Oil and Natural Gas from the Sahara to the Gulf of Guinea: The Most Promising Areas (2024-2030 Outlook)

I. Executive Summary

The Sahara-Gulf of Guinea corridor remains a hydrocarbon region of critical global importance, characterized by established producers and the emergence of new exploration frontiers. Recent high-impact discoveries, notably in Namibia's Orange Basin and the Côte d'Ivoire Basin, are transforming the regional exploration landscape and revealing considerable untapped potential. Strategic investments in gas infrastructure, such as pipelines and liquefied natural gas (LNG) terminals, are essential to commercialize the vast natural gas reserves and to address energy security concerns, particularly for European markets. The investment climate is evolving, with international oil companies (IOCs) divesting mature assets to local and regional players, while governments implement fiscal incentives and licensing rounds to attract new capital. Despite promising prospects, challenges such as security risks, infrastructure gaps and regulatory obstacles persist, calling for concerted efforts to ensure sustainable development. The region offers attractive oil and gas investment opportunities, particularly in deepwater basins and frontier areas, alongside the development of critical infrastructure needed to unlock its full potential and support regional energy security and economic growth.

II. Introduction: Strategic Importance of the Sahara-Gulf of Guinea Corridor

The Sahara-Gulf of Guinea corridor is a vital source of oil and gas on a global scale. The region holds significant proven reserves, accounting for 4.5% of global oil reserves and 2.7% of global gas reserves. This endowment positions the corridor as a substantial contributor to the world's energy supply. Its strategic importance has been amplified by growing global energy security concerns, particularly in the wake of the Russia-Ukraine crisis, making it a crucial alternative supplier, especially for European markets. This role highlights the region's capacity to diversify global energy sources.  

Hydrocarbon revenues are fundamental to the economic empowerment of West African nations, contributing significantly to their GDP and government revenues. This underscores the essential link between hydrocarbon development and socio-economic stability in these countries.  

This report provides an in-depth analysis of the most promising areas for oil and natural gas in this corridor. It examines proven reserves, recent discoveries (2023-2025), active exploration campaigns, the favorable geological characteristics of sedimentary basins, major infrastructure projects and attractive investment climates. The analysis also includes a forward-looking perspective to 2030, identifying key trends and offering strategic recommendations.

III. Regional Hydrocarbon Landscape: Reserves and Production Dynamics

The Sahara-Gulf of Guinea corridor comprises nations with varied hydrocarbon profiles, ranging from established North African producers to emerging West African giants.

The Energy Pillars of North Africa

Algeria Algeria stands out as Africa's largest holder of natural gas reserves, with 2,400 billion cubic meters (Gm³) or 159 Tcf of proven reserves in 2023. IEA data for 2025 further indicate 3,611,549 terajoules (TJ) of natural gas reserves. The country also ranks third in Africa for oil reserves, estimated at 12.2 billion barrels.  

In terms of production, Algeria consistently produces more than 100 Gm³ of natural gas per year and around 1 million barrels per day (bpd) of oil. OPEC+ data for May 2025 show crude oil production of 0.93 million bpd (Mb/d). Algeria has expressed confidence in reaching an oil production capacity of 1.155 million bpd by 2025. The country is a key natural gas exporter to Europe, using three strategic pipelines: the Trans-Mediterranean (TransMed), Medgaz and the Maghreb-Europe (MEG). It currently accounts for roughly 14% of the European Union's total pipeline gas and LNG imports. To support this activity, an estimated $23.3 billion investment is planned in Algeria's hydrocarbon sector in 2025.  

Egypt Egypt holds 12.3 billion barrels of proven oil reserves and approximately 74 billion cubic feet (BCF) of recoverable gas reserves as of 2025. It is the second-largest natural gas producer in Africa. The country's oil production, coming mainly from the Gulf of Suez and the Western Desert, contributes significantly to its output. Egypt's average daily oil production is around 600,000 bpd. The country also benefits from a booming natural gas industry, driven in particular by the Zohr gas field. Egypt is the only country in the Eastern Mediterranean with two LNG export terminals, located at Idku and Damietta, with a combined capacity of 12 million tonnes per annum (Mtpa).  

