The Aseng Gas Monetisation Project offshore Equatorial Guinea will undergo subsea installation by Subsea7, which has received a significant contract by Noble Energy EG Ltd (a Chevron Company)
Subsea7 will be establishing a single-well tieback for the project, connecting Aseng field to the existing Alen platform. It will transport and install approximately 19 kilometres of rigid production flowline and 20 kilometres of umbilicals, along with associated subsea structures and tie-ins in water depths of 800 metres.
Project management and engineering will commence immediately and will be managed from Subsea7’s Paris office, with additional support from teams in Lisbon and Equatorial Guinea. Offshore activities are expected to begin in 2026.
David Bertin, Senior Vice President for Subsea7’s Global Projects Centre East, said, “This award represents an important milestone in our ongoing global relationship with Chevron. Subsea7 has operated in Equatorial Guinea for nearly two decades, supporting offshore construction and inspection, maintenance and repair activities. We look forward to continuing our collaboration with Chevron on the Aseng Gas Monetisation Project, continuing to deliver safe, high-quality offshore installation services in West Africa.”
Global technology company SLB has announced a three-year agreement with Azule Energy to extend and enhance the use of its enterprise digital platform across Azule’s operations in Angola
The platform aims to drive more consistent execution, speed up decision-making, and support reliable energy delivery throughout Azule’s portfolio.
Azule Energy, a joint venture between bp and Eni and the largest independent energy producer in Angola, manages some of the country’s most complex assets. This new agreement builds on two years of Delfi use within Azule’s reservoir organization, where the platform supports reservoir studies, modelling, simulation, and well planning workflows, while enabling enterprise-wide digital integration by connecting reservoir workflows with wider operational data environments over time.
“Azule operates large, complex energy assets where execution reliability and consistency matter,” said ND Maduemezia, president, Europe and Africa, SLB.
“This agreement expands the use of an enterprise digital platform that connects workflows and data, strengthening and accelerating decision-making and improving execution predictability in support of reliable energy delivery in Angola.”
The agreement highlights Azule’s shift toward enterprise-scale digital operations, leveraging SLB’s platform and cloud-based capabilities. Implementation is supported through the SLB Luanda Performance Center, which allows digital solutions to be deployed and maintained locally.
The platform supports critical workflows across Azule’s reservoir and planning functions, with gradual integration into broader operational data systems. It also positions Azule to quickly adopt emerging digital and AI-driven technologies, enabling continuous performance enhancements.
Early results demonstrate tangible benefits: integrated workflows, including DrillPlan coherent well planning and engineering solutions, have shortened planning cycles from days to hours while boosting automation and reducing manual coordination.
The enterprise platform strengthens execution consistency across Azule’s large, mature operations, where operational discipline is key to sustaining performance.
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With an aim to achieve a potential gross production uplift of around 9,000 barrels of oil per day, Afentra has secured contracts to advance its accelerated two-well drilling programme on Block 3/05 offshore Angola.
The primary objective will help define the material upside potential in the Pacassa SW area (up to 70 mmbo recoverable) and the Impala field (up to 50 mmbo recoverable).
The Block 3/05 Joint Venture partners have signed a commercial agreement with Sonangol to use the Borr Grid jackup rig for the well programme. It will begin with the drilling of Pacassa SW, which will determine the next well eligible for drilling, be it the Pacassa SW injection well or the Impala-2 development well.
The Pacassa field which is anticipated to hold up to 210 mmbbls of oil will be drilled from the Pacassa F4 platform. If the drilling is a success, the well will be put to completion before connecting it to the existing production infrastructure.
The Impala field, on the other hand, can potentially play a significant role in defining the upside potential of the field that can contain up to 200mmbo of oil in place. Impala-2 will be drilled from the Impala wellhead platform into the Impala field around 1000m from the existing Impala-1 production well. Upon completion the well will be connected to the existing production infrastructure. The outcome will also assist in defining the optimum Impala field development which has up to 50mmbo of incremental recoverable resources.
