The issue has gained urgency as energy becomes a determining factor for major investment decisions. Companies developing green fuel plants, data centers and digital services require large volumes of electricity under long-term contracts with predictable pricing. The HIF project for a green fuels facility in Paysandú illustrates the complexity, with negotiations centering on whether state utility UTE would supply electricity at approximately $45 per MWh including grid charges, though final terms for backup costs and transmission infrastructure remained unresolved.
Uruguay’s electricity market has operated under a regulatory framework permitting wholesale contracts between consumers and private generators for over two decades, yet development remains limited. UTE maintains a dominant position while numerous private generators produce under long-term contracts with the state company, restricting opportunities for large consumers to negotiate directly with private suppliers. Alejandro Stipanicic of the Center for Public Policy Studies argues Uruguay should expand space for private generation to compete directly for large consumer contracts while UTE concentrates on transmission network development.
The bottleneck extends to the transmission tariff structure. For competitive markets to function effectively, grid access costs must be reasonable and predictable. Excessive charges can neutralize the competitive advantage from renewable generation itself. The challenge is particularly acute during peak evening demand when solar output declines but consumption for cooling and other services remains elevated, requiring backup from other sources or potentially from battery storage systems that could shift daytime solar production to evening hours.
This article was curated and published as part of our South American energy market coverage.
