In The Spotlight
Scatec is targetting to reach financial close over the next 12 months. (Image source: Scatec ASA)
Renewable energy solutions provider, Scatec ASA, has signed a 25-year US$-denominated corporate power purchase agreement (PPA) with Egypt Aluminium for a 1.1 GW Solar PV + 100 MW/200MWh BESS project in Egypt backed by a sovereign guarantee.
Egypt Aluminium exports approximately 60% of its production to Europe. This solar PV + BESS project will be instrumental for Egypt Aluminium’s ambition to decarbonise its aluminium production, and to meet EU’s Carbon Border Adjustment Mechanism (CBAM) requirements which will be introduced in 2026.
The key next steps for the project are to work with the relevant authorities to allocate land, finalise grid connection and secure financing, and Scatec targets to reach financial close and start construction within the next 12 months.
“This is another testament to Scatec’s position as one of the leading renewables companies in Egypt. It is a groundbreaking project as it is the first utility scale PPA in the country with an industrial offtaker. I would like to thank all parties involved for making this happen, especially our partners at Egypt Aluminium. Further, our team has shown great persistence and creativity in securing this agreement and bringing new solutions to the market,” said Scatec CEO Terje Pilskog.
The estimated total capital expenditure for the solar PV + BESS project is approximately USD 650 million which will be funded by approximately 80% non-recourse project debt, and the remainder by equity from Scatec and partners. Scatec owns 100% of the project but is targeting to reduce its long-term economic interest by inviting additional equity partners. Scatec will be the designated EPC service provider, with an EPC share of approximately 90% of total capex, as well as asset manager (AM) and operations and maintenance (O&M) service provider.
Andrew Law, CEO at Enteq. (Image source: Enteq Technology)
Energy services engineering and technology company, Enteq Technologies, has launched Saber Vertical, an advanced drilling solution designed to enhance efficiency and reduce operational complexity for vertical and top-hole drilling
Saber Vertical extends the existing advantages of Enteq’s directional drilling rotary steerable system (RSS), the Saber Tool, to vertical drilling, offering a low-service requirement and modular design that minimises both equipment needs and overall costs.
In regions such as the Middle East and Africa, vertical wells are often drilled in remote and demanding environments, making traditional methods expensive and logistically complex. Engineered in response to market demand and industry challenges, this innovative solution provides operators with greater accuracy, control and wellbore stability, helping to deliver a lower total cost of ownership than other systems available today.
The modular design enables adaptability to multiple hole sizes, reducing equipment requirements and enhancing operational flexibility. Its optimised wellbore stability improves drilling accuracy and control, ensuring greater precision throughout the process. The solution is also low-risk and can be deployed globally in a variety of environments, making it a practical and scalable option for operators worldwide.
Andrew Law, CEO at Enteq, said, "Saber Vertical is the result of listening to our customers and understanding the unique challenges of the market. It is inevitable that incumbent solutions for these applications are expensive due to the required large tool size, limiting commercially suitable options available to the market. With its compact design and cost-effective nature, Saber Vertical delivers a much-needed alternative, helping operators improve efficiency without compromising on performance."
26 blocks will be auctioned. (Image source: Adobe Stock)
The Government of Tanzania will be auctioning 26 petroleum exploration blocks through the Petroleum Upstream Regulatory Authority (PURA) to attract investment flow in the country's oil and gas industry, said the director general of PURA, Charles Sangweni, at the 11th East African Petroleum Conference and Exhibition (EAPCE’25) held recently in Dar es Salaam
Sangweni said that, of the 26 blocks, 23 are in the deep offshore of the Indian Ocean and three are in Lake Tanganyika.
“The demarcated blocks are located in strategic areas since the deep offshore is where a significant amount of natural gas was discovered and the case of Lake Tanganyika, the Lake is located in the East African Rift System (EARS) where neighboring countries (Kenya and Uganda) discovered oil in basins located in similar geological setting,” said Sangweni.
PURA used the EAPCE’25 as a platform to continue promoting the upcoming licensing round and investment in petroleum exploration blocks in the country for that is one of its responsibilities.
