Keypoints:
- Both corridors target 30 bcm yearly
- Algeria starts work on its TSGP segment
- Financing and security will decide progress
NIGERIA’S two competing gas corridors to Europe have entered a more consequential phase, with ECOWAS leaders signing an agreement for the Atlantic route shortly after Algeria began construction on its section of the shorter Trans-Saharan Gas Pipeline.
The apparent race is not simply a contest between engineering designs. Both projects are intended to carry up to 30bn cubic metres, or 30 bcm, of gas annually, but neither has secured all the financing, construction commitments and reliable Nigerian feed gas required to operate at that scale.
Political momentum, not financial close
The African Atlantic Gas Pipeline, also known as the Nigeria-Morocco Gas Pipeline, received its latest boost at the ECOWAS summit in Freetown on July 19, 2026.
The intergovernmental agreement gave effect to the bloc’s December 2024 approval and followed a 2022 memorandum involving NNPC Ltd, Morocco’s ONHYM and ECOWAS.
NNPC says the project would span nearly 6,900 kilometres along the Atlantic coast. Reuters puts its estimated cost at $25bn and says its feasibility and front-end engineering design stages are complete.
That is a significant institutional advance, but it is not financial close and does not mean construction has started across the full corridor.
Morocco and Mauritania are expected to complete a separate agreement, while the sponsors plan to establish a regulatory authority in Abuja and a project company in Casablanca.
The overall project remains pre-final investment decision. However, its sponsors intend to develop individual sections as standalone systems rather than wait for the entire corridor to receive approval at once. No final funding commitments have been announced.
That phased approach is central to Morocco’s campaign to attract capital, examined in Africa Briefing’s report on Morocco’s push for the $25bn Nigeria pipeline.
Algeria gains a tangible advantage
The Trans-Saharan Gas Pipeline, or TSGP, offers a more direct 4,128-kilometre onshore route from Warri in Nigeria through Niger to Algeria.
Sonatrach formally launched work on the Algerian segment at Aoulef in Adrar province on June 4. The section is intended to follow the Trans-Saharan Road corridor from the Nigerien border to the National Gas Dispatching Centre at Hassi R’Mel.
From there, gas could enter Algeria’s national system and established export infrastructure serving European markets.
The launch gives the TSGP a tangible advantage: physical work has begun on part of the planned corridor. But it does not mean an uninterrupted Nigeria-to-Europe pipeline is under construction.
Nigeria and Niger must still deliver their sections and settle commercial, regulatory and security arrangements. Algeria’s activity should therefore be described as construction on its national segment, not the start of the complete multinational pipeline.
Africa Briefing has previously tracked how Algeria, Niger and Nigeria revived the TSGP after decades of limited progress.
Thirty bcm does not all go to Europe
The projects share a headline capacity of 30 bcm, but their proposed markets differ.
Under the Atlantic project, 15 bcm a year would be made available to Morocco and European buyers through the existing gas connection between Morocco and Spain. The remaining capacity is intended to support electricity generation, industry, mining and domestic consumption in participating African countries.
The project is therefore more than a long export pipe. It is also conceived as a regional energy network connecting gas-producing states with markets facing unreliable electricity and costly imported fuels.
Initial phases would connect Morocco with fields in Mauritania and Senegal and link Ghana with Cote d’Ivoire. A later section would connect Ghana to Nigerian supplies. First gas from initial phases has been targeted for 2031, although that is not a completion date for the entire route.
The TSGP is promoted more directly as an export corridor feeding Algeria’s gas system. Older estimates placed its cost at about $13bn, but no current official budget has been published for the full project.
Different routes, different risks
On distance, existing infrastructure and the number of participating governments, the TSGP appears to have the simpler commercial case.
It crosses three countries and terminates at a mature Algerian gas hub. But it concentrates political and physical-security risks in the central Sahel.
A pipeline through Niger would require long-term protection against armed attacks, sabotage and political disruption. Security guarantees would have to cover the pipe, compressor stations, maintenance teams, access roads and communications systems.