Libya Libya has the largest oil reserves in Africa, at more than 48.36 billion barrels , and held 53 Tcf of proven natural gas reserves at the end of 2021. After 2024, Libya's oil production rose to 1.42 million bpd, with the National Oil Corporation (NOC) targeting 2 million bpd by 2028. OPEC+ data for May 2025 indicate crude oil production of 1.26 Mb/d. However, natural gas production declined significantly in 2024, with further substantial declines projected for 2025.  

Libya's investment climate is particularly dynamic. The 2025 licensing round, comprising 22 exploration blocks (11 onshore, 11 offshore), is governed by revised production sharing agreements (PSAs) designed to deliver a highly attractive internal rate of return (IRR) of 35.8%. Major international oil companies such as BP and Shell are re-entering the Libyan market, signaling renewed confidence.  

The Established Giants of the Gulf of Guinea

Nigeria Nigeria holds Africa's second-largest oil reserves, estimated between 36.89 and 37.89 billion barrels. Its gas reserves reached 210.54 TCF as of January 1, 2025, making it the largest gas reserve holder in Africa and about the ninth largest worldwide.  

Nigeria remains Africa's largest oil producer, with average daily production of 1.5 million bpd. Average oil and condensate production was 1,515,353 bpd in 2023. However, crude oil production fell to 1.4 million bpd in March 2025. OPEC+ data for May 2025 indicate 1.48 Mb/d. The sector faces persistent challenges, including infrastructure gaps, oil theft and political instability , as well as pipeline vandalism and illegal bunkering activities.  

Nigeria is actively focused on exploring and developing its vast gas resources, with a strong emphasis on reducing gas flaring. Key gas projects include TotalEnergies' Ima gas project, with production expected to begin in 2026 at 70,000 barrels of oil equivalent per day (boe/d) or 300 million standard cubic feet (MMscf) of gas, and the Ubeta field (production expected in 2027 with similar capacity), which are essential to feed the Bonny Island LNG plant. The resumption of construction of the critical Ajaokuta–Kaduna–Kano (AKK) pipeline is also a crucial step toward maximizing gas utilization and reducing flaring.  

Angola Angola has 7.78 billion barrels of proven oil reserves and an estimated 4.6 Tcf of proven natural gas reserves at the beginning of 2025. The country has re-established itself as a major oil producer in Africa thanks to steady offshore output. Its average daily production is 1.1 million bpd , making it the second-largest total liquid fuels producer in sub-Saharan Africa after Nigeria in 2024. OPEC+ data for May 2025 indicate 0.23 Mb/d , although this figure generally refers to crude oil production under OPEC+ quotas.  

Angola's liquefied natural gas (LNG) project, located at Soyo, is a major facility with a processing capacity of 1.1 billion cubic feet of natural gas per day, notable as the world's first LNG plant supplied by associated gas. The Sanha Lean Gas Connection project, which produced first gas in 2024, is expected to provide additional natural gas supply to Angola's LNG facility, with first production planned in 2025. Angola formally withdrew from OPEC effective January 1, 2024, following OPEC's November 2023 decision to reduce its crude oil production quota.  

Republic of the Congo (Congo-Brazzaville) The Republic of the Congo holds 3.0 billion barrels of proven oil reserves. Its oil sector is a dominant force in its economy, with average daily production of 275,000 bpd. OPEC+ data for May 2025 show 0.23 Mb/d. The country has seen new offshore drilling campaigns and increased foreign investment, particularly from Chinese and European companies. Perenco Congo is launching a new development phase with the Kombi 2 platform, representing an investment of more than $200 million.  

