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Africa’s energy systems are deeply interconnected with global markets.

Industry

The escalating confrontation between the United States, Israel and Iran has introduced a new phase of geopolitical uncertainty into global energy markets

While the immediate focus remains on security implications in the Middle East, the commercial and operational consequences for Africa’s oil, gas and energy sectors are both significant and far-reaching. As global supply chains absorb the shock of rising tensions, African producers, exporters, importdependent states, and emerging energy markets are confronting a rapidly shifting landscape.

Africa’s energy systems are deeply interconnected with global markets. Crude exports, LNG flows, refinery feedstock, maritime transport and downstream pricing all depend on stable international conditions. When geopolitical volatility disrupts these conditions, the effects cascade across the continent’s upstream, midstream and downstream operations.

Oil price volatility and supply side uncertainty

The US-Israel-Iran conflict has injected renewed volatility into global oil markets. Brent crude prices have experienced sharp fluctuations driven by fears of supply disruption, potential sanctions and the risk of escalation in the Strait of Hormuz – a corridor through which roughly one fifth of global oil supply transits.

For established African producers and exporters – Nigeria, Angola, Libya, Algeria, Egypt, the Republic of Congo, Gabon, Equatorial Guinea and South Sudan – price volatility presents both opportunity and risk. Higher prices may boost short-term revenues, but instability complicates:

∙ fiscal planning

∙ production scheduling

∙ investment decisions

∙ long-term project financing

South Sudan is particularly vulnerable. Although it produces the crude, it relies entirely on Sudan for pipeline transit, refining and export through Port Sudan. Any geopolitical shock that affects global prices or regional stability amplifies the fragility of this arrangement already impacted by the internal conflict in Sudan.

For import-dependent African economies – Kenya, Uganda (until production begins), Rwanda, Tanzania, Ethiopia, Senegal, Ghana, and South Africa – price spikes translate into:

∙ higher fuel import bills

∙ inflationary pressure

∙ increased subsidy burdens

∙ downstream pricing instability

The conflict has therefore widened the divergence between Africa’s energy exporters and importers, with both groups facing heightened commercial risk.

LNG shipping disruptions and maritime chokepoints

The Red Sea, Bab elMandeb, and the Strait of Hormuz remain critical arteries for global LNG and petroleum shipments. Rising tensions have led to:

∙ vessel diversions

∙ increased war risk insurance premiums

∙ longer shipping times

∙ higher freight costs

∙ rerouting around the Cape of Good Hope

For African LNG exporters – notably Algeria, Egypt and Mozambique – these disruptions affect:

∙ delivery schedules

∙ contract performance

∙ shipping economics

∙ buyer confidence

Mozambique, in particular, is emerging as a major LNG player. Its offshore reserves position it as a future global supplier, but project timelines and financing conditions are highly sensitive to global LNG market volatility. Any instability in shipping routes or pricing affects investor appetite and project momentum.

For LNG importing markets in North and East Africa, rerouting adds cost and uncertainty to already tight supply chains, affecting power generation, industrial output and domestic energy security.

Infrastructure and upstream project risk

Energy infrastructure across Africa – pipelines, refineries, offshore platforms, LNG terminals and power generation assets – is highly sensitive to global market conditions.

The current geopolitical environment has intensified:

∙ EPC contract renegotiations

∙ project delays

∙ cost escalations

∙ supplychain bottlenecks

∙ financing challenges

Upstream investment decisions are being recalibrated as international oil companies (IOCs) and national oil companies (NOCs) reassess:

∙ fluctuating price decks

∙ higher insurance premiums

∙ sanctions exposure

∙ shipping and logistics risk

Emerging producers such as Uganda, Namibia and Ghana are particularly exposed.

∙ Uganda’s Tilenga and Kingfisher projects, along with the EACOP pipeline, depend on stable financing and predictable price environments.

∙ Namibia’s offshore discoveries have generated global excitement, but long-term development decisions hinge on market stability.

∙ Ghana, while already producing, remains sensitive to price swings and relies heavily on imported refined products.

These countries illustrate how geopolitical conflict affects not only current production but also Africa’s future energy trajectory.

Commercial and contractual pressure across the value chain

The combination of price volatility, shipping disruptions and project delays has increased contractual tension across the African energy sector. Key areas of pressure include:

∙ crude supply agreements

∙ LNG offtake contracts

∙ pipeline transportation agreements

∙ refinery feedstock contracts

∙ EPC and O&M contracts

∙ charter party and shipping arrangements

Force majeure claims, renegotiation requests and performance disputes are to become more common as parties struggle to meet obligations under rapidly changing conditions.

This is where commercial risk management becomes essential.

Why ADR is becoming critical in Africa’s energy sector

In a period of heightened geopolitical uncertainty, effective, neutral dispute resolution capacity is no longer optional – it is a strategic necessity.

Energy disputes often involve:

∙ crossborder parties

∙ complex technical issues

∙ high value contracts

∙ time sensitive operations

∙ confidentiality requirements

Alternative Dispute Resolution – particularly arbitration, mediation and expert determination – offers:

∙ neutrality

∙ enforceability

∙ sector-specific expertise

∙ procedural flexibility

∙ continuity of commercial relationships

As global conflict continues to reshape commercial risk, African energy companies, investors and governments increasingly require dispute resolution professionals who understand both the geopolitical landscape and the operational realities of the oil and gas sector.

