The signing of the $25 billion Nigeria-Morocco Atlantic Gas Pipeline agreement is a striking demonstration of Africa’s ambition to turn its natural resource wealth into lasting regional prosperity. It is also a project that will test, in real time, whether that ambition can survive contact with the financing gaps and security risks that have derailed similarly bold plans before it.
At 6,900 kilometres with an annual capacity of 30 billion cubic metres, the pipeline is Africa’s most ambitious energy undertaking, dwarfing even the long-proposed 4,400-kilometre Trans-Saharan pipeline. It draws on Nigeria’s reserves of more than 200 trillion cubic feet of gas, reserves that make the country the world’s ninth-largest gas holder, much of it still unmonetised. The timing is favourable: global gas demand is projected to grow 15 percent through 2040, and Europe, under its REPowerEU plan, is actively seeking alternatives to Russian supply and has identified African gas as a key part of that diversification. Monetising just 10 percent of Nigeria’s reserves could generate $20 billion a year, equivalent to 5 percent of the country’s GDP.
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The potential reaches well beyond Nigeria. The pipeline could help catalyse industrialisation across the 13 West African nations it will pass through, a region where only 52 percent of the population currently has access to electricity and where industrial power costs run 60 percent above the global average. Every 1,000 megawatts of gas-fired power the project unlocks could support an estimated 50,000 manufacturing jobs and $2 billion in annual industrial output. The UN Industrial Development Organisation projects a 35 percent increase in West African manufacturing value-added within a decade of the pipeline becoming operational, and Morocco’s existing gas infrastructure offers immediate off-take capacity to help the project reach markets from day one.
Export economics also favour the project. The European Union imported 290 billion cubic metres of gas in 2024, and even under the International Energy Agency’s Net Zero Scenario, the bloc will still require around 400 billion cubic metres annually through 2050. The pipeline’s capacity would represent about 7.5 percent of current EU demand, and at $8 to $10 per million British thermal units, Nigerian gas would undercut LNG imports currently priced between $10 and $14, making long-term supply agreements commercially attractive if stability can be assured.
One of the project’s most encouraging signs is institutional rather than technical: all 13 transit countries have signed on through ECOWAS, giving the pipeline a legal framework for transit rights, investment protection and dispute resolution that few African infrastructure projects of this scale have secured. The African Development Bank finds that projects backed by strong regional frameworks reach financial close 40 percent faster than those built on bilateral deals alone, a meaningful advantage for a project this complex.
Real challenges remain. More than 2,500 violent incidents have affected West African energy infrastructure since 2020, and Boko Haram’s insurgency has created a high-risk zone along part of the pipeline’s early route, echoing the security disruptions that have kept TotalEnergies’ $20 billion Mozambique LNG project suspended since 2021. Roughly 70 percent of the route runs offshore, which helps, but the onshore sections will require serious, sustained investment in security, estimated at $500 million a year.
Financing at this scale is equally demanding. The $25 billion price tag exceeds the African Development Bank’s entire annual lending capacity across all sectors, and more than 100 financial institutions now restrict fossil fuel financing outright. Closing the gap will likely require blended finance, concessional capital to absorb early-stage risk paired with commercial capital once construction is underway. The Islamic Development Bank’s $5 billion commitment already signals strong Gulf interest, an encouraging early building block toward the full financing package.
The technical scope is formidable too: a hybrid design crossing 13 jurisdictions, offshore sections reaching depths of 3,000 metres near the edge of current engineering capability, and a construction timeline stretching two decades, over which technology, regulation and markets will inevitably shift. Governance adds another layer of complexity, with corruption perceptions and contract dispute timelines varying widely across the 13 countries involved, a dynamic the region’s existing West African Gas Pipeline, still operating below capacity since 2010, illustrates clearly.
Even so, the pipeline’s core advantage, proximity to European markets, just three to five days’ shipping compared with three to four weeks from competing basins like Mozambique’s Rovuma, gives it a genuine first-mover edge if security and financing align. The project’s defining test will come by 2028, when developers must reach a final investment decision. Success would reshape West Africa’s energy landscape and industrial future for decades; the region’s leaders now have a rare, credible framework in hand to make that outcome possible.