Equatorial Guinea Equatorial Guinea has an estimated 1.1 billion barrels of recoverable reserves , with its natural gas resources contributing significantly to its hydrocarbon profile. The country maintains stable production levels with average daily output of around 200,000 bpd. OPEC+ data for May 2025 indicate 0.06 Mb/d. The government is actively positioning the country as a regional oil and gas hub, offering incentives to investors and developing LNG infrastructure.  

Gabon Gabon holds 2.0 billion barrels of recoverable reserves. The country's average daily production is 180,000 bpd. OPEC+ data for May 2025 show 0.25 Mb/d. Oil remains extremely critical to its economy, accounting for more than 80% of exports. Gabon's oil industry has seen a revival thanks to offshore investment and improved fiscal incentives. The country has also joined OPEC's efforts to stabilize prices.  

Ghana Ghana has 48 Gm³ of proven gas reserves. Its offshore Jubilee and TEN fields form the backbone of its oil production, with average daily output of around 135,000 bpd. Ghana is rapidly becoming a key oil hub in West Africa. The government's commitment to regulatory reform and energy sector governance has encouraged new exploration.  

Chad Chad's oil sector, although modest in size, plays a vital role in its economy, accounting for more than 60% of export revenues, with average daily production of around 125,000 bpd. New investment from Chinese and French companies is reviving production in the Doba Basin.  

South Sudan South Sudan holds 3.75 billion barrels of reserves. Despite political instability, the country continues to produce significant volumes of oil, mainly thanks to infrastructure inherited from Sudan, with average daily production of 170,000 to 190,000 bpd. Chinese partnerships have been attracted to rehabilitate aging fields and pipelines, keeping its oil sector afloat.  

Table 1: Leading African Oil and Gas Producers: Reserves and Production (2024-2025)

Country	Proven Oil Reserves (Billion Barrels)	Proven Gas Reserves (Tcf / Gm³)	Average Daily Oil Production (bpd) (2025 est.)	Average Daily Gas Production (MMscf/d or Gm³/yr) (2025 est.)	Main Production Areas/Fields
Algeria	12.2	159 Tcf / 2,400 Gm³	1.0 million (0.93 Mb/d, May 2025 )	>100 Gm³/yr	Sahara (vast reserves) , Hassi R'Mel
Egypt	12.3	74 BCF	600,000	Booming industry (Zohr field)	Gulf of Suez, Western Desert, Zohr
Libya	48.36	53 Tcf (end 2021)	1.42 million (post-2024) (1.26 Mb/d, May 2025 )	Significant decline projected 2025	Sirte Basin
Nigeria	36.89 - 37.89	210.54 TCF (Jan 2025)	1.5 million (1.48 Mb/d, May 2025 )	Flaring reduction, Ima, Ubeta	Niger Delta , OML 112
Angola	7.78	4.6 Tcf (early 2025)	1.1 million (0.23 Mb/d, May 2025 )	48 MMscf/d (2024)	Offshore production, deepwater projects
Rep. of the Congo	3.0	N/A	275,000 (0.23 Mb/d, May 2025 )	N/A	Offshore
Equatorial Guinea	1.1 (recoverable)	Significant	200,000 (0.06 Mb/d, May 2025 )	N/A	Mature fields, deepwater exploration
Gabon	2.0 (recoverable)	26 Gm³	180,000 (0.25 Mb/d, May 2025 )	N/A	Offshore
Ghana	135,000	48 Gm³	135,000	699 MMscf/d (2023)	Jubilee, TEN
Chad	N/A	N/A	125,000	N/A	Doba Basin
South Sudan	3.75	N/A	170,000–190,000	N/A	Infrastructure inherited from Sudan

Note: OPEC+ production figures may differ from total national output because of quotas and because condensates are not included.

This table offers a concise overview of the current hydrocarbon situation in each major country of the region. It allows a quick comparison between reserve strength and production, highlighting countries with significant untapped potential and those that depend heavily on current output. It serves as a foundational data point for any strategic assessment of the region's energy landscape. For example, Libya, with the largest oil reserves, currently produces less than Nigeria or Angola, a gap linked to past political instability and investment challenges. Similarly, Nigeria holds enormous gas reserves, but commercialization is hampered by infrastructure problems, underscoring a need for investment in this area.