Africa’s energy future in a volatile world

The US-Israel-Iran conflict has underscored a fundamental truth: Africa’s energy markets are deeply exposed to global geopolitical shocks. From upstream investment to LNG shipping, refinery operations and downstream pricing, the continent’s oil and gas sector must navigate a more volatile and interconnected world.

For African producers, importers and infrastructure operators, resilience will depend on:

∙ robust commercial risk management

∙ flexible contracting strategies

∙ diversified supply chains

∙ and access to principled, neutral dispute resolution mechanisms

In this environment, the ability to anticipate disruption – and resolve disputes efficiently when they arise – will be essential to sustaining Africa’s energy growth and stability.

The article has been written by Elijah Paul RukidiMpuuga, FCIArb​, International arbitrator and founder, Equitas Dispute Resolution Group 

The target zone was water bearing.

Exploration

As part of phase three drilling programme offshore Gabon, Vaalco Energy has completed drilling the Etame West ET-14P exploration well

The target zone was water bearing even though 10 meters of high-quality Gamba sands were encountered in line with pre-drill predictions. Awaiting partner approval, this finding can be further pursued by utilising the well bore part to sidetrack it in the upper portion of the well. This move is expected to support the drilling of the ET-14H development well in the Main Fault Block of Etame. 

The lower portion of the well will be plugged and abandoned. Operations are expected to be completed in April.

George Maxwell, Vaalco’s chief Executive Officer, said, “When we committed to drilling the Etame West exploration well, we knew there was the geologic risk of not encountering commercial sands but the size of the potential reservoir made it a risk worth taking. Furthermore, we purposely designed the well so we could still utilise the well bore to drill a development well into a known productive area if the sands were non-commercial. This side-tracked well should be completed in April.” 

Vaalco has also been spudding the ET-15 infill well on the Etame platform as part of Phase Three Drilling Programme offshore Gabon.

This infill well is anticipated to significantly add to the production generation capacity of the floating storage and offloading vessel (FSO) that is operational on the Etame Block since 2022 following an extensive transition and field reconfiguration process. While a low cost solution, the FSO boasts of a high storage capacity and improved operational performance. It has helped Vaalco reach operational excellence, and production uptime and enhancement.

 

The complete dataset will be available for licensing from Q2 2026. (Image source: Metatek)

Geology & Geophysics

United Kingdom-based geophysical company, Metatek-Group Ltd, deployed its modern technology to conduct an airborne survey of the Kwanza Basin onshore Angola 

Full Tensor Gravity Gradiometry (eFTG), scalar gravity, magnetic and LiDAR data not only offered new insights into the subsurface but also identified precise locations that hold the most potential for future drilling programmes. Data accuracy from near-surface through to deep basement is covered by eFTG, which is known to be the highest-resolution airborne gravity gradiometry technology.

When operators are planning surface access, geomorphological interpretation and environmental baselining, they can resort to high-resolution terrain models generated by LiDAR data.

The gravity and magnetic data captured enables enhanced imaging of the Basin’s architecture, including fault and transfer zone geometries and regional structural domains, alongside more detailed analysis of sediment thickness and the distribution of salt, carbonate and volcanic bodies. 

Hydrocarbon resources besides, critical minerals could also be identified from selected priority areas flown at higher resolution. This will especially support the Angolan state-owned oil company Sonangol's diversification plans to critical minerals.  

Conducted in partnership with Angolan-based upstream consultancy Striped Horse and the Agencia Nacional de Petroleo, Gas e Biocombustiveis (ANPG), the survey captures the full Kwanza Basin, with over 36,000 kilometres flown.

The complete dataset - together with optional interpretation products including block viability ranking - will be available for licensing from Q2 2026 under a multi-client model.

Mark Davies, CEO of Metatek, said, “This survey represents a step-change in regional and prospect-scale subsurface understanding of the onshore Kwanza Basin. The integration of eFTG, gravity, magnetics and LiDAR deliver a robust, basin-wide framework enabling more informed exploration and de-risking seismic planning and acreage decisions.”

Communications Africa
OWI WA 2026

The concession's advance sustainability scopes are one of the prime reasons that locked the deal for ADNOC. (Image source: Adobe Stock)

In its first strategic investment in Mozambique, ADNOC has acquired 10% of Galp’s interest in the Area 4 concession of the Rovuma basin in Mozambique

The acquisition will allow ADNOC a share of the liquefied natural gas (LNG) produced from the concession.

With the operational Coral South Floating LNG (FLNG) facility, the planned Coral North FLNG development and the planned Rovuma LNG onshore facilities, the concession has a combined production capacity of more than 25 mn tonnes per annum. It is one of the world’s largest gas discoveries in 15 years. 

A one-of-a-kind facility in Africa, the Coral South development is currently in operation, with a production capacity of up to 3.5 mtpa of LNG. Once up and running, the Coral North development is capable of adding another 3.5 mtpa of LNG to that. It will have a FLNG facility to process and liquefy natural gas for export. 