The well was spudded last November. (Image source: Adobe Stock)
The Nigerian National Petroleum Company Limited (NNPC Limited) and FIRST Exploration & Petroleum Development Company Limited (FIRST E&P) joint venture have announced a hydrocarbon discovery in the Songhai Field, located in OML 85 in the shallow offshore region of Bayelsa
The well was spudded last November as part of efforts to increase and sustain the JV’s oil production over the next five years. It was successfully drilled to a total depth of 8,883 feet measured depth (MD) in 30 meters of water. The well encountered hydrocarbons across eight reservoirs, logging over 1,000 feet of hydrocarbon-bearing sands, most of which exhibit excellent reservoir properties. Preliminary analysis indicated substantial oil and gas volumes, reinforcing the field’s commercial potential. Further evaluations, including formation testing and well data integration, will be conducted to refine resource estimates and optimise field development plans.
Speaking on the discovery, Segun Owolabi, general manager, Exploration and Development at FIRST E&P, said "This discovery marks a major milestone in our efforts to unlock the full potential of our assets. The success at Songhai Field underscores the effectiveness of our exploration strategy and our commitment to delivering sustainable value to all stakeholders."
The discovery is strategically important for the joint venture in supporting Nigeria’s production growth and cost optimisation targets. Seyi Omotowa, chief upstream investment officer of NUIMS, noted that the success at Songhai Field aligns with NNPC Limited’s broader upstream objectives. "This aligns with NNPC Limited’s mandate to drive production growth and cost optimisation. The success at Songhai Field reflects our commitment to strategic partnerships, advanced technology, and efficient operations to maximise Nigeria’s hydrocarbon potential sustainably," he said. The discovery also highlights the role of strategic collaboration in expanding Nigeria’s hydrocarbon reserves.
NNPC Limited’s Group Chief Executive Officer, Mallam Mele Kyari, reaffirmed the company’s commitment to efficiency and long-term value creation. "This discovery reaffirms the potential of Nigeria’s offshore assets and the importance of collaboration in boosting reserves and production. NNPC Limited remains committed to driving efficiency and long-term value creation for the nation," Kyari said. Currently, the joint venture maintains a steady daily production of approximately 57,000 barrels of oil per day from its OML 83 and 85 assets. The new discovery in Songhai Field is expected to further enhance production and contribute to Nigeria’s energy security.
Furthermore, the NNPC/FIRST E&P JV remains committed to operational excellence, guided by rigorous safety standards, technical expertise, and efficient project execution. With more than 9 million man-hours of LTI-free operations, the JV continues to lead in safe and responsible hydrocarbon development. This milestone strengthens Nigeria’s oil and gas sector, reinforcing the JV’s role in supporting the Federal Government’s goal of increasing national hydrocarbon production and reserves while ensuring sustainable energy growth.
Savannah plans an 18-month expansion programme at Stubb Creek. (Image source: Savannah Energy)
British independent energy company, Savannah Energy PLC, has completed the acquisition of Sinopec International Petroleum Exploration and Production Company Nigeria Limited (SIPEC), whose principal asset includes 49% non-operated interest in the Stubb Creek oil & gas field
The Stubb Creek field is operated by Savannah-affiliate Universal Energy Resources Limited with a 51% ownership.
The acquisition boosts Savannah's reserves and resources base by approximately 30% from 151mn barrel of oil equivalent to 197mn boe, and adds 227bn standard cubic feet of 2C gross gas resources at Stubb Creek Field. This ensures a long-term feedstock gas back up for commercial purposes.
The Stubb Creek field will be prepared for further production boost to approximately 4.7k bopd from the current 2.7kbopd as Savannah plans an 18-month expansion programme. "We are delighted to announce the completion of the SIPEC Acquisition - the achievement of one of our core business priorities for 2025. Our focus at the Stubb Creek Field will now turn to progressing the expansion project, which we expect to increase production by almost three quarters over the course of 2025/26," said Andrew Knott, Chief Executive Officer of Savannah.
