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.
Halliburton has introduced the XTR CS injection system, a wireline-retrievable safety valve engineered for CO₂ injection in carbon capture, utilization, and storage (CCUS) wells.
The system offers flexibility, serving as a primary or backup safety valve or as a deep-set reservoir fluid-flowback prevention device. Unlike conventional surface-controlled wireline valves, the XTR CS injection system’s non-elastomeric design reduces leak paths and removes dependence on hydraulic operation systems. Its performance remains consistent at any depth, simplifying operations and inventory management.
The XTR CS injection system further strengthens Halliburton’s Completion Tools leadership in low-carbon technology solutions, enabling operators to optimize CCUS well performance. The system supports safe and efficient CO₂ injection, even in challenging environments.
Maxime Coffin, vice president, Halliburton Completion Tools, said, “The CS designation is a testament to Halliburton’s technology capabilities. The rigorous CS qualification program ensures the system’s operational integrity and survival capabilities in harsh CCUS environments.”
The system can be customized for specific injection media and fluid properties, delivering low opening force, minimal pressure drop, and a broad range of injection rates. To prolong operational life, high-velocity flow is directed away from seal areas, while a novel anti-throttle feature reduces valve wear, maximizing reliability.
“With the XTR CS injection system, Halliburton provides an adaptable solution to help operators achieve reliable CO₂ injection performance and advance their carbon management goals,” Coffin added.
President Bola Ahmed Tinubu has approved the gazetting of targeted, investment-linked incentives to support the proposed Bonga South West deep-offshore oil project by Shell and its partners.
The President also instructed the Special Adviser on Energy, Mrs. Olu Verheijen, to facilitate the gazette of the incentives in line with Nigeria’s legal and fiscal frameworks.
Speaking to a Shell delegation led by Global CEO Wael Sawan, President Tinubu said the incentives are disciplined, targeted, and globally competitive, aimed at attracting new capital without undermining government revenue.
He emphasised that the incentives are ring-fenced and investment-linked, focusing on new capital, incremental production, local content, and in-country value addition. “My expectation is clear: Bonga South West must reach a Final Investment Decision within the first term of this administration,” he said.
The President highlighted the strategic importance of Bonga South West to Nigeria’s economy, noting its potential to create thousands of jobs, generate foreign-exchange inflows, and deliver sustained government revenues. The project is also expected to deepen Nigerian participation in offshore engineering, fabrication, logistics, and energy services.
President Tinubu reaffirmed the administration’s commitment to policy stability, regulatory certainty, and speed, stressing that these reforms are vital for restoring investor confidence and positioning Nigeria as a preferred destination for large-scale energy investment.
Shell’s CEO, Wael Sawan, welcomed the developments, noting that Nigeria’s investment climate has improved significantly under the Tinubu administration and that Shell remains confident in long-term investment prospects in the country.
The Shell delegation included senior executives from both global and Nigerian leadership teams.
he Nigerian National Petroleum Company Limited (NNPC Ltd) has congratulated Chevron Nigeria Limited (CNL), operator of the NNPC Ltd/CNL Joint Venture, on the successful completion of the Awodi-07 appraisal and exploration well in the shallow offshore western Niger Delta
The Awodi-07 well was drilled as part of the Joint Venture’s ongoing programme to further delineate and unlock hydrocarbon potential within its asset portfolio. Drilling began in late November 2025 and was completed by mid-December 2025. All operations were carried out safely and efficiently, fully complying with approved operational and regulatory standards. After comprehensive testing, logging, and data acquisition, the well was secured, bringing the programme to a successful conclusion.
Results from Awodi-07 are highly encouraging, confirming the presence of hydrocarbons across multiple reservoir zones. The achievement marks a significant milestone for the NNPC Ltd/CNL Joint Venture, strengthening confidence in the underlying asset and reinforcing the prospectivity of the area. The well’s success further demonstrates the effectiveness of disciplined exploration, thorough technical evaluation, and strong operational collaboration between NNPC Ltd and Chevron Nigeria Limited.
Commenting on the accomplishment, Group Chief Executive Officer of NNPC Ltd, Bashir Bayo Ojulari, praised Chevron Nigeria Limited for its operational excellence, technical expertise, and consistent delivery of value.
“The success of the Awodi-07 well further reinforces the strength of the NNPC Ltd/CNL Joint Venture and our shared commitment to responsibly growing Nigeria’s hydrocarbon reserves. This achievement aligns squarely with our strategic priorities of increasing production, enhancing national energy security, and delivering sustainable value for the Nigerian people,” remarked Bayo Ojulari.
Speaking on the milestone, executive vice-president, Upstream, NNPC Ltd, Udy Ntia, described the results as evidence of the benefits of sustained collaboration, technical rigour, and a stable, enabling operating environment.
“This discovery underscores the importance of disciplined exploration programmes, strong partnerships, and the positive impact of the reforms introduced under the Petroleum Industry Act. We look forward to working closely with Chevron Nigeria Limited to mature this opportunity and progress it towards timely development and monetisation,” added Ntia.
NNPC Ltd and Chevron Nigeria Limited operate several oil and gas fields in Nigeria’s Niger Delta under a joint venture agreement. Chevron holds a 40% interest in the assets, while NNPC Ltd owns the remaining share. The partnership allows both companies to pool resources, technical expertise, and investment to develop Nigeria’s oil and gas resources efficiently.
Through this collaboration, the joint venture aims to increase oil production to approximately 146,000 barrels per day, supporting government revenue, creating jobs, and contributing to Nigeria’s energy supply.
Canada’s ReconAfrica has increased a private finance placement ahead of a major 2026 programme covering planning, pre-drill work, appraisal and testing across its West African assets.
