Galp Energia first arrived in Namibia in 2012 when the Atlantic frontier was a graveyard of unfulfilled dreams. Oil companies had drilled for decades without a commercial discovery.
Yet Galp took the gamble, farming into three offshore exploration licences operated by Brazil’s HRT Participações em Petróleo — PEL 23 in the Walvis Basin and PELs 24 and 28 in the Orange Basin.
Back then, optimism ran high.
HRT was a darling of Brazil’s pre-salt boom and had convinced investors that Namibia’s deepwater geology mirrored Brazil’s Santos Basin across the Atlantic. Galp bought a 14 per cent stake and agreed to carry part of HRT’s 2013 drilling costs, hoping the Namibian Atlantic margin would yield another Lula-sized discovery.
In March 2013, HRT spudded the Wingat-1 well in PEL 23, with Galp as partner.
The well encountered light oil — 38 to 42° API — but in thin, non-commercial sands. Still, it proved something no one had confirmed before: Namibia’s offshore source rocks were indeed generating oil.
Next came Murombe-1, drilled deeper into the Walvis Basin in search of thicker turbidite reservoirs. The sands were there, but they were water-wet. Finally, Moosehead-1 in the Orange Basin, which many believed would be the big one, found only tight volcanic rocks and traces of the Aptian–Barremian Kudu shale, rich in organic matter but poorly developed as a reservoir. Three wells, three misses.
For HRT, the financial toll was devastating. The company’s share price collapsed, its Namibian dream evaporated, and it eventually withdrew from the country. But for Galp, the experience was different.
Those wells had given it the most critical insight in Namibian petroleum geology: there was a working oil system — active, marine, and prolific. It just needed better imaging, better reservoir targeting, and better luck.
Galp stayed on quietly while others left. Over the next several years, it acquired and reprocessed seismic data, studied HRT’s logs, and observed TotalEnergies and Shell beginning to test deeper structures farther south. By 2019, Galp had repositioned itself into PEL 83, in the heart of the Orange Basin — a zone that later proved to hold Namibia’s most significant discoveries. It was a patient bet, rooted in what HRT’s early wells had revealed and what new data now confirmed: the source rocks extended farther south, charging a vast series of traps along the basin margin.
In late 2023, more than a decade after its first Namibian venture, Galp spudded Mopane-1X in PEL 83. This time, everything clicked—the well intersected multiple stacked light-oil and gas-condensate reservoirs with excellent porosity and pressure.
Follow-up wells — Mopane-2X and Mopane-3X — confirmed continuity and volume, suggesting a system that could hold around 10 billion barrels of oil equivalent in place.
Suddenly, the company that had entered Namibia when no one believed in its petroleum promise was now leading one of the country’s biggest offshore plays.
Galp’s Namibian journey is a story of endurance. Where its original partner HRT burned out, Galp adapted — learning from early dry holes, investing in better technology, and moving to a more prospective geological fairway.
The same basins once dismissed as barren are now alive with drilling rigs and seismic vessels, and Galp stands at the centre of that revival.
From Wingat-1’s faint traces of oil in 2013 to Mopane’s stacked reservoirs in 2024, Galp’s path shows how long-term persistence, informed by science and timing, can turn early disappointment into a defining oil story.
The data from yesterday’s failures can light the way to tomorrow’s discoveries.
 |
|