IV. New Hotspots and Frontier Exploration: The Most Promising Areas

The current dynamics of the hydrocarbon sector in the Sahara-Gulf of Guinea corridor are strongly shaped by recent discoveries and intensifying exploration activity in key basins.

The Orange Basin (Namibia and South Africa)

The Orange Basin has transformed the industry with a series of high-impact light oil and associated gas discoveries since 2022. Shell made the Graff-1X (2022) and Jonker-1X discoveries, which together hold an estimated 5 billion barrels. Despite a $400 million impairment on license PEL 39 owing to technical and geological difficulties, including a high natural gas content, the African Energy Chamber (AEC) still considers that the basin holds significant potential.  

TotalEnergies made the Venus-1X discovery (2022), hailed as the largest sub-Saharan oil discovery in Africa and TotalEnergies' largest in about 20 years. The field is believed to hold an estimated 5.1 billion barrels , or 2 billion recoverable barrels out of 5 billion in place. In addition, about 9 Tcf of associated gas have been discovered by TotalEnergies and Shell. The Venus development is expected to be sanctioned in mid-2025, with production planned by 2029, requiring several floating production, storage and offloading (FPSO) units.  

Galp Energia added to the excitement with the Mopane oil discovery (2023-2024), estimated at more than 10 billion barrels of oil in place, with a recoverable estimate of 2.5 billion barrels. Notably, this discovery sits in shallower water (1,400 m shallower than Venus) and has good reservoir properties. Galp is actively drilling, with its sixth well under way after five consecutive successful discoveries. The Mopane-3X well, drilled in January 2025, indicated the presence of significant columns of light oil and gas condensate in high-quality sandstones.  

The Orange Basin has demonstrated an impressive 75% success rate across 12 wells drilled by Shell, TotalEnergies, Galp and Chevron. It was a major contributor to the nearly 2.9 billion barrels of oil equivalent discovered in Africa in 2024. The basin is expected to see 7 to 10 new wells drilled in 2025.  

A major obstacle to commercialization is the high associated gas content, which requires costly and complex reinjection solutions, as flaring is not an option. The deepwater environment (ranging from 1,600 m for Galp to 3,000 m for TotalEnergies) further complicates and increases the cost of gas solutions. These discoveries are expected to propel Namibia among the world's leading oil producers by 2035. The next 12 to 24 months will be crucial, with TotalEnergies' final investment decision (FID) in 2026 set to set the tone for the broader development of the basin. The main companies active in the Orange Basin include TotalEnergies, Shell, Galp, Chevron, ExxonMobil (expanding its presence), QatarEnergy (partner on several blocks), Supernova, Sintana Energy and Pancontinental Energy (operator of PEL 87 with Custos Investments and NAMCOR).  

The geological potential of the Orange Basin is undeniably transformative, positioning it as a future major oil province. However, the high associated gas content and the inherent complexities and costs of deepwater operations represent a significant commercialization challenge. The promise of these discoveries lies not only in the volume of hydrocarbons found, but depends critically on developing economically viable and environmentally acceptable solutions for managing associated gas. This situation shows that, for promising areas, geological prospectivity must be matched with technical and economic feasibility. It suggests that future investment in the Orange Basin will focus heavily not only on exploration, but also on innovative gas monetization strategies and cost-effective deepwater development, which will be crucial determinants of ultimate commercial success.

The Côte d'Ivoire Basin

The basin has seen significant discoveries, notably the Calao field (identified through the Murène 1X well by Eni) and the Baleine field (discovered in 2021, with production starting in August 2023). These discoveries have positioned Côte d'Ivoire's gas sector for a new phase of growth.  