Stubb Creek Field, located in Akwa Ibom State, Nigeria, is a producing oil field with considerable undeveloped, non-associated 2C gas resources. Commercial oil production started at Stubb Creek Field in 2015, with cumulative production of 8.1 MMstb to 31 December 2024. Oil produced at Stubb Creek Field is processed through production facilities onsite and then exported to the Qua Iboe terminal via a 25 km pipeline. The Stubb Creek Field was converted to a 20-year petroleum mining lease, PML20, in accordance with the Petroleum Industry Act 2021 and effective from 1 December 2023.
High hopes in the Niger Delta for Africa Oil (IMAGE SOURCE: Adobe Stock)
Canada’s Africa Oil Corporation has said it hopes to double output and reserves from Nigeria after it takes on full ownership of the privately-owned Netherlands-based company, Prime Oil & Gas, in the coming week
“On closing of that deal we will significantly change the scale of our business, we will double production, we double reserves and significantly boost our liquidity position,” Oliver Quinn, chief commercial officer at Africa Oil told Reuters news agency in an interview.
Assets held by Prime Oil & Gas Coöperatief U.A. — formerly known as Petrobras Oil & Gas — include indirect stakes in deepwater producing Nigerian fields operated by heavyweights Chevron and TotalEnergies.
The non-operating player has a stake in key oil blocks such as PML 2, 3, 4, and PML 52, in the Niger Delta region.
Following the acquisition, Africa Oil expects to produce around 35,000 barrels per day (bpd), Quinn told Reuters.
“They are very significant value barrels because they have very low lifting cost of under US$10, so the margin on the barrels is high and typically sell at premium to Brent.”
As well as boosting its presence in Nigeria, the company has a foothold in Namibia’s dynamic Orange Basin, arguably the hottest exploration property in Africa right now, with a stake in Impact Oil and Gas and exposure to the Venus discovery.
Africa Oil also has exposure to Equatorial Guinea, another major West African oil and gas producer.
On 27 February, Africa Oil’s president and CEO, Roger Tucker, presenting the company’s full-year results for 2024, said it had been a “transformative year” already, and one that will be enhanced again with the acquisition of Prime Oil & Gas.
“This transformational milestone will significantly enhance our scale, financial strength, and ability to deliver meaningful shareholder value,” he said, referring to the acquisition.
"The enlarged Africa Oil will benefit from robust long-term free cash flows and a strong balance sheet with low leverage. We will have direct interests in producing assets in Nigeria, complemented by funded development and exploration projects in the prolific Orange Basin.”
In Namibia, a final investment decision on the Venus discovery by operator TotalEnergies is expected to be taken in 2026, which could further swell Africa Oil’s production numbers.
“Our focus is to add to the cash generation machine, which runs through the decade while on the backend Namibia Venus comes onstream and then we have significant growth in that asset,” Quinn told Reuters.
Read more:
Africa Oil aims for high impact exploration
Orange Basin to be a top drilling zone in 2025 finds Westwood
BP’s GTA project will boost global LNG supply (IMAGE SOURCE: BP)
A potential gas leak has been revealed from a well at the flagship Greater Tortue Ahmeyim (GTA) project, located offshore Mauritania and Senegal
Operator BP said that it had detected subsea gas ‘bubbles’ at one of its wells, A02, during a planned commissioning test at the project site, which straddles the border between the two West African countries.
The company has put in place a plan to rectify any issues but added that the incident would not disrupt output or create any significant environmental impact.
“We have a plan to stop the bubbles,” the company told Reuters in an email statement.
“As part of that plan we have mobilised specialised equipment and personnel to support the rectification efforts.”
BP is developing the mega project alongside US-listed partner Kosmos Energy and two minority stakeholders, Petrosen and SMH.
Mauritania's oil ministry adviser, Ahmed Vall Ould Mohameden, was also cited by the news agency as saying that similar incidents can often occur at the start of production.
"Last week a plane carrying equipment to plug the leak was sent to the site to repair it."
The GTA project produced its first gas at the start of 2025 and is set to become a major gas exporter in the years ahead, producing 2.3 million metric tons of liquefied natural gas (LNG) a year during a first phase.