The Coral south development is already yeilding vegetable oil to serve as feedstock in Eni's biorefineries. 

The modular, electric-drive design of the 18-mtpa Rovuma Onshore LNG development is capable of challenging industry standards when it comes to carbon intensity reduction from LNG production. 

The concession's advance sustainability scopes are one of the prime reasons that locked the deal for ADNOC, which aims to achieve a just transition-driven net zero by 2045. 

Integrated global gas business 

Musabbeh Al Kaabi, ADNOC executive director for low carbon solutions and international growth, said, “For over fifty years, ADNOC has been a reliable and responsible global provider of LNG and we are building on this role with this landmark investment in the world-class Rovuma supergiant gas basin in Mozambique as we deliver on our international growth strategy. Natural gas plays an important role to meet growing global demand with lower emissions compared to other fossil fuels and this acquisition supports our efforts to build an integrated global gas business to ensure we continue providing a secure, reliable and responsible supply of natural gas.”

 

 

 

 

 

The signing ceremony included the CEOs of Baker Hughes, SONATRACH and MAIRE, and the Minister of Energy and Mines. (Image source: Baker Hughes)

In an effort to boost production from Hassi R’Mel gas field 550 km south of Algiers, SONATRACH has signed a contract with Baker Hughes

The energy technology company will supply 20 compression trains based on Frame 5 gas turbine and BCL compressor technology will be installed across three gas boosting stations within the Hassi R’ Mel gas field. 

This comes as part of the Mattei Plan, a broader strategic collaboration across industries between Algeria and Italy. Italy has assured financial support for Algeria's gas production, which is the European nation's biggest single source of import. 

In 2023, Bloomberg NEF recognised Algeria as the second-largest gas supplier to Europe. The country has introduced multiple gas boosting stations to hold its title on the global energy market, while embracing natural gas as its prime energy source for socio-economic development. In June last year, TotalEnergies signed contract with SONATRACH to develop gas resources in the north-east Timimoun region. The oil major has also extended its LNG contract with SONATRACH till 2025 to access 2 mn tonnes of LNG for France and Europe.  

The largest gas field in Algeria, Hassi R’ Mel is equipped to not just meet domestic demands but also serves as key source of energy supply for Europe. At more than 20 trillion cu/m, shale gas is a lucrative investment opportunity for Algeria which falls under SONATRACH's long-term development plans as the company's vice president for planning and strategy, Rachid Zerdani noted last year. 

Baker Hughes responsibilities on Hassi R’ Mel will include boosting and stabilising the pressure of natural gas to increase production at site. Its facility in Italy will be the base for all project activity from compressor trains packaging and manufacturing to trains testing. This comes as a sub-contract of an order awarded to a consortium between Baker Hughes and technology and engineering group MAIRE-subsidiary Tecnimont. 

Reliable energy source for Europe

“We have long believed that it is critical to increase gas within the overall global energy mix to help achieve a lower-carbon economy. This project helps to solve for energy producers’ multi-faceted challenge of driving sustainable energy development as energy demand increases. We are proud to support such a critical energy project in partnership with Tecnimont,” said Lorenzo Simonelli, chairman and CEO of Baker Hughes. 

“Today’s announcement marks a notable milestone in our historical collaboration with SONATRACH for key energy projects in Algeria that have played a crucial role in supplying reliable energy to Europe,” said Simonelli on the occasion of contract signing, which also included Rachid Hachichi, CEO, SONATRACH; Alessandro Bernini, CEO, MAIRE, and the Minister of Energy & Mines, Mohamed Arkab.

 

 

 

 

There is a potential for an uptick in E&A drilling activity. (Image source: Westwood)

Mozambique can still lead production and drilling in the East African Ruvuma-Rufiji (EARR) Gas Basin through to 2030, if the government continues to take strides to guarantee rapid progression of projects off Cabo Delegado province, writes Michela Francisco, analyst - onshore energy services, Westwood Global Energy Group

According to bp's 2024 Energy Outlook, global liquefied natural gas (LNG) traded volumes are forecast to grow 43% by 2030 from the 543 bn cu/m recorded in 2022

In recent years, LNG exports have been dominated by the United States, Australia and Qatar, which, according to the Energy Information Administration (EIA), held a combined LNG export capacity of approximately 257 mmtpa in 2023 (60% of total global LNG capacity). By 2030, Qatar and the US are projected to add approximately 150 mmtpa in LNG feedstock, securing the top two positions in global LNG export capacity. New additions are anticipated to stem from LNG facilities currently under construction in the US (84.1 mmtpa) and expansion phases of QatarEnergy’s North Field (65mmtpa). Despite this, there is still an appetite for additional LNG supply, given current demand expectations, making the business case for developing long-stalled gas projects from frontier areas stronger.

Mozambique and Tanzania, which house the EARR Gas Basin, could potentially be major beneficiaries of this projected demand, given abundant gas reserves (165.7 trillion cu/ft) and the basin's proximity to South-Asian import markets. However, the burning question remains – how soon can the world expect the EARR Gas Basin to roar amid an increasingly thirsty LNG demand environment?