Production from the Baleine field began at 17.5 MMscf/d in its first phase (2023), contributing to average national gas production of nearly 264 MMscf/d that year. At the end of 2024, Eni commissioned the FSO Yamoussoukro to raise production to 70 MMscf/d in a second phase. A third phase, with a final investment decision (FID) planned for 2025, aims to complete the development by 2026, raising production to 200 MMscf/d. Côte d'Ivoire is on track to reach 150,000 bpd from the Baleine field by 2028.  

Murphy Oil plans drilling by the end of 2025, with the Paon oil and gas discovery a likely candidate for early development, requiring estimated capital expenditure (CAPEX) of between $250 million and $500 million. Vaalco Energy has also shown increased interest in four new offshore blocks, having acquired its first block in Côte d'Ivoire in March 2025. The Côte d'Ivoire Basin was a major contributor to African discoveries in 2024, alongside the Orange Basin.  

Senegal and Mauritania

Both countries are the setting for major projects. The Sangomar oil field started production in June 2024 with a capacity of 100,000 bpd. The Greater Tortue Ahmeyim (GTA) LNG project, developed in partnership with Mauritania, achieved first LNG production in 2025, with the first LNG exports expected shortly afterward.  

Looking ahead, Senegal plans a final investment decision (FID) for the Yakaar-Teranga project in 2025, targeting production between 2028 and 2029. Mauritania is actively seeking a partner to develop the BirAllah gas field, with a capacity of 60 Tcf, and is advancing the Banda field project. The investment climate is favorable: Mauritania signed an agreement in 2024 with PGS to acquire subsurface data for oil and gas exploration and is preparing to auction 15 offshore blocks. Recent regulatory improvements are strengthening investor confidence in both countries.  

Ghana's Offshore Potential

A formal declaration of commerciality (DoC) for the Eban-Akoma oil and gas discoveries in the Cape Three Points 4 (CTP-B4) block was announced on July 3, 2025. The Eban-1X (oil) and Akoma-1X (gas and condensate) wells confirmed commercial viability. The offshore Jubilee and TEN fields continue to support Ghana's oil production. A $2 billion memorandum of understanding was signed to drill 20 new wells in these fields.  

In terms of infrastructure, the Atuabo II gas processing plant and the Pecan Phase 1A projects are both on track for production in 2025, supporting gas commercialization. The Ghanaian government's commitment to regulatory reform and energy sector governance has encouraged new exploration. The Ghana National Petroleum Corporation (GNPC) is actively pursuing innovative joint ventures with Eni.  

While Ghana has a history of oil production from fields such as Jubilee and TEN, the recent declaration of commerciality for Eban-Akoma, combined with clear government strategies such as the Gas Master Plan and investments in gas processing infrastructure, points to a deliberate, strategic pivot toward maximizing its natural gas potential. This is not just about extracting hydrocarbons, but about leveraging gas as a cleaner transition fuel to establish Ghana as a regional energy hub. The broader vision, which includes nuclear development, suggests a diversified long-term energy strategy. Ghana's promise extends beyond its hydrocarbon reserves to its proactive energy policy, which aims for energy security, regional supply leadership and a more diversified energy mix. This makes it an attractive destination for integrated energy investment, and not only for traditional oil and gas exploration and production.

Sierra Leone: The Next Frontier?

Sierra Leone has an estimated offshore potential of 30 billion barrels of oil equivalent recoverable , including the substantial Vega prospect, which alone is believed to hold approximately 3 billion barrels of recoverable oil. The country launched its first offshore 3D seismic survey in more than a decade in May, with results expected in October. Reprocessing of this data is being carried out in collaboration with multi-client partners TGS.  

Sierra Leone could potentially offer up to 60 offshore blocks in its sixth licensing round, following the conclusion of the previous round in 2023. The country wants to strengthen its reputation as a new exploration frontier, explicitly citing Namibia and Guyana as examples of successful exploration booms after periods of inactivity. Major companies such as Shell, Petrobras, Hess and Murphy Oil have already purchased licensed data. The country also offers an attractive fiscal regime, with a breakeven price of about $50/bbl for a commercial deepwater discovery.  

