The last time Petrobras ventured into Namibian waters, it committed around US$16 million in farm-in and work-programme expenditure to acquire a 50% interest in offshore Block 2714A now PEL 72 in the Orange Basin, initially alongside Chariot Oil & Gas and later joined by BP.
It was a high-risk frontier bet made at a time when Namibia’s Atlantic margin was still unproven.
Petrobras entered the block in 2009, when Namibia had no offshore oil discoveries, limited modern seismic coverage, and no proof that its Atlantic margin could deliver commercial hydrocarbons.
The Brazilian major was testing a geological hypothesis in one of the world’s least understood offshore provinces, drawing conceptual parallels with Brazil’s own early South Atlantic experience.
Following the farm-in, the joint venture acquired an extensive modern 3D seismic survey over Block 2714A, aimed at improving subsurface imaging and de-risking drillable prospects identified from earlier regional data.
Interpretation focused on large structural and stratigraphic targets linked to the Nimrod delta system, which at the time was considered a viable reservoir fairway in the southern Orange Basin under prevailing geological models.
On the back of this work, the consortium advanced to drilling in 2012, spudding its only exploration well, Kabeljou-1 (2714/6-1), with Petrobras participating alongside BP and Chariot Oil & Gas.
Kabeljou-1 was drilled approximately 75 kilometres offshore, in waters spanning the continental shelf to the upper slope, and reached a total depth of about 3,150 metres true vertical depth subsea (TVDSS).
The well was fully logged and evaluated, including comprehensive wireline logging and formation assessment across the primary target intervals.
Despite intersecting the anticipated stratigraphic section, the well failed to encounter hydrocarbons in commercial quantities.
With no discovery declared, Kabeljou-1 was plugged and abandoned in accordance with regulatory requirements. The partners subsequently undertook post-well technical studies and applied for a short licence extension to complete their evaluation, incorporating the drilling results into revised basin and play models.
Those studies did not justify further drilling under the geological interpretations and market conditions prevailing at the time.
Petrobras and BP elected to exit the licence, and Block 2714A was formally relinquished back to the Namibian state. The acreage did not lapse permanently. Instead, it was later reconfigured under Namibia’s evolving petroleum licensing framework and reissued within the Petroleum Exploration Licence (PEL) system, eventually forming part of NAMCOR’s PEL 72.
For more than a decade, that single dry well defined Petrobras’ Namibian record: significant capital deployed, one exploration well drilled, and no discovery to show for it. Yet the company’s re-entry more than a decade later suggests that Kabeljou-1 did not close the door on Namibia. It marked the end of the country’s first, premature offshore exploration chapter.
What changed in the years that followed was not Petrobras’ tolerance for deep-water risk, but Namibia’s offshore context. Subsequent discoveries further north — most notably Venus in PEL 56 — proved that Namibia’s Atlantic margin hosts a working, large-scale petroleum system.
These discoveries did not validate the structural concepts tested at Kabeljou-1, nor did they sit within Block 2714A. They revealed a different play altogether: deep-water Cretaceous fan systems charged at the right time and trapped on a massive scale.
That success re-rated the entire margin and forced a reassessment of what might lie south of the proven fairway. Against that backdrop, Petrobras sought renewed exposure to Namibia’s offshore potential as the basin matured.
The Brazilian major has announced its return to Namibia through participation in PEL 104, entering alongside TotalEnergies as operator, with NAMCOR and local partners holding minority interests.
The precise equity split and final transaction terms were confirmed through regulatory and partner disclosures.
Crucially, PEL 104 lies in the Lüderitz Basin, south of the Orange Basin, rather than in the acreage Petrobras explored more than a decade earlier.
The Lüderitz Basin remains a frontier with no discoveries and no modern deep-water wells, but it shares a common tectonic origin with the Orange Basin. Its renewed appeal lies in a question now being asked with far better data: whether the petroleum system proven further north extends southward.
Over the past decade, both the Lüderitz and neighbouring Walvis basins have been progressively re-imaged through extensive multi-client 2D seismic programmes, significantly improving regional subsurface understanding before any drilling decisions are taken.
Environmental impact assessments for these seismic campaigns underline how Namibia’s offshore exploration strategy has matured, shifting from early, data-poor drilling to basin-scale reconnaissance, ecological clearance and geological screening first.
In that sense, Petrobras’ return is as much about timing as geology. Kabeljou-1 was drilled before Namibia’s offshore petroleum system was understood.
Venus and subsequent discoveries reshaped that understanding. Petrobras is now re-entering not as a lone frontier pioneer, but as a strategic partner sharing risk with an established operator already embedded in Namibia’s offshore narrative.
The irony is that the dry well that once ended Petrobras’ first Namibian venture has become part of the learning curve that brought it back.