It is pertinent to state that the EARR Gas Basin has failed to live up to its full potential due to a series of endemic bottlenecks faced in the host countries. In Tanzania, the US$40bn Tanzania LNG project, which aims to receive gas feedstock from six fields across Blocks 1 and 4 (Shell) and Block 2 (Equinor), has been subject to extensive delays due to protracted negotiations rooted in unattractive fiscal terms due to high domestic supply obligations.

The story behind undeveloped gas reserves is quite different for the reserves offshore Mozambique, with the main culprit being the Islamist insurgency in Cabo Delgado province. The conflict has led to delays in final investment decisions (FIDs) and project start-ups, given declarations of force majeure for key projects. An example is TotalEnergies’ enforcing force majeure on the 13 mmtpa Mozambique LNG project, hereby delaying production start from the operator's Golfinho-Atum field into 2028, nine years post sanction.

On a similar note, ExxonMobil's Rovuma LNG project also felt the knock-on effect following the declaration of force majeure by TotalEnergies, given that it plans to share some facilities belonging to the Mozambique LNG project. ExxonMobil, however, seized this as an opportunity to cut costs by heavily reconfiguring the design plan from its initial two-train 15.2 mmtpa stick-build facility to an 18 mmtpa facility now being constructed using a modular approach whilst putting some emphasis on mitigating greenhouse gas emissions from the project. To date, ExxonMobil has launched tenders for a front-end engineering and design (FEED) contract and an engineering, procurement, construction and installation (EPCI) option for the subsea-to-shore gas gathering facilities.

Another factor contributing to the untimely development of resources in Mozambique is complicated project economics. TotalEnergies highlighted this in 2023 when it reported that supply chain inflationary pressures further complicated the resumption of the US$20bn Mozambique LNG project. However, there have been signs of positive developments given that TotalEnergies communicated in the company’s April 2024 earnings call that contractors have agreed to reverse contract inflation plans; thus, this is no longer an obstacle to the project’s sanctioning decision.earr gas basin

Despite these challenges, the Basin's inaugural project, Eni's 75,000 boepd Coral South floating liquified natural gas (FLNG) project, came onstream in 2022, signalling that complex, multi-billion-dollar developments could work offshore Mozambique. Output in Mozambique is forecast to remain stable at around 75,000 boepd until 2027 before growing to a peak of 295,000 boepd by 2030, up 296%, driven by TotalEnergies’ Golfinho-Atum and Eni's Coral Phase II fields.

Additionally, Tanzania's inaugural field in the Basin should come onstream in 2026 from Aminex's 7000 boepd Ntorya onshore gas field, boosting total output across the Basin to a peak of approximately 302,000 boepd by 2030, up 305% on 2023. Although there are positive signs for production, the spectre of delays that have been haunting projects remains strong, potentially diluting the positive picture prior to 2030, especially since only one of the three projects expected onstream by 2030 has passed sanctioning (TotalEnergies’ Golfinho-Atum). 

Drilling activity across both countries has been negligible, averaging one well per annum over the 2019-2024 period. Activity is anticipated to liven up over the forecast, driven by approximately 50 wells to be drilled to support upcoming LNG projects in Mozambican deepwater. Of these, 27 subsea trees have already been awarded between 2017 and 2019 for Eni’s Coral South and TotalEnergies’ Golfinho-Atum fields. 30 additional subsea trees are forecast to be awarded, with six awards anticipated for Eni’s Coral North field, scheduled to reach FID before the end of 2024. Onshore drilling activity will remain negligible, with only Aminex’s Chikumbi-1 exploration well set to be spud in 2024, the only onshore E&A well spud in the basin since 2016.

Post 2030, the outlook from the EARR Basin could be more promising, given continued interest from international energy companies (IECs), as well as licencing rounds and concession award announcements made across both countries since 2023. Although projects are few and far between in Tanzania, Shell and Equinor proposed a US$42bn LNG project from three deepwater blocks in March 2023, and this was later followed by CNOOC’s expression of interest in developing a FLNG deepwater project in blocks 4/1B and 4/1C in June 2023. From a regulatory standpoint, the current administration has increased optimism, given ongoing negotiation on fiscal terms with joint venture companies; however, nothing has materialised thus far.

Additionally, it is noteworthy to highlight the potential for an uptick in E&A drilling activity beyond Westwood’s current forecasts. This is due to the semi-autonomous Government of Zanzibar, off-Tanzania, launching its inaugural five-year licensing round in March of 2024, inviting IECs to explore eight offshore blocks.

earr gas basinsE&A drilling could also occur in Mozambique, given that the National Hydrocarbon Company approved a concession contract for oil exploration and production in the Angoche A6-C Area in July 2024. However, Westwood is bearish on these progressing into any E&A drilling activity before the second half of the forecast.

When dissecting current developments in the EARR Basin, it is evident that by the onset of the next decade, the Basin could contribute about 295,000 boepd of gas to meet global LNG demand. Westwood anticipates that Mozambique will continue to lead production and drilling in the EARR Basin through to 2030. However, it remains crucial for the Mozambican government to continue to take strides towards eradicating the insurgency to guarantee rapid progression of projects off Cabo Delegado province, which are currently mainly in the FEED stage.

