Green Gas in Brazil:
How Waste Is Becoming
a Scalable
Energy Model

Brazil's energy identity in international discourse is built on a familiar shortlist: hydropower, ethanol, offshore oil. Biomethane — renewable gas produced from landfill waste, organic residues, and agricultural bystreams — does not typically appear on that list. That absence is increasingly difficult to justify. In 2024, Brazil produced 81.5 million cubic metres of biomethane, an 8.9 percent increase over 2023, according to the Brazilian Statistical Yearbook of Petroleum, Natural Gas and Biofuels. Installed capacity across authorised plants now stands at approximately 989,000 Nm³ per day, according to the ANP. And a new legislative framework — the Fuel of the Future law (14.993/2024), approved in September 2024 — has introduced a blending mandate that for the first time creates structural demand rather than relying on voluntary uptake.

What is changing in Brazil's biomethane sector is the underlying economic logic. Organic waste — previously managed primarily as a cost and a compliance obligation — is increasingly being treated as a feedstock for a regulated, tradeable energy molecule. That shift has consequences for waste management economics, gas infrastructure planning, industrial decarbonisation strategies, and capital allocation. How far and how fast it goes depends on factors that market data alone does not resolve: logistics infrastructure in the interior, regulatory consistency at the state level, and whether long-term offtake structures become available to producers beyond the largest operators.

The Mandate That Changes the Market Architecture

Until September 2024, Brazil's biomethane market operated primarily on the basis of voluntary corporate demand — companies purchasing renewable gas for ESG commitments or fleet decarbonisation, without regulatory compulsion on the supply side. The Fuel of the Future law changes that architecture. Starting in 2026, natural gas producers and importers must reduce at least 1 percent of their greenhouse gas emissions through biomethane commercialisation or by acquiring Biomethane Guarantees of Origin (CGOBs) — certificates that verify the renewable origin of the molecule and can be traded separately from the physical gas. The mandate escalates: regulators can revise the target annually, up to a ceiling of 10 percent of traded natural gas volumes.

Meeting the 10 percent target, based on 2024 demand, would require approximately 5.1 million cubic metres per day of biomethane — roughly twenty times current average production of 0.25 MMcmd, according to analysis by Rystad Energy. That gap between mandate ambition and existing capacity is the market signal. It creates a pull effect that was previously absent: producers, gas companies, and investors can now price long-term biomethane contracts against a regulatory obligation rather than against discretionary ESG budgets. Petrobras moved early: in January 2025 the company launched a biomethane procurement initiative seeking firm contracts with deliveries beginning in 2026, with terms extending up to eleven years.

Gás Verde and What the Leading Operator Reveals

Gás Verde, headquartered in Rio de Janeiro, describes itself as the largest biomethane producer in Brazil and Latin America — a claim consistent with publicly available capacity data. Its plant in Seropédica, Rio de Janeiro state, holds approximately 204,000 Nm³/day of biomethane capacity and is the largest single facility of its kind in the region. The company currently processes more than 1 million m³ of biogas daily, produces 160,000 Nm³/day of biomethane, and has 45 MW of installed clean energy capacity, according to its own disclosures. By 2028, it plans to add ten new plants and expand biomethane output to 600,000 Nm³/day — an expansion that would require an investment of approximately R$500 million at its Seropédica facility alone, according to earlier Argus reporting.

What Gás Verde illustrates beyond its own scale is the business model that the sector is converging on. Revenue streams no longer depend solely on gas sales. The company sells biomethane for industrial and fleet use, generates renewable electricity, issues BioREC traceability certificates, and — from 2025 — supplies green CO₂ to beverage-grade industrial clients. That diversification across energy, certification, and industrial gases reflects a broader pattern: the economics of biomethane improve materially when a single waste stream can be monetised across multiple output channels simultaneously.

The Feedstock Structure — and Its Geographic Logic

Brazil's biomethane potential is unevenly distributed, and that distribution shapes where investment is going. Urban landfill gas currently dominates operational capacity, with plants concentrated in São Paulo (54 percent of national production) and Rio de Janeiro (42 percent), according to Argus. But the country's largest untapped potential lies in agribusiness: the sugar-ethanol sector alone accounts for nearly 50 percent of the biomethane production potential attributed to agricultural sources, driven by vinasse and filter cake — abundant byproducts of sugarcane processing available at scale across the country's mill infrastructure.

This creates a geographic tension. Landfill-based production clusters near coastal demand hubs with existing pipeline access. Agricultural biomethane production, by contrast, is distributed across the interior — often in areas far from the natural gas grid. Connecting these inland sources to demand requires either new pipeline infrastructure or cost-competitive road transport, and neither is straightforward. The ANP's regulatory framework currently addresses quality standards and guarantees of origin but leaves distribution logistics — particularly for isolated projects outside the grid — as an outstanding constraint. Several states still lack specific rules for local biomethane distribution, as noted in a 2026 MDPI review of the sector.

What the Regulatory Gap Means for Investors

The institutional framework around Brazilian biomethane is advancing faster than in most comparable markets — but it is not complete. The ANP has established quality specifications and the CGOB certification system. The Gas Law (14.134/2021) and subsequent ANP resolutions (885/2022 and 886/2022) opened urban-derived biomethane to the same regulatory treatment as agricultural sources. The Metano Zero program, established by Decree 11.003/2022, formally integrated biogas into climate policy. These are meaningful steps.

The Larger Argument: Waste as Strategic Energy

Brazil generates 81.6 million tonnes of municipal solid waste annually. In 2024, only 3.2 percent of that volume was used for biomethane production, according to Abrema. The gap between current utilisation and available feedstock is, from one angle, a measure of how much runway remains. From another, it is a measure of how much infrastructure, regulation, and commercial architecture still needs to be built before that potential converts into reliable output.

The model that is emerging — waste management, energy production, decarbonisation services, and tradeable certificates converging in a single business — is structurally more interesting than a conventional energy play. It does not require new resource extraction. It does not compete for land with food production in the way that first-generation biofuels do. And it addresses a liability — organic waste — that Brazil generates at scale regardless of energy policy. Whether that model scales at the pace the Fuel of the Future law implies is an open question. The regulatory ambition is clear. The infrastructure, logistics, and commercial architecture required to meet it are still being assembled.