Shell's Merlin Find Revives Namibia Orange Basin as TotalEnergies Targets 2030 First Oil
A new Shell discovery offshore Namibia and TotalEnergies' Venus timeline put the Orange Basin back at the top of deepwater investment rankings.
Shell has declared the Merlin-1X well offshore Namibia its "most promising" result on licence PEL 39 — the same block where the company booked a $400 million impairment in January 2025 following engineering failures at the Graff-1X and Jonker-1X wells. The turnaround matters for more than one company's balance sheet.4,7
Merlin-1X sits in the Orange Basin, a deepwater petroleum province estimated to hold more than 20 billion barrels of oil equivalent straddling the Atlantic maritime boundary between Namibia and South Africa. Shell spudded the well on April 8 (2026-04-08) and the result has injected fresh credibility into a basin that had looked, briefly, like it might disappoint. Recoverable reserves at the Merlin structure are estimated at 750 million barrels for Phase 1 alone.4,7
The prior write-down was specific: high gas-to-oil ratios and complex geology at older discovery wells. Merlin's early results suggest the consortium has located better-quality reservoir within the same licence. Shell has now drilled ten wells on PEL 39.4,7
TotalEnergies has moved further along. Its Venus Project — anchored by the Venus-1X discovery of 1.5 billion barrels of light crude and 4.8 trillion cubic feet of gas, located roughly 290 kilometres off Namibia's coast — is now targeting initial production capacity of around 150,000 barrels per day, with first oil set for 2030. That timeline, if met, would make Venus one of the largest deepwater developments to reach production this decade.7
ICE Brent crude front-month was trading at $82.89 a barrel on August 6 (2026-08-06), up 1.36% on the day — a price environment that, for now, supports deepwater project economics but does not guarantee final investment decisions on developments with decade-long payback horizons.7
What separates Namibia from its neighbour is mostly institutional pace. South Africa controls roughly two-thirds of the same Orange Basin petroleum province, yet remains years behind Namibia in development. Namibia's Ministry of Mines and Energy and state-owned NAMCOR operate under a standardised Model Petroleum Agreement with a 35% petroleum income tax and a 5% royalty, with clearly defined approval timelines. South Africa's largest undeveloped offshore gas asset — the Ibhubesi Gas Field in Block 2A — holds an estimated 540 billion cubic feet of natural gas and 4.3 million barrels of condensate, but has not advanced at comparable speed.7
The fiscal and regulatory gap between the two countries is giving Namibia a structural head start. Majors choosing where to commit capital across a shared petroleum system will weigh Pretoria's slower permitting against Windhoek's track record of moving projects forward. TotalEnergies, which has been the most active African frontier explorer of any supermajor in recent years, placed its largest basin bet on the Namibian side.2,7
The African deepwater story sits alongside, but does not compete directly with, the shale surge underway on the other side of the Atlantic. Argentina's Vaca Muerta recorded crude output of 887,227 barrels per day in May 2026 — an all-time high, up 19% year on year — while a roughly $1 billion financing package from Citigroup, Banco Santander and JP Morgan is in progress for Transportadora de Gas del Sur's Vaca Muerta infrastructure. Abu Dhabi's XRG has also moved in, acquiring a 32% upstream interest in a Vaca Muerta block to anchor the Argentina LNG export project alongside YPF and Eni. These are different supply stories — shale versus deepwater, short-cycle versus decade-long — but they compete for the same pool of international capital and the same export buyers.6,3,5
For the Orange Basin specifically, the sequence of catalysts now runs through Namibia. TotalEnergies' final investment decision on Venus and Shell's next steps at Merlin are the events that will set the basin's production timeline. South Africa's ability to accelerate its own permitting and attract comparable commitments to its two-thirds share remains the outstanding variable.7,4
Rystad Energy forecast that South American crude production would surpass 3.7 million barrels per day this year, rising sharply through 2030 — a trajectory that makes African deepwater compete not just on geology but on pace. For Namibia, the Merlin result at minimum keeps Shell in the basin and reinforces the case TotalEnergies has already made by committing to a 2030 production date. The next signal is whether Shell moves toward appraisal drilling at Merlin or steps back to evaluate the full dataset from ten wells on PEL 39.1,4,7