Contrarily, on the Tanzanian side of the Basin, the portrait is more promising than in the hindcast, albeit there is still a need to focus on improving fiscal terms to attract more near-term investment and ensure that current interest from IECs is maintained. Overall, Westwood believes that by 2030, the EARR Gas Basin might start to live up to its potential as projects finally move from potential to reality.

APT has a gas sales agreement with TPDC. (Image source: Adobe Stock)

ARA Petroleum Tanzania and its development partner Aminex Plc have received a 25-year development licence over the Ntorya Gas discovery in Tanzania from the Deputy Prime Minister and Minister for Energy of Tanzania, Doto Mashaka Biteko

“We were honoured to receive this licence from Deputy Prime Minister Doto Biteko at such a prestigious event. This ceremony marked a significant milestone in our commitment to harness Tanzania’s gas resources for the benefit of its people. Our ambition for this serious endeavour is that it results in boosting economic development, alleviating energy poverty and supporting the country’s energy transition,” said Erhan Saygi, general manager, ARA Petroleum Tanzania, commenting on the handover ceremony that took place in Mtwara.

APT has acquired land for the installation of upstream processing facilities, and the Chikumbi-1 appraisal well location, while expanding an adjacent site to accommodate the construction of a camp and storage yard. It is also putting into place the logistics necessary to conduct the subsurface work that will lead to first gas production. This includes conducting a well-test on Ntorya-2 and converting it to a producing well, drilling the Chikumbi-1 appraisal well with a view to converting it to a producing well and carrying out a well workover at Ntorya-1, before turning it into a producing well. 

The company is aiming the completion of pipeline placement from Ntorya to Madimba by early next year, working in line with the Tanzanian government's ambitions to enable gas delivery for electricity generation in the Mtwara region. 

According to a Gas Sales Agreement signed with the Tanzanian Petroleum Development Corporation (TPDC) earlier this year, APT expects an initial yield of 40 to 60 mn st cu/ft a day in the first year, gradually boosting production to 140 mn st cu/ft over the next few years. 

This estimate is backed by strikingly positive 3D seismic datasets from the region, indicating significant potential gas volumes in other untested structures over the wider licence area. To emphasise just how significant the potential gas volumes might be, Charles Santos, the executive chairman of Aminex, has said that the Ntorya accumulation can become the largest onshore gas discovery in East Africa. 

This, however, will require investment in a phased development of the Ntorya gas field and the maturing of domestic industries as gas offtakers, such as fertiliser, cement and plastics production plants, vehicle CNG stations, domestic LPG suppliers and additional gas-fired power stations for industrial and residential use.

Ntorya gas hub

“We are excited about further exploration and appraisal work in this area as we consider it to hold truly enormous volumes of gas. We believe this could be game-changing for Tanzania’s energy security, for Mtwara’s industrial development and for Tanzanians’ prosperity. We look forward to building strong partnerships with local businesses and entrepreneurs to share knowledge, impart expertise and build a home-grown industry around a Ntorya gas hub,” said Saygi.

APT has been actively involved in the Ruvuma Asset since 2020, before its interests in the region accumulated to 75% post acquisition from Scirocco Energy last year. The remaining 25% interest in the Ruvuma Asset is held by Aminex.

 

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Exploration

The agreement will considerably push Nigeria's deepwater development.

Exploration

As Oil Prospecting Licence 245 (OPL 245) undergoes conversion, the President of the Federal Republic of Nigeria, Bola Ahmed Tinubu, and Eni's chief executive officer, Claudio Descalzi, met in Abuja to explore how the development can advance the Nigerian deepwater sectors

A significant feature of the agreement is the discontinuation of the international arbitration proceeding at the International Centre for Settlement of Investment Disputes (ICSID), thus allowing the conversion of the existing license into two development licences, Petroleum Mining Leases (PML) 102 and 103, and two exploration licences, Petroleum Prospecting Leases (PPL) 2011 and 2012, to Nigerian Agip Exploration Limited (NAE) as operator, alongside its partners Nigerian National Petroleum Company Limited (NNPC) and Shell Nigeria Exploration and Production Company Limited (SNEPCO). 

The agreement will considerably push Nigeria's deepwater development with Eni set to apply its know-how on the Zabazaba and Etan fields for optimal output. An extensive programme has been devised to generate approximately 500 MMbbl of reserves from the fields, including the deployment of a 150 kbopd capacity FPSO processing facility, while gas (200 MMSCFD at peak) will be exported through Nigeria LNG. The highly potential PPL 2011 and PPL 2012 exploration licenses will also be developed in line with the Zabazaba and Etan fields for a well-synced operational and production output from all facilities involved.

President Tinubu and Mr Descalzi also discussed Eni’s significant investment portfolio — including the Abo and Bonga fields and Nigeria LNG — as well as on potential new developments designed to expand the country’s offshore production capacity. Within this framework, and in line with its long-term strategy in the country, Eni has recently expanded its interests in deep-water developments, with the acquisition of an additional stake in OML 118, now holding 15%.

 

The ultra-deepwater drillship, Sonangol Quenguela, will continue to operate in Angola.

