The 2024 Africa Cup of Nations (AFCON) in Côte d’Ivoire highlighted the substantial energy demands of major sporting events, traditionally met by conventional, and nonrenewable sources. This study investigates the technoeconomic feasibility and environmental benefits of integrating solar and wind energy systems into the six stadiums used for the 2024 AFCON to enhance sustainability, long‐term economic benefits, and reduced carbon emissions. Utilizing the hybrid optimization of multiple electric renewables (HOMER) software for simulation and optimization, and the engineering equation solver for mathematical modeling, this study assesses the energy demand and potential renewable energy contributions for stadiums in Abidjan, Yamoussoukro, Bouaké, Korhogo, and San Pedro. The findings reveal that grid purchases dominate the energy mix across all cities, with varying contributions from solar and wind energy. Abidjan achieves 20.1% renewable energy penetration, while San Pedro reaches 69.9%. The proposed hybrid renewable energy systems offer substantial economic benefits, including payback periods of less than 2 years and high internal rates of return (IRR), with surplus energy generated in some locations potentially sold back to the grid. Additionally, the environmental impact assessment indicates an estimated annual CO ₂ reduction of 6518.25 metric tonnes cumulatively, equivalent to planting ~2.17 million trees over 20 years. This study provides a detailed technoeconomic analysis, demonstrating the viability of hybrid wind–solar systems in large sports venues and contributing valuable insights for future implementations of renewable energy technologies in the sports infrastructure sector.

This work estimates the annual energy that could be generated from a concentrated solar power (CSP) plant. The optimal location used for this analysis was selected based on a set of multicriteria decision-making (MCDM) methods employed in an earlier research. The paper also determines the financial viability of implementing a CSP plant within the selected location. A 100 MW CSP plant for the said location was modelled and simulated using the System Advisor Model (SAM) software with data from the online database of the National Renewable Energy Lab (NREL) available from the SAM software. Using a solar multiple of 2.0 with a TES of 6 hours, the plant generated an estimated annual energy of 306.850 GWh with a capacity factor of 35.10% and gross-to-net conversion of 89.10%. The months with the highest generation were from November to March while July to September had the least generation. Generation begins from 8 am, rising to a peak around 12 pm to 4 pm and gradually declines into the night. Results from the financial analysis produced a net present value (NPV) of USD 156,287,433.72 after the plant life of 25 years, indicating profitability of the project. Results from the sensitivity analysis showed that the project NPV became negative only when the base case capital cost, electricity price, and revenue were, respectively, increased by 15%, reduced by 10%, and reduced by 13%.