# Renewables and Advanced Storage in Power Systems: The Iberian Case
## 4 Study Case: The Iberian System in 2030 According to the National Energy and Climate Plans (NECPs)  
### Consumption and Cost Data  
Following the request of the European Commission within the Clean Energy for All Europeans package (see [4]), all members of the EU have produced their 10-year National Energy and Climate Plan (NECP) for 2030. Spain [33] and Portugal [34] submitted their plans, with ambitious objectives of 42% and 47%, respectively, of the final energy consumption coming from renewable energy. Table 1 shows the main components of the generation mix in 2019 (2019 has been chosen due to the reduced demand in 2020), with data taken from [35] and the future generation mix in 2030 forecasted by these plans. In the table, combustion fuels for 2019 include coal plants that will be closed by 2030. It is planned that nuclear plants will finish their operation in 2035. The Iberian Peninsula has a large installed pumping hydro capacity, and this capacity will be increased in the next years by converting hydro plants in the same basin into pumping plants by exchanging between upstream and downstream reservoirs. In addition to the National Plan, the Spanish government has published a strategy to facilitate the integration of storage into the power system [36]. The base case patterns used to run the optimization problem utilize the Iberian power system electricity production data for 2017 because it was a very dry year, and this may better reflect future conditions of water stress due to climate change [37]. Data from wind and solar production have been taken to make a normalized production pattern to be scaled according to the final installed power coming from the optimization process. Demand patterns from 2017 have also been scaled to demand forecasted in the NECP for 2030. Hydro inflows have been calculated from the hourly production of hydro plants in both countries and the state of their reservoirs. Data comes from the Transparency Platform of ENTSO-E [35]. The installed renewable power technologies that are not optimized are those planned for 2030. They include the capacity of hydro and pumping plants, run-of-river hydro, concentrated solar power and biomass. The hourly production patterns of these last three technologies were taken from the 2017 data and scaled to the installed power values shown in Table 2. The capacity factor of hydro plants is very low, since 2017 was a very dry year, as already mentioned. Gross demand (including losses) has been considered because this is the energy that must be finally produced and paid for by consumers. To give an idea of the approximation of the copper plate approach followed in the paper, it may be mentioned that congestions between Spain and Portugal take place for less than 5% of the yearly hours and that the energy traded in congestion management in 2019 in both countries was 7621 GWh and that the cost of the remedial actions was 0.99 EUR/MWh for an average day-ahead price of 47.7 EUR/MWh (see [38]). Cost data are taken from references [11; 39; 40] for 2030. Costs of storage are taken from [6] for Li-ion batteries. Fixed costs are annuitized and include both investment and fixed operation and maintenance (O&M). They represent the money per MW of the installed