Both of the Magoga wells drilled the full reservoir interval. (Image source: Assala)

Geology & Geophysics

The survey spans approximately 12,600 line kilometers. (Image source: TGS)

Geology & Geophysics

Energy data and intelligence provider, TGS, has announced the Ultra Profundo multi-client 2D survey offshore Angola

The survey spans approximately 12,600 line kilometers, and Ramform Victory began operations earlier in Q1. Data acquisition is likely to be completed in around 100 days, with fast-track products available in Q3. Full data processing is scheduled for completion in Q2 2027.

The Ultra Profundo multi-client 2D survey marks the first 2D multi-client acquisition over Angola’s ultra deep-water areas since 2015 and aims to reach previously underexplored region. The survey delivers modern, long-offset seismic data critical for imaging complex pre-salt and top-salt structures as well as basin floor channel systems, significantly enhancing regional geological understanding.

Kristian Johansen, CEO of TGS, said, “Angola’s ultra deep-water margin represents one of the most exciting frontier exploration opportunities in West Africa. Our Ultra Profundo multi-client 2D program delivers high-quality seismic coverage needed to unlock pre-salt and sub-salt potential. By leveraging TGS’ acquisition and imaging capabilities, we will provide high-quality data supporting future exploration activities.”

The complete dataset will be available for licensing from Q2 2026. (Image source: Metatek)

The Nigeria Laide multi-client 3D survey. (Image source: TGS)

Technology

TEN field's total production count for 2025 is 16.0 kbopd.

Technology

With all reservoir and operations risks for 2026 considered, Tullow Oil is aiming an average production rate of 34-42 kboepd, including 6 kboepd of gas 

In 2025, Ntomme and Enyenra performance from TEN led the field's total production count at 16.0 kbopd, while the exit rate from Jubilee stood at 57 kbopd. 

The company will be deploying riser system and riser-base gas lift for well production management activities, and waterflood and fluid lift optimisation. These, along with the support of high-uptime FPSO, five planned Jubilee wells (four producers and one water injector) are expected onstream this year. The J75-P, for instance -- where a rig has been active for drilling -- has recorded three good reservoir intervals. 

The recently completed J74-P well is already onstream since January, revealing 50 meters of net pay while generating an initial gross production through the wellbore at 13 kbopd. 

The well management measures align with findings from 4D seismic and Ocean Bottom Node seismic surveys to leverage significant reservoir information extracted. 

Tullow has made a strategic investment to acquire the TEN FPSO as it will simplify operational synergies between the TEN and Jubilee fields, maximising output in the long term with minimal expenses. The company has already secured 10-year and 14-year-long ratifications on the West Cape Three Points and Deep Water Tano Petroleum Agreements.

Ian Perks, chief executive officer, Tullow Oil Plc, said, “2025 has been a year of disciplined execution across the business. This includes strong operational momentum which continues with excellent results from the latest Jubilee well and a further five wells due onstream this year to support our production targets. We have achieved significant cost reductions and completed the sale of non-core assets in our ongoing efforts to streamline our portfolio and strengthen our financial position.

“However our 2025 full year free cashflow was negatively impacted by the commodity price environment towards the end of the year and delays in receipt of Government of Ghana receivables and the second instalment of proceeds from the Kenya disposal.

“The refinancing transaction we have announced today enables us to focus on delivering our near-term priorities, which include driving further cost efficiencies, improving cashflow management and optimising our production."

 

The company will be conducting testing and commissioning activities.

The project was executed to a very high standard. (Image source: Corcel)

Gas

The panel's theme was 'Africa's energy transition on African terms'.

Gas

Crystol Energy's founder and chief executive officer, Dr. Carole Nakhle, moderated an Africa-focused panel during the recently concluded International Energy Week in London to get a perspective on the continent's stand on decarbonisation and energy transition practices

"It's not saying that decarbonisation should be ignored, but the truth is, you can't decarbonise what you don't have. If you don't have energy, you can't be talking about decarbonisation. You have to have the energy faster than you decarbonise," said the Nigerian National Petroleum Company's chief financial officer, Adedapo Segun, in the context of poor energy access in Africa. 

Segun's case was further supported by Renaissance Africa Energy Company's managing director and chief executive officer, Tony Attah, who said that with a teeming youth population, Africa cannot compromise on industrialisation. "I think it's a no brainer that from an African lens, from a Nigerian lens, industrialisation is what will move people out of poverty. We want to be given the flexibility to use the same resources to achieve what Europe and the rest of the world has achieved. From an African lens, it's survival first. I haven't survived. You're asking me to make a choice. It's about the industrialisation of Africa...when you talk about the whole emissions and impact on climate, data suggests that the entire Africa is contributing way less than 4% so essentially, we can even carry on at two, three times the scale today, and it will not be of any significant impact," Attah said.

While Dr. Nakhle was all ears, she stressed Africa's responsibility to eliminate flaring for sustainable production. "Just by increasing the penalty on gas flaring, you motivate the companies to actually still produce oil and gas with lower carbon intensity, because I think that would be the winning step for the future, and not to continue with what was a good old fashioned way of producing oil and gas."

