Brava Energia weighs Phase 3 at Atlanta to extend production plateau

Just 2 months after bringing its flagship Atlanta field onstream with the new FPSO Atlanta, Brazil’s independent operator Brava Energia SA is evaluating a potential third development phase that could add roughly 25 million bbl of reserves and help sustain peak production longer than originally planned.

The Phase 3 project, still at an early technical and economic evaluation stage, focuses on the Atlanta Nordeste area; a separate, shallower reservoir discovered in 2006 by Shell’s 9-SHEL-19D-RJS well.

According to André Fagundes, vice-president of research (Brazil) at Welligence Energy Analytics, Phase 2 has four wells still to be developed: two expected in 2027 and two in 2029. Phase 3 would involve drilling two additional wells in 2031, bringing total development to 12 producing wells. Until recently, full-field development was understood to comprise 10 wells, but Brava has since updated guidance to reflect a 12-well development concept.

Atlanta field upside

The primary objective is clear. “We believe its main objective is to extend the production plateau,” Fagundes said. Welligence estimates incremental recovery could reach 25 MMbbl, increasing the field’s overall recovery factor by roughly 1.5%.

Lying outside Atlanta’s main Cretaceous reservoir, Atlanta Nordeste represents a genuine upside opportunity, Fagundes explained. The field benefits from strong natural aquifer support, and no water or gas injection is anticipated. Water-handling constraints that affected early production using the Petrojarl I—limited to 11,500 b/d of water treatment—are no longer a bottleneck. FPSO Atlanta can process up to 140,000 b/d of water.

Reservoir performance to date has been solid, albeit with difficulties. Recurrent electric submersible pump (ESP) failures and processing limits on the previous FPSO complicated full validation of original reservoir models. With the new 50,000-b/d FPSO in operation since late 2024, reservoir deliverability has become the main constraint. Phase 3 wells would also use ESPs and require additional subsea infrastructure, including manifolds and flowlines.

Phase 3 capex is expected to be “relatively modest, given that only two wells are planned,” according to Fagundes. The FPSO, commissioned just over a year ago, is unlikely to require debottlenecking or major upgrades, and Welligence does not forecast production exceeding its nominal 50,000-b/d capacity even with Phase 3.

Final investment decision will largely depend on Phase-2 performance, Fagundes said. With first oil not expected until 2031, Brent price assumptions remain too distant to quantify precisely. Internal capital allocation will also consider synergies with Brava’s Papa-Terra asset, including potential rig-sharing opportunities.

Westlawn Americas Offshore’s 20% stake helps share risk in what remains a technically demanding deepwater heavy-oil development (14° API crude in about 1,550 m of water). Within the broader Brazilian offshore landscape, Atlanta stands out as a differentiated deepwater play rather than a marginal heavy-oil asset. The reservoir exhibits high porosity and permeability, while the crude, although heavy, has low sulfur content, allowing it to command a premium price.

Brava’s offshore operations director, Carlos Travassos, has also indicated interest in capturing additional upside. “Our teams are constantly seeking opportunities to extract value from the asset, so we are evaluating a Phase 3 at Atlanta for when production from these wells declines, but there is still no final investment decision,” he said in late-February remarks.

With gross 2P Atlanta reserves of 172 MMstb (GaffneyCline, year-end 2024) and production ramping toward its 50,000-b/d target by early 2027, a successful Phase 3 would further consolidate the field as one of Brazil’s most notable independent offshore developments and keep Brava on track toward its goal of 100,000 boe/d by the end of the decade. Regulatory risk from Brazil’s ANP appears limited, provided the project demonstrates technical and economic viability. Brava’s concession runs through June 2044, with an option to extend.

Brava Energia’s Atlanta Definitive Production System has won the 2026 Offshore Technology Conference Distinguished Achievement Award for Companies, the first independent Brazilian company to do so. Located 185 km off the coast of Rio de Janeiro state, in water depths exceeding 1,500 m, Brava describes Atlanta as the world’s deepest heavy oil field. Project innovations included the artificial lifting of oil from two wells via the same multiphase pump.