According to BP, it represents one of the deepest and most complex gas development projects yet in Africa, with gas resources located in water depths of up to 2,850 metres.
Gas from GTA Phase 1 is sent to the GTA floating production storage and offloading (FPSO) approximately 40 km offshore, where water, condensate and impurities are removed.
From there, the gas is transferred via pipeline to a floating liquefied natural gas (FLNG) vessel 10 km offshore, to be cryogenically cooled, liquefied and stored before being transferred to LNG carriers for export.
Some of the gas is also being allocated to help meet growing energy demand in the two host countries.
Read more:
African LNG projects set to benefit with natural gas seen as a bridge fuel in the energy transition
FLNG Gimi receives feed gas from GTA project offshore Mauritania and Senegal
BP's Greater Tortue Ahmeyim offshore Mauritania and Senegal sees first gas
Scatec is targetting to reach financial close over the next 12 months. (Image source: Scatec ASA)
Renewable energy solutions provider, Scatec ASA, has signed a 25-year US$-denominated corporate power purchase agreement (PPA) with Egypt Aluminium for a 1.1 GW Solar PV + 100 MW/200MWh BESS project in Egypt backed by a sovereign guarantee.
Egypt Aluminium exports approximately 60% of its production to Europe. This solar PV + BESS project will be instrumental for Egypt Aluminium’s ambition to decarbonise its aluminium production, and to meet EU’s Carbon Border Adjustment Mechanism (CBAM) requirements which will be introduced in 2026.
The key next steps for the project are to work with the relevant authorities to allocate land, finalise grid connection and secure financing, and Scatec targets to reach financial close and start construction within the next 12 months.
“This is another testament to Scatec’s position as one of the leading renewables companies in Egypt. It is a groundbreaking project as it is the first utility scale PPA in the country with an industrial offtaker. I would like to thank all parties involved for making this happen, especially our partners at Egypt Aluminium. Further, our team has shown great persistence and creativity in securing this agreement and bringing new solutions to the market,” said Scatec CEO Terje Pilskog.
The estimated total capital expenditure for the solar PV + BESS project is approximately USD 650 million which will be funded by approximately 80% non-recourse project debt, and the remainder by equity from Scatec and partners. Scatec owns 100% of the project but is targeting to reduce its long-term economic interest by inviting additional equity partners. Scatec will be the designated EPC service provider, with an EPC share of approximately 90% of total capex, as well as asset manager (AM) and operations and maintenance (O&M) service provider.
26 blocks will be auctioned. (Image source: Adobe Stock)
The well was spudded last November. (Image source: Adobe Stock)
Map showing Angola's Block 16 with additional TGS data (Image Source: TGS)
Norwegian seismic firm TGS has completed reprocessing work on data that it hopes will spur renewed interest in Angola’s forgotten deepwater Block 16
The company has announced that it had finished work on the Block 16 GeoStreamer MC3D seismic dataset in the Lower Congo Basin, in partnership with Agência Nacional de Petróleo, Gás e Biocombustíveis (ANPG).
Exploration in the deepwater Lower Congo Basin has experienced a resurgence in recent years, TGS reported, with numerous significant discoveries being made and rapidly brought on stream.
"This 3,684-sq-km rejuvenation project utilises modern depth processing workflows to deliver enhanced imaging beyond the original data, enabling detailed evaluation of deeper target plays in both post-salt and pre-salt sections,” it said in a statement.
Angola’s Block 16 has remained largely under explored since the early 2010s, however, with the most recent exploration well drilled in 2013. Until recently, publicly-known oil and gas discoveries within Block 16, in the latest dataset, were limited to the Bengo (1994) and Longa (1995) Upper Miocene finds in the northern section.
However, TGS said that a recent re-evaluation of wells in the Lower Congo Basin has identified oil recovery from Upper Miocene reservoirs in the southern part of the survey area. The survey also provides partial coverage of the field, a marginal field development opportunity currently being marketed by ANPG.