According to Attah, flaring has been a focus area for most creditors as part of decarbonisation strategy, which aligns with attaining zero routine flare by 2030. With engineers working on projects to deal with gas storm compression infrastructure that are capable of moving gas from flood centres to the market, there has been a massive reduction in flare now. 

Gas is already driving Africa's energy narrative, with around 620 trillion standard cubic feet coming solely from Algeria, Mozambique and Nigeria. The world has come to Africa with massive investments, not just for international market but also the domestic market. The nation is hence way past the stage of "making a case", as now its just a matter of the investments unleashing the potential that is trapped in all these countries.

"Gas is going to be the game changer for us. So we are looking to develop our gas resources and export the gas to derive the financing for developing the country, and bridging the infrastructure gap," said AGPC's managing director, Effiong Okon, as he gave some perspective on Nigeria's national budget against the infrastructure budget of European countries.

"We have a budget of just about 20 something million dollars. That is for the whole country, and 45% of that goes to debt service. Another 15% goes to security. So you have 60% of the budget locked in debt service and security. And with that, you really cannot build infrastructure. You need to improve the standard of living. It becomes impossible. I checked on some of the European countries, Germany, for example, for just for infrastructure in 2026 [it is] going to spend close to US$200bn. So we really need to find the prosperity to develop," he said. 

Dr. Nakhle also raised the question of Africa's biggest paradox. "Africa is rich in energy resources, and yet it is poor when it comes to energy consumption. What do you think needs to change to change this reality on the ground?" she asked.

Attah's answer was that Africa is looking at a typically extractive industry when it comes to oil and gas. While the resource belongs to the nation, it was entirely under the control of international oil companies. Due to this structural dislocation, IOCs will extract, go and develop their respective countries with it. But now with majors announcing massive divestments on the back of onshore maturation, companies like Renaissance were feeling the heat. "But I have to thank NNPC for just supporting the divestment to go through. So we bought the share assets, and you can imagine that our philosophy and vision will be different from that of an IOC. We have a very audacious vision to be the African leader in energy. The IOC will not want to be the African leader in energy. They want to be the global leaders, but we want to be the African leader in energy. We want to enable energy security, [and] we want to bring about the industrialisation of Nigeria. Now that was not an assignment for the IOC...We are now taking our destinies in our hands to the extent that we will have no choice than to ensure that that shared prosperity from this energy resource base changes the narrative. On behalf of Nigerians, starting from Nigeria, pivoting to rest of Africa, which is why we like to say as Renaissance, we were made in Nigeria, built for Africa," he said. 

On the energy transition front, Silvia Macri, Middle East and Africa lead, Power & Renewables, S&P Global, said, "If you think about diversification, some countries in western Africa, Kenya in eastern Africa, are pushing either away from a fossil fuel heavy energy mix, or diversifying the sources, instead of having one major source of the produces, power or energy for the country; just choosing all the different options that are available. And this is something that South Africa, for example, has started doing at a faster pace. Kenya is probably the country where this has happened at the highest level, because it has a huge availability of geothermal resources, which allowed the diversification into renewables, but western African countries are bringing gas generation in the mix together with renewables...going forward, [it is important that] the decisions that they're making are more for the longer term, and they're not just solving the problem that is immediate."

 

 

The NGC project is driven by gas produced offshore Quiluma field. (Image source: bp)

Coral Norte will be an enhanced replica of the Coral Sul project.

Downstream

Vitol Bahrain EC has a long-standing presence in Uganda's downstream sector.

Downstream

As the Uganda National Oil Company aims to build a crude refinery, it has reached out to a unit of global commodities trader, Vitol, for a US$2bn loan to support the project alongside construction and infrastructure developments

According to Henry Musasizi, Uganda's junior finance minister, this seven-year tenor loan from Vitol Bahrain EC (VBA) comes with an interest rate of 4.92%. The minister worked on advancing the approval process for the credit line and the loan, which involved significant lawmakers, who sanctioned the development with a majority verdict.

Musasizi said that Vitol's support "presents an opportunity to access non-traditional financing to implement. ..projects and support the government in developing national infrastructure."  

Vitol Bahrain EC has a long-standing presence in Uganda's downstream sector, functioning as the sole supplier of refined petroleum products to UNOC, before the state-owned company sells it to retailers across the country.

Alongside the refinery, the loan amount will also be covering road construction, a petroleum products storage terminal and extension of a petroleum pipeline from western Kenya to Uganda's capital Kampala.

Previously, the UNOC also concluded a deal with the UAE-based Alpha MBM Investments, whereby a domestic refinery with a capacity of 60,000 barrels per day is in the pipeline. The agreement accords 60% stake on the refinery to the UAE firm while UNOC retains 40%.

Uganda is looking to begin commercial oil generation starting next year from fields in its west.

Afreximbank has framed a US$1.75bn facility for Sonangol. (Image source: Afreximbank)

The refinery will revitalise Ghana's downstream petroleum sector.

Event News

Christopher Hudson, President of dmg events. (Image source: dmg events)

Event News

Oil Review Africa catches up with Christopher Hudson, President of dmg events, ahead of ADIPEC 2025

Excerpts from an interview: 

Energy across Africa, as elsewhere in the world, is seeing major shifts and advancements. How does ADIPEC 2025 reflect this changing industry landscape and help meet the needs? 

