This paper examines the possibility of adding a photovoltaic(PV) power station to an already planned wind park in terms of profitability. At this time, southern Sweden’s grid is facing a number of challenges and is hurting economic development. Hybrid parks have showed to be able to tackle some of those challenges. This study has used a two-scaled methodology to analyse which solar PV size is the optimal to be co-located to the wind park of 24MW[Office1] . The results show that the 21MW size is the ideal one. In addition, to complement the findings, an analysis has been conducted to determine which battery size would be the optimal size to be added to the hybrid system. The results showed that a 1MW/1MWh battery storage would be the ideal size, however, it is possible that a 5MW/MWh battery storage might produce better results if peak shaving is included. All the scenarios in this study have been analysed in terms of IRR.

Wind resources are highly intermittent and fluctuant, making wind turbines less reliable and the unstable power output will affect grid stability and security. This paper presents an idea of integrating the solar PV plant and energy storage system into an existing wind project, project Rödene in Gothenburg. The hybrid renewable system, which consists of two or more renewable energy sources, is considered the renewable energy development trend. An economic analysis of a 1.2 MW PV plant, 5 MW lithium-ion battery storage system and 300 kg hydrogen fuel cell storge system are assessed in terms of LCOE and LCOS of plants. The revenue stream is discussed separately, consisting of electricity tariff, ancillary services and energy arbitrage. The results show that both PV plant and energy store systems are unprofitable. When the PV panel cost is reduced more than 30% and the annual production increases at least 30%, the LCOE of the PV plant arrives at the break-even point. Also result shows the hydrogen fuel cell energy storage system is too expensive of commercial use, and the battery energy storage system has a high potential of profitable if the ancillary service in Sweden is well organized in the future

Yes / The cost of electricity produced by thermal power plants in Republic of Djibouti is relatively high at about $0.32/ kWh. This is due to its dependence on imported oil coupled with fluctuating oil prices. Consequently, the customer pays a high electricity bill. However, Djibouti is endowed with indigenous renewable energy resources such as a good solar irradiance of 5.92 kWh/ m2 day, a potential geothermal energy estimated up to 1000 MW, and few sites with annual wind speed higher than 6 m/s. The goal of this paper is, therefore, to assess an economic evaluation of different grid connected hybrid renewable energy systems to a residential urban house located in Tadjourah city (11.7913◦ N, 42.8796◦ E) in the North-Eastern part of Djibouti to reduce the cost of electricity from the grid. To reach this objective, a powerful software tool called HOMER (Hybrid Optimization Model for Electric Renewables) has been used to find the optimum hybrid energy system using real wind and solar irradiation data. The results obtained from this study show that the best economical suited combination of hybrid renewable energy system is a PV-Wind grid connected system. This study shows also that potentially the indigenous renewable energy contribution, in Tadjourah, can be as much as 77 % with 47 % of solar and 30% of Wind energy. The Net Present Cost, the Levelized Cost of Energy, and the operating cost of the optimal HRES are $337, $0.002/kWh and $1,025/year, respectively. When compared with the average cost of grid-only connection of $0.32/kWh, the optimal hybrid renewable energy system is more economical and will save 51 % of the cost that the customer must pay when using only the electricity from the grid.

Urban areas house most of the global population and are also responsible for large shares of global greenhouse gas emissions. Cities and municipalities thus play a significant role in modern society to achieve an energy transition to renewable energy sources and to adapt to climate change. Achieving such a transition is a difficult process due to the high energy density and complexity of urban multi-energy systems. This is further exacerbated by the adverse effect future climate hazards will likely have on urban infrastructure. Despite this, energy development and climate adaptation plans are often researched and drafted in a disjointed manner. In many instances, future energy strategies do not consider climate impacts, whereas climate adaptation tactics disregard energy production. This study proposed that such mutually exclusive analysis and decision-making increases the vulnerability of planned and optimised future urban energy systems. Investigating the Swedish municipality Malmö, the study focused on achieving a future energy transition in its electricity network and then considering potential climate change impacts. Current urban energy plans and capacity were used to forecast the renewable energy potential for 2030 in Malmö’s geographical area. This formed the basis for modelling an optimised hybrid renewable energy system for the municipality using HOMER Grid. Based on future climate data and Malmö’s climate adaptation plans, this system was then evaluated in terms of impacts from climate hazards. The results indicated that Malmö’s current energy plans would expose a large share of their energy infrastructure to risk of damage from climate hazards. Thus, the vulnerability of the optimised energy system is indeed heightened when disregarding climate change impacts in the planning phase. If climate change and energy transition strategies are developed conjointly, urban energy system resilience could likely be increased significantly.