Discovered in 2003, Tchihumba contains hydrocarbon-bearing zones within Upper Miocene, Lower Miocene and Oligocene sands, with recoverable volumes estimated at approximately 136mn barrels.
Additionally, the Lumpembe-1 oil discovery on Block 15/06, drilled in 2023 and currently undergoing development studies, falls within the survey’s coverage.
“TGS is very pleased to continue our support of exploration in this region with our high-quality seismic data,” said David Hajovsky, executive vice president multi-client, TGS. “These accumulations, along with the proximity of significant neighbouring discoveries, present strong opportunities for future exploration success.”
Other West African projects TGS has completed recently include an enhancement of its Fusion 3D seismic dataset offshore Sierra Leone, focusing on the Vega prospect.
Recent discoveries in South America have intensified interest in this region, TGS stated late last year, positioning Sierra Leone as a promising new exploration frontier.
“With growing interest from international oil companies and independents, the Fusion 3D data comes at a crucial time.”
TGS also signed an agreement last year to enhance datasets in Mauritania with the Ministère du Pétrole, des Mines et de l’Énergie, strengthening its position as the sole provider of multi-client subsurface data in the country.
Read more offshore Angola news here:
Red Sky Energy signs risk service contract on Angola Block 6-24
Cabgoc's Sanha project achieves first gas offshore Angola
Sequa Petroleum to acquire interests in multiple blocks in Angola
The Seismic License provides Woodside ongoing rights to the PEL 87 3D seismic data. (Image source; Adobe Stock)
PetroVision will facilitate operations within Nigeria using DUG Insight software. (Image source: Adobe Stock)
Andrew Law, CEO at Enteq. (Image source: Enteq Technology)
Energy services engineering and technology company, Enteq Technologies, has launched Saber Vertical, an advanced drilling solution designed to enhance efficiency and reduce operational complexity for vertical and top-hole drilling
Saber Vertical extends the existing advantages of Enteq’s directional drilling rotary steerable system (RSS), the Saber Tool, to vertical drilling, offering a low-service requirement and modular design that minimises both equipment needs and overall costs.
In regions such as the Middle East and Africa, vertical wells are often drilled in remote and demanding environments, making traditional methods expensive and logistically complex. Engineered in response to market demand and industry challenges, this innovative solution provides operators with greater accuracy, control and wellbore stability, helping to deliver a lower total cost of ownership than other systems available today.
The modular design enables adaptability to multiple hole sizes, reducing equipment requirements and enhancing operational flexibility. Its optimised wellbore stability improves drilling accuracy and control, ensuring greater precision throughout the process. The solution is also low-risk and can be deployed globally in a variety of environments, making it a practical and scalable option for operators worldwide.
Andrew Law, CEO at Enteq, said, "Saber Vertical is the result of listening to our customers and understanding the unique challenges of the market. It is inevitable that incumbent solutions for these applications are expensive due to the required large tool size, limiting commercially suitable options available to the market. With its compact design and cost-effective nature, Saber Vertical delivers a much-needed alternative, helping operators improve efficiency without compromising on performance."
The partnership aims to accelerate innovation. (Image source: Adobe Stock)
Tullow will use Opsealog's tools to track vessels. (Image source: Opsealog)
BP’s GTA project will boost global LNG supply (IMAGE SOURCE: BP)
A potential gas leak has been revealed from a well at the flagship Greater Tortue Ahmeyim (GTA) project, located offshore Mauritania and Senegal
Operator BP said that it had detected subsea gas ‘bubbles’ at one of its wells, A02, during a planned commissioning test at the project site, which straddles the border between the two West African countries.
The company has put in place a plan to rectify any issues but added that the incident would not disrupt output or create any significant environmental impact.
“We have a plan to stop the bubbles,” the company told Reuters in an email statement.
“As part of that plan we have mobilised specialised equipment and personnel to support the rectification efforts.”
BP is developing the mega project alongside US-listed partner Kosmos Energy and two minority stakeholders, Petrosen and SMH.
Mauritania's oil ministry adviser, Ahmed Vall Ould Mohameden, was also cited by the news agency as saying that similar incidents can often occur at the start of production.