"The ability to accelerate our drilling programme is a pivotal moment for Afentra, marking a clear transition to the execution phase of our organic growth strategy. This opportunity is a direct result of the strong, collaborative partnership we have with Sonangol and the Joint Venture. The funding structure agreed with Sonangol allows us to fast-track the unlocking of significant potential value from both the Pacassa SW area and the Impala field without impacting our 2026 cash capex. This programme is designed to efficiently convert resources into production, growing volumes through our existing infrastructure and delivering tangible value for our shareholders. Crucially, it will also provide invaluable data to de-risk and define future prospectivity across the wider Block 3/05 area, optimising our long-term development plan," said Paul McDade, Chief Executive Officer of Afentra.
bp and Eni venture, Azule Energy, has announced start-up of gas production from the Quiluma field, part of the New Gas Consortium (NGC) in Angola, which is initially expected to reach 150 mn standard cu/ft per day and ramp up to 330 mn standard cu/ft per day by the year end.
A first for Angola's non-associated gas development, the NGC project is driven by gas produced from the shallow water offshore Quiluma field. This gas is directed for export from the Angola LNG plant following treatment at an onshore processing facility.
Azule Energy is operator of the NGC, with a 37.4% participation, in partnership with Cabinda Gulf Oil Company (CABGOC) with 31%, Sonangol E&P with 19.8% and TotalEnergies with 11.8% and ANPG as the National Concessionaire.
Gordon Birrell, bp’s executive vice president for production and operations, and Azule board member, said, "The safe delivery of the NGC project is another example of bp’s strategic progress and demonstrates what strong partnerships and collaboration can deliver. This project marks an important step for Angola’s energy system and strengthens the country’s energy mix as it looks to enhance its position as a global player in the natural gas market.”
This development comes following the inauguration the project’s gas treatment plant in November 2025. The NGC start-up is the latest in a series of upstream advancements such as the Agogo field at the Agogo Integrated West Hub (Agogo IWH) project, in block 15/06, offshore Angola, and the Ndungu start-up in February 2026.
Eni has announced two new gas discoveries offshore Libya following an exploration campaign carried out in recent months.
The finds are located within two nearby geological structures, Bahr Essalam South 2 (BESS 2) and Bahr Essalam South 3 (BESS 3). These were confirmed through drilling activities at the B2-16/4 and C1-16/4 wells, positioned around 85 km offshore in water depths of approximately 650 feet and about 16 km south of the Bahr Essalam gas field.
Both wells intersected gas bearing zones within the Metlaoui Formation, which is recognised as the primary producing reservoir in the region. Analysis of the data suggests a high quality reservoir, with strong productivity already verified through testing conducted on the first well.
Initial estimates indicate that the combined gas resources of the BESS 2 and BESS 3 structures exceed 1 trillion cubic feet (Tcf). Their close location to the Bahr Essalam field, Libya’s largest offshore gas field, operational since 2005, means development can be fast tracked by linking the discoveries to existing offshore infrastructure. The extracted gas is expected to serve both domestic demand in Libya and exports to Italy.
Eni has maintained a long standing presence in Libya since 1959 and remains the country’s leading international energy operator. In 2025, the company reported equity production of approximately 162,000 barrels of oil equivalent per day and is currently advancing three development projects, with two scheduled to come online in 2026.
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.
Following a period of challenging drilling work, including horizontal wells, Lime Petroleum has confirmed that the hook-up of its Mobile Offshore Production Unit (MOPU) and Floating Storage and Offloading unit (FSO) has been completed on the Sèmè field in Benin.
After the FSO Kristina was anchored in place, a flow-line was laid from the Stella Energy 1 MOPU to the FSO.
“Commissioning of the production system is well underway, with oil now flowing into the FSO,” a Lime Petroleum statement noted on 5 March, 2026.
Over the coming days, further testing and commissioning will take place, with the aim to optimise production rates and start regular production, it added.
However, drilling operations proved a challenge, the company reported earlier in February.
While the latest operational milestones marked an important step forward, it noted that drilling operations “encountered significant technical complications” — this resulted in a “material increase in drilling costs and a production delay of more than three months.”
The delays and complications brought with them knock-on financial implications, it added.
At the field, it follows the drilling of the AK-2H production well by Lime Petroleum’s wholly-owned indirect subsidiary Akrake Petroleum Benin.
A total of 1,405 metres was drilled horizontally through the reservoir section at the site.
The well was geo-steered using advanced Logging While Drilling (LWD) tools to ensure the well only encountered oil-bearing reservoir sandstone.