Niger hopes the corridor could help monetise its own resources, as explored in Africa Briefing’s report on Niger’s gas ambitions through the TSGP. That opportunity still depends on bankable supply agreements and investor confidence.
The Atlantic project avoids the deepest parts of the central Sahel but carries different risks. Its offshore sections require demanding marine engineering, multiple landing points and extensive environmental approvals.
Its greater challenge may be institutional coordination. Participating countries must align taxes, tariffs, transit rights, environmental obligations, gas pricing and dispute-resolution rules.
The phased structure provides some protection because one section could advance without the whole corridor. Yet it also creates the possibility that several regional systems become viable without ever forming the complete Nigeria-to-Morocco pipeline originally advertised.
Nigerian gas is the shared constraint
Both routes depend on Nigeria converting reserves into dependable commercial supply.
The Nigerian Upstream Petroleum Regulatory Commission put the country’s official gas reserves at 215.19tn cubic feet as of January 1, 2026. But underground reserves are not the same as processed gas ready to enter an export pipeline.
Nigeria would need additional upstream investment, gathering systems, processing plants and domestic transmission capacity. It must also balance exports against electricity generation, industrial demand, fertiliser production and existing LNG commitments.
A pipeline carrying 30 bcm annually would require roughly 2.9bn cubic feet of gas each day at full capacity. Filling two such corridors would demand an exceptional expansion in production and supporting infrastructure.
The projects could therefore compete not only for international finance but also for the same Nigerian feed gas, technical expertise and government guarantees.
Europe faces a timing paradox
Europe has a strategic reason to welcome additional non-Russian pipeline options.
The EU reduced Russian LNG and pipeline gas imports from 152 bcm in 2021 to 36 bcm in 2025. It has also adopted rules intended to end Russian LNG imports by the close of 2026 and Russian pipeline imports by November 30, 2027.
The 2026 disruption of LNG flows through the Strait of Hormuz strengthened the case for diversified routes. The IEA says the strait carried almost 20 percent of global LNG supply before its de facto closure disrupted markets.
Europe’s direct exposure to Gulf LNG is smaller than Asia’s, but reduced exports can still raise global prices, redirect Atlantic cargoes and make European storage more expensive to refill.
African pipeline gas would avoid Hormuz. However, neither Nigerian corridor is likely to deliver its full capacity soon enough to solve the present supply problem.
The projects also face a longer-term contradiction. European gas demand is expected to decline as renewable power, electrification, efficiency and climate rules expand. Developers need long-term purchase commitments for infrastructure that may not reach full operation until the 2030s, while European buyers are under pressure to reduce fossil-gas use.
Finance will decide the contest
The decisive question is not which line is shorter. It is which project can assemble the most credible combination of gas supply, customers, political guarantees, security protection and patient capital.
The Oxford Institute for Energy Studies has identified legal and fiscal frameworks, bureaucracy, weak utility creditworthiness, currency risks, domestic pricing and political insecurity among the main obstacles to financing gas projects in Sub-Saharan Africa.
The TSGP benefits from Algeria’s established network and a shorter route, but investors must price concentrated Sahel security risk and uncertainty over the Nigerian and Nigerien sections.
The Atlantic pipeline offers a wider regional-development case and independently financed phases. Its disadvantages are a much higher capital requirement and the challenge of coordinating numerous jurisdictions for decades.
There may not be a single winner. The Atlantic corridor could emerge first as a chain of regional systems supporting power and industry, while the TSGP could become a narrower export route into Algeria’s Mediterranean network.
Nigeria has strategic reasons to keep both options alive. One strengthens ties with Morocco and ECOWAS coastal states; the other deepens energy links with Niger and Algeria.
For now, Algeria has the advantage of visible construction on its own segment, while the Atlantic project has broader regional backing and a more developed phased-financing concept.
The eventual outcome will be decided less by route length than by which coalition can turn political support into secure supplies, bankable contracts and credible guarantees.