"Last week a plane carrying equipment to plug the leak was sent to the site to repair it."
The GTA project produced its first gas at the start of 2025 and is set to become a major gas exporter in the years ahead, producing 2.3 million metric tons of liquefied natural gas (LNG) a year during a first phase.
According to BP, it represents one of the deepest and most complex gas development projects yet in Africa, with gas resources located in water depths of up to 2,850 metres.
Gas from GTA Phase 1 is sent to the GTA floating production storage and offloading (FPSO) approximately 40 km offshore, where water, condensate and impurities are removed.
From there, the gas is transferred via pipeline to a floating liquefied natural gas (FLNG) vessel 10 km offshore, to be cryogenically cooled, liquefied and stored before being transferred to LNG carriers for export.
Some of the gas is also being allocated to help meet growing energy demand in the two host countries.
Read more:
African LNG projects set to benefit with natural gas seen as a bridge fuel in the energy transition
FLNG Gimi receives feed gas from GTA project offshore Mauritania and Senegal
BP's Greater Tortue Ahmeyim offshore Mauritania and Senegal sees first gas
Africa's LNG sector poised for growth (IMAGE SOURCE: Adobe Stock)
The ESIA approval will help advance pilot production activities. (Image source: Adobe Stock)
Diesel, petrol and kerosene were delivered. (Image source: NNPC)
The Nigerian National Petroleum Company (NNPC) Ltd has restreamed the Port Harcourt Refining Company (PHRC), commencing crude oil processing from the plant for the delivery of petroleum products into the market
The NNPC group chief executive officer, Mele Kyari, announced the development, expressing his gratitude to all stakeholders involved, and marked the occasion as an era of energy independence and economic growth for the country.
Products delivered included premium motor spirit (PMS), automotive gas oil (AGO) and household kerosene (HHK), among others.
The PHRC rehabilitation project, is an engineering, procurement, construction, installation and commissioning (EPCIC) project that is aimed at restoring the refinery to full functionality and renewal.
Claus Reimers, chief product and technology officer at Akselos. (Image source: Adobe Stock)
The Cabinda Refinery aims to double capacity to 60,000 bpd. (Image source: Adobe Stock)
The event will delve into regional success stories. (Image source: EAECS)
The East Africa Energy Cooperation Summit (EA-ECS), taking place 29-30 January in Arusha, Tanzania, will be uniting the region's energy independent poiwer producers (IPPs) and engineering, procurement, construction and financing contract (EPCF) stakeholders to discuss the region's investment potential and innovations taking place in the industry
The event will delve into the success stories, including the Ethiopia-Kenya electricity highway, highlighting the role of cross-border collaboration for economic and social development.
Led by Ministers from across the EAC and large-scale energy users, over two days, the Arusha Summit will deep dive into opportunities for the private sector, advocating for a diversified energy mix to maintain grid stability to support major industrial growth, as well as C&I generation.
“Energy is a pillar for development and growth and is crucial for the functioning of the economies of the EAC Partner States. The East Africa Energy Cooperation Summit will serve as the ideal platform for advancing projects and bringing tangible changes in the industry,” said Andrea Malueth, deputy secretary general (Infrastructure, Productive, Social & Political Sectors), East African Community Secretariat.
“Ten years from now, the EAC’s middle classes will have more job stability, more opportunities, and more disposable income than ever before. New railways, industries, ports, and tourism will position the region as the number one investment destination globally, taking the title back from both parts of Asia and Latin America,” said Elisa Palmioli, producer, EnergyNet, which is organising the event.