The Sèmè Field, discovered by Union Oil in 1969, is located in Benin’s Block 1in shallow water depth of 20 to 30 metres.
It was first developed by Norwegian oil company, Saga Petroleum, and had produced approximately 22 MMbbl1 between 1982 and 1998, before production was stopped prematurely due to low oil prices of around US$14 per barrel in 1998.
KOIL Energy Solutions Inc. has secured a major contract from an international oil company to support an offshore development project in West Africa, reinforcing its role in delivering specialised services for deepwater energy projects
The company will provide load out, transit oversight, installation monitoring and pre-commissioning services as part of the development. The contract covers a comprehensive range of activities, including engineering support, project management, offshore and onshore personnel, as well as specialised rental equipment required for subsea operations.
As part of the project, KOIL Energy will deploy its personnel and equipment to transportation and installation vessels, as well as to quayside locations and offshore production facilities. The work will involve supporting the installation and pre-commissioning of several subsea umbilical systems that will connect to an existing deepwater production field.
Mobilisation for the project is expected to begin during the second half of 2026.
"This contract is a recognition of our company’s capabilities of delivering mission-critical services to deepwater developments internationally," said Erik Wiik, CEO of KOIL Energy. "It is also a testament to our teams’ expertise in testing of advanced deepwater systems and helping customers bring production online efficiently and safely."
KOIL Energy is widely recognised for delivering subsea systems and services that support offshore oil and gas projects throughout their lifecycle. The company’s specialised testing equipment and operational methodologies are designed to help operators accelerate project timelines and move more quickly toward production.
Founded in 1997 and headquartered in Houston, KOIL Energy provides engineering expertise, subsea equipment and technical support services to energy and offshore industry clients worldwide. Its team of engineers and manufacturing specialists focuses on developing solutions for complex subsea challenges while supporting energy projects across global offshore markets.
VAALCO Energy has announced encouraging operational advancements in its West African assets, highlighting successful drilling results in Gabon and confirmation of its operatorship in a key discovery offshore Côte d’Ivoire.
In Gabon, the company has successfully drilled, completed, and brought online the Etame 15H-ST development well within the Etame field’s 1V block.
The well encountered a 250 m lateral section of net pay in high-quality Gamba sands positioned near the reservoir top.
It has achieved a stabilised flow rate of approximately 2,000 gross barrels of oil per day (BOPD), with a 38% water cut, produced through a 42/64 choke and an electrical submersible pump (ESP) operating at 54 Hz.
This performance aligns closely with expectations derived from the earlier ET-15P pilot well.
VAALCO is actively managing the well to stabilise reservoir pressure and optimise long-term output.
The drilling rig has remained on the Etame platform, and in mid-February, it spudded a step-out exploration well targeting the West Etame (ET-14P) prospect.
This well, drilled from the S1 slot, carries a 57% chance of geological success and is anticipated to reach the target zone by mid-March.
Should it prove successful, the prospect could deliver significant additions to production and reserves by the end of 2026.
Turning to Côte d’Ivoire, VAALCO has been formally confirmed as operator of the Kossipo field on the offshore CI-40 block, holding a 60% working interest, with partner PetroCI retaining 40%.
The Kossipo field, originally discovered in 2002 by the Kossipo-1X well and appraised in 2019 by Kossipo-2A (which tested at over 7,000 BOPD), lies southwest of the producing Baobab field.
Recent ocean bottom node (OBN) seismic data has enhanced and de-risked VAALCO’s updated evaluation and development strategy.Independent estimates indicate gross 2C contingent resources of approximately 102 million barrels of oil equivalent (MMBOE), with around 293 MMBOE in place.
The company anticipates completing a field development plan during the second half of 2026.
Additionally, the Baobab Ivorien FPSO (formerly MV10), currently positioned off the east coast of Africa, is expected to return to Côte d’Ivoire waters by late March, supporting resumed operations and future drilling on the block.
These updates underscore VAALCO’s focus on organic growth through targeted drilling and field development in its core African portfolio.
The company expressed optimism about enhancing production profiles and reserves in both regions
Eni has announced a major oil discovery following the successful drilling of the Algaita-01 exploration well in Block 15/06 offshore Angola.
The well is located approximately 18 km from the Olombendo FPSO, with preliminary assessments indicating oil in place of around 500 million barrels.