Sierra Leone presents a classic frontier exploration opportunity: immense, uncommercialized hydrocarbon potential combined with historical exploration challenges. The government's current proactive efforts to de-risk (seismic surveys) and market aggressively (licensing rounds, citing successful analogues) aim to overcome these past obstacles. This creates a high-risk, high-reward scenario, in which the potential for supergiant discoveries is significant, but which requires substantial upfront exploration capital and a willingness to invest in a less proven, though highly promising, basin. For companies with a strong appetite for frontier exploration and the technical expertise to operate in difficult environments, Sierra Leone offers a potentially very rewarding long-term investment. Its promise lies in the scale of its undiscovered resources and in a government that is actively working to create a more attractive investment climate, making it a speculative but potentially transformative bet.

Nigeria's Enduring Potential

Nigeria retains significant potential, particularly in the Niger Delta, its most prolific basin, which holds 37.4 billion barrels of oil and 193 Tcf of gas reserves. The Anambra Basin is also attracting growing investor interest because of its favorable petroleum geological attributes.  

Key gas projects include TotalEnergies' Ima and Ubeta fields , which are vital for supplying the Bonny Island LNG plant. The resumption of construction of the Ajaokuta–Kaduna–Kano (AKK) pipeline and the rollout of the Nigerian Gas Flare Commercialization Programme (NGFCP) are crucial steps toward maximizing gas utilization and reducing flaring. Nigeria was the leading destination for upstream oil and gas investment in Africa in 2024, attracting $13.5 billion in final investment decisions (FIDs) for projects such as Shell's Iseni gas, TotalEnergies' Ubeta gas and Shell's Bonga North Tranche 1. TotalEnergies' $750 million FID for the Ima shallow gas project is planned for 2025.  

Other Underexplored Basins

Ghana The Volta Basin, covering 40% of Ghana's landmass, holds significant potential. Sediments in this basin exceed 6,000 m in thickness, and historical observations by Soviet geologists noted viscous black oily bitumen in core samples, suggesting an active petroleum system. The Ghana National Petroleum Corporation (GNPC) is due to drill its first exploration well in the Volta Basin in 2025.  

Nigeria Beyond the Niger Delta and Anambra basins, other sedimentary basins with active oil exploration potential include the Benue Trough, the Benin Basin, the Bida Basin, the Bornu Basin and the Sokoto Basin.  

West Africa (General) The offshore Casamance sub-basin within the Senegal Basin has promising source rocks in its Cenomanian and Turonian units. Sierra Leone's potential is also linked to the highly successful Guyana basin through tectonic reconstruction.  

Africa (General) Companies such as Impact Oil & Gas are specifically targeting "underexplored sedimentary basins in offshore Africa" , recognizing the continent's vast untapped potential. The Orange Basin itself was, until recently, considered an "underexplored oil giant" , underscoring the potential for new discoveries in other less-explored areas.  

The existence of numerous underexplored basins with promising geological indicators represents substantial long-term potential for the Sahara-Gulf of Guinea corridor. The promise here lies in the sheer volume of untapped resources that could be unlocked. However, realizing this potential requires significant upfront investment in de-risking activities, such as advanced seismic surveys and targeted exploration wells, as well as the development and deployment of technologies capable of operating in difficult environments. This points to a strategic opportunity for companies with a high appetite for high-risk exploration and specialized technical capabilities. De-risking these frontier basins is crucial for Africa's long-term energy security and for diversifying the global hydrocarbon supply. It signals a potential shift from exclusive reliance on mature fields to the discovery of entirely new hydrocarbon provinces, which could reshape regional and global energy maps. It also implies the need for supportive and attractive regulatory frameworks from governments to incentivize such high-risk, high-reward exploration efforts.

