Browsing by Autor "Marco Navia"

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Bolivian interconnected power system
(2022) Marco Navia; R Lafuente; Sergio Balderrama; Sylvain Quoilin
Comparative Analysis of Dynamic and Linear Programming Energy Systems Models Applied to the Bolivian Power System
(2023) Alizon Huallpara; Marco Navia; Isaline Gomand; Sergio Balderrama; Matija Pavičević; Sylvain Quoilin
Energy system models are indispensable tools for energy planning and decision making. They identify the most cost-effective way of delivering energy to the final consumer. No one tool that addresses all the energy systemrelated issues. Every model has its own strengths and limitations and serves a different purpose. This paper aims to compare the capabilities of two different model formulations to model both the hydro scheduling and the short-term dispatch problems in hydro-dominated power systems. On the one hand, SDDP, a commercial model for hydrothermal generation scheduling with a representation of the transmission network, has been used by the Bolivian system operator for dispatch simulations. Conversely, Dispa-SET, an open-source unit commitment and economic dispatch model with mid-term hydrothermal coordination capability, has been used previously in several Bolivian case studies. In this paper, both models were applied to the same input dataset of the Bolivian electric system considering probabilistic results for 43 weather years from 1984 to 2021. SDDP optimizes the system under all weather years, while Dispa-SET optimises under one full year, for which 43 runs were made. The results show that SDDP generation, reservoir level and spillage fall into the ranges of Dispa-SET results. Some differences that are present mainly lie in the conceptualization of the methods of both models. SDDP prioritizes the dispatch of hydro units, while Dispa-SET, with a higher temporal and technical resolution, maximizes the use of non-dispatchable units such as variable renewables and run-of-river.
Energy Transition Planning with High Penetration of Variable Renewable Energy in Developing Countries: The Case of the Bolivian Interconnected Power System
(Multidisciplinary Digital Publishing Institute, 2022) Marco Navia; Renán A. Orellana; Sulmayra Zaráte; Mauricio Villazón; Sergio Balderrama; Sylvain Quoilin
The transition to a more environmentally friendly energy matrix by reducing fossil fuel usage has become one of the most important goals to control climate change. Variable renewable energy sources (VRES) are a central low-carbon alternative. Nevertheless, their variability and low predictability can negatively affect the operation of power systems. On this issue, energy-system-modeling tools have played a fundamental role. When exploring the behavior of the power system against different levels of VRES penetration through them, it is possible to determine certain operational and planning strategies to balance the variations, reduce the operational uncertainty, and increase the supply reliability. In many developing countries, the lack of such proper tools accounting for these effects hinders the deployment potential of VRES. This paper presents a particular energy system model focused on the case of Bolivia. The model manages a database gathered with the relevant parameters of the Bolivian power system currently in operation and those in a portfolio scheduled until 2025. From this database, what-if scenarios are constructed allowing us to expose the Bolivian power system to a set of alternatives regarding VRES penetration and Hydro storage for that same year. The scope is to quantify the VRES integration potential and therefore the capacity of the country to leapfrog to a cleaner and more cost-effective energy system. To that aim, the unit-commitment and dispatch optimization problem are tackled through a Mixed Integer Linear Program (MILP) that solves the cost objective function within its constraints through the branch-and-cut method for each scenario. The results are evaluated and compared in terms of energy balancing, transmission grid capability, curtailment, thermal generation displacement, hydro storage contribution, and energy generation cost. In the results, it was found that the proposed system can reduce the average electricity cost down to 0.22 EUR/MWh and also reduce up to 2.22 × 106 t (96%) of the CO2 emissions by 2025 with very high penetration of VRES but at the expense of significant amount of curtailment. This is achieved by increasing the VRES installed capacity to 10,142 MW. As a consequence, up to 7.07 TWh (97%) of thermal generation is displaced with up to 8.84 TWh (75%) of load covered by VRES.