At CERAWeek 2026
TotalEnergies, the French energy major, has sent its clearest signal yet of a strategic retreat from renewables toward conventional upstream: last week the company agreed with the Trump administration to return its offshore wind licenses off New York and North Carolina in exchange for approximately $1 billion in compensation, committing that capital to oil and gas projects in the United States.
The agreement was formalized by TotalEnergies CEO Patrick Pouyanné and U.S. Interior Secretary Doug Burgum on the sidelines of CERAWeek 2026.
The wind deal extends a capital reallocation that began in 2025, when TotalEnergies agreed to sell its 45% operated interest in two unconventional Vaca Muerta blocks — Rincón La Ceniza and La Escalonada — to YPF, Argentina's state-controlled oil and gas company, for $500 million, at approximately $10,000 per acre, to concentrate capital on higher-return conventional assets.
With capital reallocated and a declared focus on deepwater conventional upstream, TotalEnergies is evaluating entry into the OFF-5 block in Uruguayan waters — a 16,845 km² ultra-deepwater exploration license targeting a South Atlantic pre-salt play — where YPF and ENI, the Italian energy company, formalized a 50/50 joint venture under ENI's operatorship in November 2025, according to Shale24. No formal farm-in process or announcement has been made public.
The Namibia Mirror
The strategic logic is geological as much as financial. It was TotalEnergies that discovered the Venus prospect in Namibia's Orange Basin — the deepwater Atlantic margin play that emerged as one of the industry's most significant frontier discoveries of the 2020s — in 2022, the find that validated the pre-salt petroleum system of the African passive margin and triggered a wave of global interest in its mirror play across the Atlantic. No company in the industry reads the South Atlantic pre-salt system with more technical authority than the one that drilled Venus.
OFF-5 targets the same Aptian lacustrine pre-salt play — a geological formation in which organic-rich lake sediments deposited roughly 125 million years ago were buried beneath a salt layer, creating conditions for large hydrocarbon accumulations — that produced the Namibian mega-discoveries.
The geological mirror holds because the South American and African continental margins were once joined: the opening of the South Atlantic some 130 million years ago split a single depositional system into two conjugate margins with matching stratigraphy. Water depths across the block range from 2,500 to 4,100 meters.
The initial exploration program calls for a rank wildcat — an exploratory well drilled with no nearby production or structural confirmation — in 2027–2028, at a total depth of approximately 6,200 meters and a per-well capital cost of $180–220 million. Under the carried interest agreement between ENI and YPF, ENI finances the first well in full, allowing YPF to maintain its 50% working interest without committing capital during the highest-risk phase of exploration.
That structure leaves YPF with the option of farming down a portion of its interest to a third partner, reducing exploration risk further. If TotalEnergies were to enter, the sequencing would replicate what unfolded in Namibia: TotalEnergies and Shell established the play, Galp, the Portuguese energy company, confirmed its extension with the Mopane discovery, and the Orange Basin filled with international majors within three years of the first success.
Why TotalEnergies Fits
For TotalEnergies, an OFF-5 entry would align across multiple dimensions. The company has operated in Argentina since 1978: through TotalEnergies Austral, its Argentine subsidiary, it holds operatorship of the Marina Austral 1 block — which includes the Fénix gas field, an offshore production asset in the Austral Basin off the Tierra del Fuego coast — and maintains operated positions in the Neuquén Basin, including the producing Aguada Pichana Este and San Roque blocks.
Regional infrastructure, institutional knowledge of the Southern Cone, and an existing relationship with YPF reduce the friction of a potential negotiation. ENI as operator is not an unfamiliar counterpart: both companies share a track record in deepwater African projects, including Nigeria.
The geopolitical backdrop adds urgency. The Middle East conflict drove Brent to approximately $104 per barrel at the close of CERAWeek, according to Shale24 reporting — a level not seen since 2022 — and raised the strategic value of exploration on South Atlantic passive margins, the continental shelf and slope zones where geological conditions favor large conventional accumulations.
Those margins access Atlantic export routes bypassing the Strait of Hormuz and the Suez Canal, a structural advantage that has appreciated materially since the conflict began.
The combination of available capital, established geological expertise, regional operating presence, and a familiar deepwater partner represents an unusually complete strategic alignment — if TotalEnergies elects to act on it.