Table 2: Significant Recent Discoveries (2023-2025) and Estimated Reserves

Discovery Name	Country	Basin	Hydrocarbon Type	Estimated Reserves (Billion Barrels / Tcf / BoE)	Key Companies Involved	Year/Date of Discovery	Status
Graff-1X	Namibia	Orange	Oil, Associated gas	5 billion barrels (combined with Jonker-1X)	Shell	2022	Appraisal under way (impairment on PEL 39)
Venus-1X	Namibia	Orange	Oil, Associated gas	5.1 billion barrels (estimated) / 2 billion barrels recoverable / 9 Tcf associated gas (TotalEnergies & Shell)	TotalEnergies	2022	FID expected mid-2025, production 2029
Mopane	Namibia	Orange	Oil, Gas condensate	>10 billion barrels in place (2.5 billion recoverable)	Galp Energia	2023-2024	Active drilling, multi-phase potential
Calao (Murène 1X)	Côte d'Ivoire	Côte d'Ivoire	Gas	N/A	Eni	2024	Positions the gas sector for growth
Baleine	Côte d'Ivoire	Côte d'Ivoire	Gas	N/A	Eni	2021	Production started August 2023, phase 3 FID 2025
Sangomar	Senegal	Offshore Senegal	Oil	N/A	Woodside Energy	N/A	Production started June 2024 (100,000 bpd)
Greater Tortue Ahmeyim (GTA)	Senegal/Mauritania	Offshore	LNG	N/A	BP, Kosmos Energy, SMH, Petrosen	N/A	First LNG production 2025
Eban-Akoma	Ghana	Cape Three Points 4	Oil, Gas & Condensate	N/A	Eni Ghana, Vitol Upstream Tano, Woodfields Upstream Ghana, GNPC Explorco	2025 (declaration of commerciality)	Declaration of commerciality, development plan under way
Vega prospect	Sierra Leone	Offshore	Oil equivalent	~3 billion barrels recoverable	Anadarko (historical)	N/A	Untapped potential, new seismic survey

This table highlights the most significant and recent discoveries, providing quantifiable data on the scale of newly identified resources. It identifies the companies leading these successful exploration efforts and offers indications of potential development timelines, which is actionable information for investors and policymakers. The geographic concentration of discoveries in the Orange Basin and the Côte d'Ivoire Basin is clearly illustrated, indicating where the most intense and fruitful exploration activity is concentrated.

V. Conclusions

The Sahara-Gulf of Guinea corridor positions itself as a pivotal region for global oil and gas supply, with significant growth potential through 2030 and beyond. Established countries such as Nigeria, Algeria, Angola and Egypt continue to play an essential role, supported by substantial reserves and targeted infrastructure investment. Nigeria, in particular, is striving to capitalize on its vast gas reserves through major infrastructure projects and reforms aimed at reducing flaring.

The emergence of new hotspots, notably the Orange Basin in Namibia and the Côte d'Ivoire Basin, is a transformative factor. The multi-billion-barrel discoveries in the Orange Basin, although facing commercialization challenges linked to associated gas and deepwater costs, are set to make Namibia a major player by 2035. Côte d'Ivoire, for its part, demonstrates an ability to move quickly from discovery to production, particularly in the gas sector. Ghana, with its new discoveries and its Gas Master Plan, is strategically moving toward regional energy hub status.

Moreover, frontier regions such as Sierra Leone, with considerable resource estimates and proactive government efforts to de-risk exploration, represent high-risk, high-reward opportunities for investors willing to engage in less established areas.

For the region to realize its full potential, it is imperative to address persistent challenges such as security risks, infrastructure gaps and regulatory obstacles. Attracting investment, from both international oil companies and national oil companies, will depend on implementing stable and attractive fiscal and regulatory frameworks, and on ensuring a secure operating environment. The trend of IOCs divesting assets to regional and indigenous players also opens new avenues for sector development, fostering greater self-reliance and increased local content.

In sum, the Sahara-Gulf of Guinea corridor is not merely a current source of hydrocarbons, but a region with a clear roadmap for future growth, driven by new discoveries, strategic investment in gas and a growing determination by governments to create business-friendly environments.