Green Gas in Brazil:
Waste, Regulation and
the Infrastructure Gap
Behind Biomethane Scale

Brazil's energy identity in international discourse is usually built around a familiar shortlist: hydropower, ethanol and offshore oil. Biomethane rarely appears in that first sentence. That omission is becoming harder to defend. 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. The Fuel of the Future law (14.993/2024), approved in September 2024, has added the missing element: a mandate that turns renewable gas from a voluntary decarbonisation option into a regulated market requirement.

The more important shift is not technological. It is commercial. Organic waste — previously treated mainly as a cost, a liability or a compliance problem — is being reframed as feedstock for a regulated, certifiable and tradeable energy molecule. That changes the logic for landfill operators, sugar-ethanol mills, municipal waste systems, gas distributors, fleet operators and industrial buyers. It also creates a harder analytical question: where does Brazil actually have a scalable market, and where does it only have theoretical feedstock potential?

Why the Mandate Changes the Market

Before the Fuel of the Future law, Brazil's biomethane market depended largely on voluntary corporate demand: companies buying renewable gas for fleet decarbonisation, ESG commitments or industrial emissions targets. That market existed, but it was discretionary. The new law changes the demand architecture. From 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). The target can be revised annually up to a ceiling of 10 percent of traded natural gas volumes.

This matters because a certificate-backed obligation is different from a sustainability preference. It allows producers, investors and gas companies to assess biomethane against a compliance-driven demand curve. Meeting the 10 percent target, based on 2024 demand, would require about 5.1 million cubic metres per day of biomethane — roughly twenty times current average production of 0.25 MMcmd, according to Rystad Energy. The gap is not a footnote. It is the market signal.

Gás Verde: 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 available capacity data. Its Seropédica plant in Rio de Janeiro state holds approximately 204,000 Nm³/day of biomethane capacity, making it the largest single facility of its kind in the region. The company says it 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. By 2028, it plans to add ten new plants and expand biomethane output to 600,000 Nm³/day.

The company is important not only because of its size. It shows the business model toward which the sector is moving. Revenue no longer depends only on gas sales. Gás Verde combines biomethane for industrial and fleet use, renewable electricity, traceability certificates and green CO₂ for industrial clients. This is where the economics become more interesting: the same waste stream can support several revenue channels when infrastructure, certification and offtake are aligned.

The Feedstock Structure: Brazil Has Potential, But Not in One Place

Brazil's biomethane potential is large, but it is geographically uneven. Urban landfill gas currently dominates operational capacity, especially in São Paulo and Rio de Janeiro. These locations are close to demand hubs and existing gas infrastructure. The largest untapped potential, however, lies in agribusiness. Sugar-ethanol residues such as vinasse and filter cake offer major production potential because they occur at scale across Brazil's mill infrastructure.

This creates a structural tension. Landfill biomethane is often closer to gas consumers and pipeline access. Agricultural biomethane is more dispersed and frequently located inland. That means the market cannot be evaluated only by feedstock volume. It has to be evaluated by the relation between feedstock density, transport distance, grid access, state-level regulation and long-term offtake. In practical terms, Brazil may have strong national biomethane potential while still having very different regional project economics.

The Infrastructure Gap Behind the Green-Gas Narrative

The current regulatory framework has advanced. The ANP has established quality specifications and the CGOB certification system. The Gas Law (14.134/2021) and subsequent ANP resolutions opened urban-derived biomethane to the same regulatory treatment as agricultural sources. The Metano Zero program formally integrated biogas into climate policy. These are meaningful steps. They reduce ambiguity around product definition, certification and market participation.

But regulation does not remove the physical problem. A biomethane market needs collection, upgrading, compression, injection or transport, certification, contracting and end-use demand. In regions without pipeline access, producers need cost-competitive logistics or alternative local offtake. Several states still lack specific rules for local biomethane distribution, and isolated projects remain exposed to higher transport and contracting costs. This is the gap between policy ambition and market formation.

Cost Structure and Offtake Will Decide the Pace

Biomethane prices in Brazil have ranged between BRL 2.20 and BRL 3.95 per cubic metre — approximately USD 9.20 to USD 18.10 per MMBtu — depending on feedstock, scale and logistics, according to Rystad Energy. At the lower end, biomethane can compete with natural gas in specific applications. At the upper end, it requires either a carbon value, a compliance obligation, a premium buyer, or a long-term offtake structure that spreads risk over time.

Petrobras moved early in January 2025 with a biomethane procurement initiative seeking firm contracts with deliveries beginning in 2026 and terms extending up to eleven years. That matters because long-term contracts can turn regulatory demand into investable cash flow. But this structure will not automatically reach smaller producers, municipalities or dispersed agricultural projects. The market's depth will depend on whether similar offtake mechanisms emerge beyond the largest operators.

Why This Matters for Brazil's Energy Transition

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. From one perspective, this shows how much runway remains. From another, it shows how much infrastructure still has to be built before the available waste base becomes reliable energy supply.

The model emerging in Brazil is structurally more interesting than a conventional energy play. It does not require new resource extraction. It does not compete for land in the same way as first-generation biofuels. It converts an existing liability into a gas, certification and decarbonisation market. But scale will not be determined by narrative. It will be determined by the slower mechanics of infrastructure, regulation, finance and buyer commitment.

The Larger Argument: Waste Becomes Strategic Only When the System Works

Brazil's biomethane opportunity is real because it sits at the intersection of waste management, gas infrastructure, industrial decarbonisation and agricultural production. But that also makes it vulnerable to oversimplification. Waste does not become strategic energy merely because it exists. It becomes strategic when it can be collected, upgraded, certified, transported and sold through a contract structure that supports capital deployment.

That is the central distinction. Brazil is not just discovering a new green gas opportunity. It is testing whether a fragmented waste base can be converted into a regulated energy market at national scale. The Fuel of the Future law creates the pull. The next phase will show whether logistics, finance and regulation can build the bridge.