Field/project development

How Brava Energia Turned Brazil’s Atlanta Deepwater Heavy-Oil Field Into a Full-Scale FPSO Development

Once labeled “undrillable,” Brazil’s heavy-oil Atlanta field in the Santos Basin faced technical, financial, and logistical challenges. But through a phased approach, clever reuse of assets, and disciplined project execution, Brava Energia transformed a risky deepwater asset into a producing field with 172 million BOE in 2P reserves.

Brava Energia brought the first two Atlanta wells online on the last day of 2024. The FPSO is expected to reach peak capacity of 50,000 BOPD later this year. Source: Yinson.
Brava Energia brought the first two Atlanta wells online on the last day of 2024. The FPSO is expected to reach peak capacity of 50,000 BOPD later this year.
Source: Yinson.

Some oil fields show a lot of promise—but even more in the way of challenges. An example is the Atlanta field in block BS-4 offshore Brazil.

This post-salt field holds estimated 2P reserves of 172 million BOE. That oil? It’s heavy, extremely viscous, and highly acidic, in an unconsolidated reservoir in 1550 m water depth.

Shell discovered heavy oil at Atlanta in 2001, pronounced it commercial in 2006, and later exited the concession without developing it. In 2012, a consortium led by the former Brazilian independent OGX—alongside a partner that would later become known as Enauta and eventually Brava Energia—scooped up the concession in 2012 (Fig. 1).

Fig. 1—The deepwater Atlanta field offshore Brazil is in the BS-4 license in the Santos Basin. Source: OTC 35600.
Fig. 1—The deepwater Atlanta field offshore Brazil is in the BS-4 license in the Santos Basin.
Source: OTC 35600.

But the following year, OGX, which later became known as Dommo Energia, declared bankruptcy.

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