Libya is the next investment destination. (Image source: African Energy Chamber)
ADSW Summit 2025 to accelerate global sustainable development. (Image source: ADSW)
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Bourbon will utilise its data management system for end-to-end execution. (Image source: Adobe Stock)
The locations will employ locals and are expected to grow Namibia’s energy sector. (Image source: Halliburton)
The well was spudded last November. (Image source: Adobe Stock)
PetroVision will facilitate operations within Nigeria using DUG Insight software. (Image source: Adobe Stock)
Soudotec will initiate an inventory programme. (Image source: Svanehoj)
Umar Ajiya, chief financial officer, NNPC. (Image source: NNPC)
63 wells in Tilenga and 9 in Kingfisher have been drilled. (Image source: Adobe Stock)
There is a potential for an uptick in E&A drilling activity. (Image source: Westwood)
The enlarged Africa Oil is expected to have significant scale. (Image source: Adobe Stock)
Sanha Lean Gas Connection is a project by Cabinda Gulf Oil Company Limited. (Image source: Chevron)
The project could reduce the fleet’s GHG emissions by up to 10%. (Image source: Opsealog)
The onshore-focused NAOC is also involved in Nigeria's power generation industry. (Image source: Adobe Stock)
The two-month survey will be conducted early 2025. (Image source: Adobe Stock)
The facilities employ company-trained local workers. (Image source: Adobe Stock)
The Cabinda Refinery aims to double capacity to 60,000 bpd. (Image source: Adobe Stock)
The pump is ideally suited for applications with limited suction head. (Image source: Michael Smith Engineers)
The Olo and Olo West Fields were formerly part of OML 58. (Image source: Adobe Stock)
Independent Petroleum Marketers Association of Nigeria will acquire diesel at US$0.96 per l. (Image source: Adobe Stock)
Helium and hydrogen presence higher after re-drilling. (Image source: Adobe Stock)
Latest news
Scatec is targetting to reach financial close over the next 12 months. (Image source: Scatec ASA)
Andrew Law, CEO at Enteq. (Image source: Enteq Technology)
26 blocks will be auctioned. (Image source: Adobe Stock)
The well was spudded last November. (Image source: Adobe Stock)
Savannah plans an 18-month expansion programme at Stubb Creek. (Image source: Savannah Energy)
High hopes in the Niger Delta for Africa Oil (IMAGE SOURCE: Adobe Stock)
BP’s GTA project will boost global LNG supply (IMAGE SOURCE: BP)
Côte d’Ivoire offshore blocks (IMAGE SOURCE: Vaalco Energy)
Agogo FPSO set for Angolan offshore work (IMAGE SOURCE: Cosco)
Namibia's offshore is bringing new investment to the country. (Image source: Adobe Stock)
Bonga North boost for TechnipFMC. (Image source: Adobe Stock)
Map showing Angola's Block 16 with additional TGS data (Image Source: TGS)
Namibia's offshore has become hot property. (Image source: Adobe Stock)
Nigeria's independents are flourishing. (Image source: Adobe Stock)
Africa's LNG sector poised for growth (IMAGE SOURCE: Adobe Stock)
The partnership aims to accelerate innovation. (Image source: Adobe Stock)
The ESIA approval will help advance pilot production activities. (Image source: Adobe Stock)
The new wells are expected to produce around 220bn cubic feet of gas and 7 million barrels of condensate. (Image source: bp)
With this acquisition, UEG's current production will reach 39,000 boepd. (Image source: Adobe Stock)
Cutting emissions from flaring significantly reduces Algeria’s contribution to global warming. (Image source: Adobe Stock)
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Andrew Law, CEO at Enteq. (Image source: Enteq Technology)
The partnership aims to accelerate innovation. (Image source: Adobe Stock)
Tullow will use Opsealog's tools to track vessels. (Image source: Opsealog)
Leucipa will help optimise well performance. (Image source: Baker Hughes)
Africa Performance Centre is a collaborative hub. (Image source:
Virtual reality has emerged as a cost-effective option. (Image source: Adobe Stock)
According to Expro, the contract demonstrates its ability to provide technical solutions across the entire well lifecycle. (Image source: Expro)
This is the first project to use Subsea 2.0 configure-to-order solution. (Image source: Adobe Stock)
The new solution extends SLB's autonomous drilling capabilities. (Image source: SLB)
Intelli suite of diagnostic well intervention wireline logging services. (Image source: Halliburton)
The high-pressure radial shaft seal portfolio. (Image source: Trelleborg Sealing Solutions)
The agreement signing. (Image source: Kent)