergyweb.es 30 FuturEnergy | Diciembre 2018-Enero 2019 December 2018-January 2019 cano, y que resulta más adecuado para una eventual traslación a nuestro país, ha sido el de los 700 MW termosolares de Dubái, ya que el nivel de radiación directa anual (DNI) en Dubái es muy similar a la del sur de nuestro país, donde la electricidad será vendida a un precio de unos 7 c€/kWh. Inicialmente se solicitaron 200MWde potencia, que se ampliaron a 700 MW tras comparar estos precios con los de ciclos combinados. Las ofertas iniciales habían sido aportadas por varios consorcios internacionales de reconocida solvencia, liderados por ACWA, EDF y ENGIE respectivamente (desgraciadamente los recortes en nuestro país cercenaron las posibilidades de que nuestras empresas volvieran a actuar como promotores), con un perfil de despacho como el que recomienda Protermosolar en su informe de transición del sector eléctrico al que posteriormente nos referiremos. La necesidad de satisfacer la demanda a partir de la puesta del sol, como ocurrirá más pronto que tarde en otros muchos países, entre ellos España, motivó la petición de ofertas para suministrar electricidad desde las últimas horas de sol en la tarde hasta el amanecer del día siguiente. No se recibió ninguna oferta de centrales fotovoltaicas de dicho tamaño con 12 h de almacenamiento, porque dicho producto ni existe ni, a juicio de los expertos, se le espera. Al comparar el coste ofertado por las centrales termosolares con el de nuevos ciclos combinados a gas se pudo comprobar que la termosolar ofrecía mejores precios y sin incertidumbres, por lo que la decisión fue obvia. También en Australia y en Chile se han podido comparar ya los costes de centrales termosolares con gran volumen de almacenamiento con los ciclos combinados con resultados favorables. En el caso de Chile, los proyectos no fueron aprobados por otros motivos, pero en Australia se adjudicó un proyecto de 150 MW de central de torre con 8 h de almacenamiento. La buena noticia en Chile es la reanudación de la construcción de la central de Cerro Dominador, en Atacama, suspendida hace algo más de un año por la situación económica de Abengoa, que ha sido adjudicada ahora a un consorcio formado por la propia Abengoa y Acciona. La central termosolar de torre tiene 110 MW de potencia con 17,5 h de almacenamiento y se complementa con una central fotovoltaica de 100 MW, suministrando 24 horas al día al sector minero de Atacama, cuyos consumos son prácticamente constantes día y noche. La complementariedad entre la tecnología termosolar y la fotovoltaica se va revelando como una tendencia, bien sea en unidades de negocio integradas, como el citado proyecto en el desierto de Atacama, o los dos proyectos que se adjudicarán dentro de pocas semanas en of this type of tower plants with a molten salt receiver. But this year has also been very important sector due to the cost references achieved in different international tenders. The closest to home and the one that is the most appropriate for an eventual transfer to Spain has been the 700 MW CSP plant in Dubai, given that the direct normal irradiance (DNI) of Dubai is very similar to that of southern Spain, where electricity will be sold at a price of around 0.7 €/ kWh. 200 MW of capacity was initially requested, later extended to 700 MW having compared these prices with those of combined cycles. Initial tenders had been submitted by several international consortia with recognised solvency, headed up by ACMA, EDF and ENGIE respectively (unfortunately the cuts in Spain curtailed the prospect of Spanish companies returning to their role as developers), with a dispatch profile such as the one recommended by Protermosolar in its power sector transition report that will be mentioned below. The need to cover demand after sunset, which takes place earlier rather than later in many other countries, including in Spain, lead to the request for tenders to supply electricity from the last hours of sunshine in the afternoon until dawn the following day. No tender was received from PV plants of such a size with 12 hours of storage, because this product neither exists nor, in the opinion of experts, was expected. By comparing the cost offered by the CSP plants with that of new gas combined cycles, it was shown that CSP would offer better prices, without uncertainties, leaving no doubt over the decision to take. It has already been possible to compare the costs of CSP plants in Australia and Chile that have a high storage volume with those of combined cycles - achieving favourable results. Although in the case of Chile, projects were not approved due to other reasons, a 150 MW tower plant project with 8 hours of storage was awarded in Australia. The good news in Chile is resumption of the construction of the Cerro Dominador plant in Atacama, suspended just over a year ago due to the financial situation of Abengoa. The work has now been awarded to a consortiummade up of by Abengoa itself and Acciona. The tower CSP plant has a capacity of 110 MW with 17.5 hours of storage, complemented by a 100 MW PV plant, providing the Atacama mining sector, whose consumption is almost constant day and night, with a 24/7 supply. The complementary nature of CSP and PV technology is shown to be a trend: whether in integrated business units, such as the above-mentioned project in the Atacama Desert and the two projects to be awarded in two weeks’ time in Midelt, Morocco, and which will set new price references; and also in independent units, integrated into the electrical system of a country. This combination, in which PV would supply electricity during the day and CSP, helping PV during the last hours of daylight and also generating power during the night, would replace the need for backup from natural gas, reducing emissions and at an average price that cannot be beaten by any other conventional or renewable technology. This complementary generation strategy lies behind the report from Protermosolar entitled “The Power Sector Transition. 2030 Central Ilanga -1 de 100 MW con 5 horas de almacenamiento en Upington, Sudáfrica. Cortesía de Emvelo y Cobra | 100 MW Ilanga I CSP plant with 5 hours of storage in Upington, South Africa. Courtesy of Emvelo and Cobra
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