Brazil’s Solar Curtailment Compensation Scheme Faces Developer Rejection

Brazil’s Ministry of Mines and Energy issued Ordinance 140 in July, establishing a compensation framework for solar curtailment occurring between September 2023 and November 2025. The rule aims to address financial losses incurred by operators when grid constraints force them to reduce power output.

Despite this regulatory intervention, industry pushback has intensified. According to Saur Energy, developers have surrendered 923 solar projects for 2026. This significant withdrawal suggests that the proposed compensation terms may not sufficiently offset the economic risks associated with grid instability. The move highlights ongoing tensions between policymakers and investors regarding the viability of renewable energy expansion under current infrastructure conditions.

Scale of Project Withdrawals

The magnitude of the developer exodus is evident in the sheer volume of capacity being pulled from the pipeline. According to Saur Energy, the 923 solar projects surrendered for 2026 represent a total of 40.6 GW of planned generation. This volume of cancelled infrastructure corresponds to lost investment totaling BRL 134 billion, equivalent to $26.3 billion. Such large-scale withdrawals indicate that the financial exposure from curtailment risks has outweighed the projected returns for a substantial portion of the sector. When developers abandon projects at this scale, it reflects a fundamental reassessment of the risk profile inherent in the current grid environment.

The impact extends beyond individual project balances to the broader regulatory registry. Aneel’s authorised plant register provides a clear metric of this contraction. The following table compares the registered capacity at the start of the year with the current figure:

Metric	Value
Registered capacity in January	110 GW
Current registered capacity	60 GW

This drop from 110 GW to 60 GW illustrates the tangible reduction in the solar fleet awaiting operational status. For the grid, this shrinkage in the registered base complicates long-term planning and resource adequacy assessments. It signals that the pipeline of future capacity is thinning rapidly, which may alter the expected contribution of solar power to the national energy mix in the coming years. The disparity between the initial register and the current state underscores the severity of the market reaction to the ongoing curtailment issues.

Curtailment Metrics and Scope

The operational reality of grid congestion is defined by specific, measurable constraints rather than abstract risks. This year, solar curtailment averaged 1.4 GW, a figure that represents 25.3 per cent of total solar generation. Such a high proportion of lost output indicates that grid limitations are not occasional anomalies but a persistent structural feature of the current system. When nearly a quarter of potential energy production is discarded, the economic viability of solar assets comes under immediate pressure. Operators face the direct consequence of building capacity that cannot reliably feed into the transmission network, turning theoretical generation potential into unrecoverable financial loss. This level of inefficiency disrupts the standard return-on-investment calculations that underpin project financing and long-term development strategies.

The regulatory response targets a specific subset of the installed base. Ordinance 140 covers 682 solar plants with a combined capacity of 25.5 GW. This scope determines which operators are eligible to claim compensation for the losses incurred during the defined period. For the plants within this bracket, the ordinance provides a formal mechanism to address the revenue gap caused by forced output reduction. However, the boundary of this coverage is critical for understanding the market reaction. Projects outside these 682 facilities do not benefit from this specific framework, leaving them exposed to the same grid constraints without the corresponding financial remedy. The distinction between covered and uncovered assets creates a fragmented landscape where risk mitigation depends entirely on regulatory classification. This segmentation influences how developers assess future investments, as the presence or absence of a compensation backstop fundamentally alters the risk profile of new projects entering the grid.

Regulatory Mechanics and Exclusions

The regulatory architecture governing curtailment compensation involves distinct administrative actions and legal prerequisites that shape developer participation. Key components of the current framework include:

• Aneel published Normative Resolution 1,170 on 6 October.
• The resolution dictates how future curtailment sharing is allocated among different generating technologies.
• Participation in the compensation scheme requires developers to drop pending legal claims.
• The ordinance explicitly excludes curtailment events caused by oversupply.
• Resolution 1,170 establishes a priority for run-of-river hydropower in curtailment allocation.

These provisions create a complex compliance environment for solar operators. The requirement to drop pending legal claims acts as a significant barrier, forcing developers to forgo potential litigation outcomes in exchange for the possibility of financial compensation. This trade-off alters the strategic calculus for firms already engaged in disputes over grid constraints. The exclusion of oversupply-related curtailment narrows the scope of eligible losses. Since solar generation often coincides with high output from other renewable sources, a substantial portion of curtailment may be classified as oversupply rather than technical grid failure, thereby rendering it ineligible for reimbursement under the ordinance.

The allocation rules in Resolution 1,170 further complicate risk assessment by prioritizing run-of-river hydropower for curtailment. This hierarchy suggests that solar assets may face different curtailment frequencies or severities compared to hydro assets. For investors, this technological prioritization introduces uncertainty into long-term revenue modeling. Understanding which technology bears the initial burden of grid balancing is essential for evaluating the stability of cash flows. The interplay between these exclusions and allocation priorities means that not all curtailment events carry the same financial implications, requiring developers to carefully map their specific exposure against the regulatory definitions.

What to watch

Developers must now decide whether to forfeit pending legal claims to access the compensation framework. This choice forces a strategic pivot, trading potential litigation outcomes for a defined, albeit limited, financial remedy. The outcome of these individual decisions will determine the actual uptake of the scheme and whether the intended relief reaches the intended recipients.

Simultaneously, grid operators and regulators face the challenge of classifying curtailment events. The distinction between technical grid failures and oversupply conditions is critical, as only the former qualify for reimbursement. As solar generation continues to coincide with peak output from other renewable sources, accurately categorizing these instances will define the scope of eligible losses.

The allocation hierarchy established by recent resolutions also warrants close monitoring. With run-of-river hydropower holding priority in curtailment distribution, the frequency and severity of interruptions affecting solar assets may diverge from those impacting hydro facilities. Investors need to observe how this technological prioritization plays out in practice to refine long-term revenue models and assess the stability of cash flows for future projects.