Energy is one of the most dynamic and rapidly evolving sectors. According to the International Energy Agency (IEA), global energy demand rose by 2.2% last year, outpacing the average annual increase of 1.3% recorded over the last decade. At the same time, the global population is projected to reach 9.8 billion by 2050, with over 750 million people still lacking access to electricity, and more than 2.1 billion people remain without access to clean cooking. Rising urbanisation and living standards are reshaping energy demand, with air conditioning alone expected to be one of the largest contributors to electricity demand growth in the coming decades. This reveals the sector’s increasing need to not only produce more energy but to produce it in a way that is equitable and sustainable.

In this context, ADIPEC 2025 is being held under the theme of ‘Energy. Intelligence. Impact’. It reflects a simple but powerful truth: meeting the world’s growing need for secure, affordable and sustainable energy will depend on how intelligently we harness every resource – human, technological and natural – to deliver meaningful results for economies and communities alike.

At its core, the theme recognises that intelligence – both human and artificial – is transforming the way energy is produced, managed, and consumed. From AI-driven optimisation and digital integration to advances in hydrogen, LNG, and decarbonisation, intelligent innovation is reshaping the global energy landscape. ADIPEC serves as the meeting point for these forces, where ideas translate into action and impact can be measured in investment, policy, and progress.

AI is a major topic of discussion in the context of energy, due to its high demand. How is ADIPEC responding to the challenges and opportunities of the AI-energy nexus? 

Artificial intelligence is reshaping both global energy demand and the industry’s ability to respond. Data centres already consume around 1.5% of global electricity, and with AI workloads, that demand could more than double by 2030, rising from 415 TWh to 945 TWh. A single advanced AI model can require as much electricity to train as 100 households use in a year, while an AI query may consume 10 times more energy than a standard search.

This convergence is both a challenge and an opportunity. AI requires enormous energy, but it can also optimise grids, cut waste, improve operational efficiency, and accelerate decarbonisation. At ADIPEC 2025, we have expanded our AI Zone into five experiential areas showcasing how AI is transforming systems, people, and infrastructure. Alongside this, more than 80 conference sessions are dedicated to the AI–energy nexus, from predictive analytics to governance frameworks.

For Africa, this is particularly significant. Many countries are rapidly digitalising while also expanding power systems. The ability of AI to enhance reliability and reduce costs could be transformative for energy access and economic growth.

How is the diversity of the African continent and its vast energy sector reflected across ADIPEC 2025’s programme? 

Africa is a core part of ADIPEC’s community. This year, we are proud to welcome a strong delegation of African ministers and leaders, including those from Nigeria, Kenya, Uganda, Sierra Leone, Zimbabwe, Gambia, Equatorial Guinea, and Egypt. Their participation enriches ADIPEC’s Strategic Conference and exhibitions, ensuring Africa’s perspectives are reflected in discussions on natural gas, hydrogen, downstream, and low-carbon solutions.

dmg events is also the largest organiser of energy and infrastructure events across Africa, with long-standing operations in Nigeria, Mozambique, Kenya, Ethiopia, Ghana, Tanzania, South Africa, Egypt and Morocco. This presence gives us a unique vantage point to bridge African priorities with global dialogue.

Africa holds some of the world’s largest reserves of natural gas, oil, and minerals, as well as enormous potential in renewables. ADIPEC is committed to supporting this potential by convening African voices alongside global leaders, unlocking partnerships that can expand access, accelerate industrialisation, and strengthen Africa’s contribution to global energy progress.

Some of ADIPEC 2025’s notable African speakers include: Honourable J. Opiyo Wandayi, Cabinet Secretary for Energy and Petroleum, Kenya; Honourable Sen. Dr. Heineken Lokpobiri, Minister for State (Oil), Petroleum Resources, Nigeria; Rt. Honourable Ekperikpe Ekpo, Minister for State (Gas) Petroleum Resources, Nigeria; Honourable Chief Adebayo Adelabu, Minister of Power, Nigeria; Honourable Julius D. Mattai, Minister of Mines and Mineral Resources, Republic of Sierra Leone; Honourable Ruth Nankabirwa Ssentamu, Minister of Energy and Mineral Development, Uganda; His Excellency Karim Badawi, Minister of Petroleum and Mineral Resources, Arab Republic of Egypt; His Excellency Antonio Oburu Ondo, Minister of Mines and Hydrocarbons, Equatorial Guinea, Honorable Julius D. Mattai, Minister of Mines and Mineral Resources, Republic of Sierra Leonne; Honourable July Moyo, Minister of Energy and Power Development, Zimbabwe; His Excellency Nani Juwara, Minister of Petroleum and Energy, Gambia; Honourable Cheikh Niane, Deputy Minister of Petroleum and Energy, Senegal, and Mathias Katamba, board chairman, Uganda National Oil Company.

Tony Attah, managing director and chief executive officer, Renaissance Africa Energy Company. (Image source: Alain Charles Publishing)

NNPC is reviewing its portfolio.

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