Brazil’s power market is entering a new phase: distributed solar has scaled to millions of sites, large consumers are increasingly exposed to market price signals and regulators are testing new ways to procure flexibility. Energy management is therefore moving to become a practical tool for cutting costs, managing risk and unlocking new revenue streams. Flexibility is very important in the Brazilian electricity grid: increasing curtailments caused 6,5 billion Brazilian real (about 1,2 billion US dollars) in 2025.
According to the Brazilian Electricity Regulator (ANEEL), distributed photovoltaic (PV) has surpassed 44 gigawatts (GW), with almost 4 million connected systems benefiting over 7 million consumer units. This creates immediate use cases for self-consumption optimization with energy management systems and aggregation of distributed assets.
Brazil’s free power market already offers strong incentives for optimization. The Electricity Market Operator (CCEE) publishes the reference price for every hour of the next day, and prices differ by submarket and region. Electricity can be cheap at some hours and expensive at others, so companies can reduce their bills by shifting flexible loads and limiting peak demand, making energy management software a direct cost lever. The addressable market is significant: by end-2024, the free market counted 64,493 consumer units and accounted for about 39 percent of Brazil’s electricity demand, after 26,834 new migrations in 2024 alone.
In parallel, time-of-use pricing is moving closer to the mass market. ANEEL launched a consultation in late 2025 on automatic Time-of-Use (Tarifa Horária / Tarifa Branca) for low-voltage customers consuming ≥1 megawatt-hour (MWh) per month, with implementation targeted by end-2026.
Demand Response in Brazil has evolved beyond pilots into a structural program, still mainly focused on large consumers in the free market (ACL), with aggregator models explicitly foreseen. In the sandbox run by the National System Operator (ONS) together with CCEE for the “availability” product, contracted capacity rose from 93 megawatts (MW) in 2024 to 229 MW in 2025. In the 2025 competitive mechanism, 229 MW was contracted for five months, with bids up to 32.5 percent below the price cap and an average cost of 1,300 Brazilian real (about 248 US dollars) per MW-day of availability.
Brazil’s strongest near-term energy-management business cases sit where price exposure and flexibility value are already tangible: C&I optimization and automated Demand Response delivery. As time-differentiated tariffs and metering expand, similar control approaches are likely to spread further across buildings and households – broadening the role for aggregators and portfolio-style offerings.