Drilling operations began on 10 January 2026 using the Saipem 12000 drillship in water depths of 667 metres. The well intersected multiple oil-bearing sandstone intervals within Upper Miocene formations. These reservoirs have been described as having strong petrophysical characteristics, supporting their commercial potential. An extensive data gathering programme, including fluid sampling, confirmed both reservoir quality and favourable fluid properties.
The proximity of established production facilities, including the Olombendo floating production, storage and offloading unit, strengthens the economic case for development. Access to nearby infrastructure is expected to shorten development timelines and optimise capital expenditure, improving the overall viability of bringing the resource on stream.
Block 15/06 is operated by Azule Energy, which holds a 36.84% interest, in partnership with SSI (26.32%) and Sonangol E&P (36.84%). Azule Energy is jointly owned by Eni and bp, and the latest find further reinforces the consortium’s upstream position in Angola.
The discovery highlights the continued exploration potential of Angola’s offshore basins, particularly within mature producing blocks where near-field opportunities can deliver material additions to reserves. By leveraging existing infrastructure and technical expertise, operators are increasingly able to unlock value from adjacent prospects while maintaining cost discipline.
Looking ahead, appraisal activities will likely focus on refining reserve estimates, evaluating development concepts and assessing tie-back options to current facilities. If progressed efficiently, the Algaita-01 discovery could contribute meaningfully to Angola’s medium-term production outlook, supporting national revenue generation and strengthening the country’s role as a key hydrocarbon producer in sub-Saharan Africa.
Perenco Congo has installed the new Kombi 2 platform with connection work currently underway on the Kombi-Likalala-Libondo II (KLL II) field, before commissioning begins early March.
This marks the first redevelopment move in more than 20 years since the drilling of its last well.
The field's future performance will stand secured from Kombi 2's new-generation infrastructure that ensures improved water and effluent treatment and increased associated gas recovery. On top of that, two gas turbines will generate 8 MW of electricity for greater energy autonomy for operations.
Designed to meet global sustainability standards, the six-well drilling campaign starting this year will involve production optimisation, enhanced field recovery, and field-life extension work, all of which will be supported by the forward-looking Kombi 2 platform.
Considering it a historic field, Perenco Congo has invested more than US$200mn with a long-term strategy in the region. “This project is a concrete example of Perenco's commitment to investing in high-performance, responsible, and value-creating infrastructure that promotes the sustainable development of national resources,” said Gregoire de Courcelles, managing director of Perenco Congo.
The outlook for well support, interventions and other associated services across West Africa should be buoyed by the prospect of high levels of wildcat drilling this year.
According to analysis by Rystad Energy, the global upstream sector is set to carry strong momentum into 2026, with high-impact drilling activity expected to remain elevated following a solid 2025.
Africa is set to continue leading global activity, it estimates, accounting for around 40% of planned high-impact exploration wells, driven largely along the Atlantic margin, with exploration expected to focus on the Orange Basin in southern Africa and the Gulf of Guinea in West Africa, reinforcing the region’s role in global high-impact drilling.
Wells are designated as high-impact based on a variety of factors: the size of the potential resources, whether they could open new hydrocarbon plays in frontier or emerging basins, and their significance to the operator.
Such activity in 2026 is expected to drive exploration momentum higher in specific basins and countries, with 42 such wells identified globally — close to half of them in Africa.
Last year, the success rate for high-impact wildcat wells rose to 38% from 23% in 2024, while total discovered volumes increased by 53% year on year to around 2.3 billion barrels of oil equivalent (boe), according to Rystad Energy.
What we are seeing in 2026 is a clear shift in which where operators are willing to deploy capital, according to Aatisha Mahajan, Rystad Energy’s Head of Exploration, Oil & Gas Research.
“Ultra-deepwater and frontier plays remain capital-intensive, but they also offer scale and material upside at a time when conventional opportunities are increasingly limited,” Mahajan said.
“Africa stands out because it still combines geological potential with the prospect of large, commercially meaningful discoveries, particularly for operators looking to secure long-life resources in a tightening global supply environment.”
Of around 17 potential high-impact wells across Africa during 2026, nearly all are offshore, with just a few onshore.
The continent scores twice as many proposed wells as Asia, the next busiest region, followed by South America and Europe.
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