The company reported that it increased the size of the finance offering from C$20mn to C$32mn due to strong investor demand.
In a statement, Brian Reinsborough, President and CEO, called the 2026 capital spend “the most comprehensive and diverse programme in ReconAfrica's history.”
It will fund multiple activities in parallel, including advancing the Kavango discovery in Namibia toward commerciality, advancing the exploration inventory of the newly discovered Damara Fold Belt play from Namibia into Angola, and progressing the Loba discovery on the Ngulu exploration block offshore Gabon to a drill-ready state.
Work at Namibia’s Kavango West 1X will include a production test after a decision was taken not to perform a drill stem test (DST) to allow for more controlled testing of isolated intervals of interest.
A production casing string will be installed from the surface down to a total depth of 4,260 metres to allow for more controlled testing of all hydrocarbon-bearing intervals and for the well to be completed as a potential producing well.
The activities in Namibia aim to position the company towards final investment decision and commercialisation of the Kavango discovery and the acceleration of first production, according to Reinsborough.
In Gabon, the company signed a production-sharing contract last year for the Ngulu block, located in shallow waters offshore.
After wading through seismic data, ReconAfrica plans to obtain a third-party resource report outlining the block’s potential with the goal of progressing the Loba field appraisal well to a drill-ready status.
In Angola, ReconAfrica plans to accelerate geochemical sampling of surface oil seeps in its MOU area and commence permitting for a potential 2D seismic programme as part of a broader evaluation of the Damara Fold Belt, with crews expected on site in April 2026.
As December 2025 draws to a close, West Africa's offshore oil and gas industry demonstrates steady momentum, driven by conferences, acquisitions, seismic advancements, and ongoing projects amid a challenging market for crude sales.
The MSGBC Oil, Gas & Power Conference, held 8-10 December in Dakar, spotlighted deepwater prospects in the Mauritania-Senegal-Gambia-Guinea-Bissau-Guinea-Conakry basin.
New seismic data highlighted frontier geology, while discussions emphasised LNG progress, green hydrogen, and investment opportunities in onshore/offshore blocks, particularly in The Gambia and Guinea-Conakry.
In Angola, Viridien launched a 4,300 sq km seismic reimaging programme over offshore Block 22 in the Kwanza Basin on 10 December, applying advanced technologies to support upcoming licensing rounds and enhance pre- and post-salt imaging.
BW Energy, in consortium with Maurel & Prom, announced on 12 December the acquisition of a combined 20% non-operated interest (BW's share: 10%) in Blocks 14 and 14K from Azule Energy (BP-Eni JV).
This marks BW's entry into Angola's mature deepwater sector, operated by Chevron, adding immediate production and upside potential.Investor interest persists in deepwater areas across Nigeria, Angola, and Ghana, bolstered by regulatory reforms and gas-focused policies.
ExxonMobil continues its planned US$1.5bn investment to revive Nigeria's Usan field, while Valaris secured a drillship contract for West Africa operations.
However, West African crude faces sales difficulties, with unsold cargoes for December-January loading due to global surplus and competition from cheaper supplies.
Ongoing milestones include the Greater Tortue Ahmeyim LNG project, which achieved first gas earlier in 2025 and is ramping up production.
The sector anticipates 2026 startups and final investment decisions, positioning West Africa for sustained growth despite market headwinds.(Word count: 348)
Seadrill Limited has announced new contract awards for its rigs West Neptune, Sevan Louisiana, and Sonangol Quenguela.
In the U.S. Gulf of Mexico, the West Neptune has secured a contract with LLOG Exploration. The four-month program is scheduled to begin immediately following the current contract, contributing approximately $48 million to Seadrill’s backlog.
Meanwhile, the Sevan Louisiana also received a contract award in the U.S. Gulf from an undisclosed operator for a two-month program. This engagement is set to start directly after its current contract with Walter Oil and Gas. The campaign will mark the first use of the Trendsetter well-intervention equipment in the region.
In Angola, an option for five wells has been exercised, extending the Sonangol Quenguela’s operations by around ten months, keeping the rig contracted through February 2027.
“These awards reflect Seadrill’s ability to contract preferentially in direct continuation to current contracts and avoid costly white space in a challenging market phase,” said Simon Johnson, President and Chief Executive Officer. “We continue to build backlog into 2026 and beyond, deepening longstanding partnerships with existing and repeat customers.”
As Reconnaissance Energy Africa reports a productive 2025 in its year-end corporate operational performance, the company is preparing to conduct a well test in Damara Fold Belt offshore Namibia.
“We are preparing to conduct a production test on Kavango West 1X, which will allow us to conduct a longer flow period and pressure buildup analysis to better calculate potential production rates and reserve estimates. Early planning suggests that we may test up to eight separate reservoir intervals of interest,” said Nick Steinsberger, Senior Vice President Drilling & Completions.
Unlike the usual process, the partners are prioritising production testing over a drill stem test to allow for more controlled testing of isolated intervals of interest. This way better addressed the operational challenges posed by a 2,000-m open hole section in adequately testing the entire gross Otavi reservoir at one time.
Production casing and testing equipment are being sourced before testing operations can be commenced in the first quarter of 2026. In a span of roughly two months, up to eight zones of interest will be evaluated.
Wireline logging from the Huttenberg and Elandshoek formations within the Upper Otavi Group have also indicated promising results. Well analysis from the Elandshoek sections shows 81 m of hydrocarbon fluorescence found in cuttings, a clear indicator of hydrocarbons. Indications of fracturing were pervasive based on well logs.
Also, rapid increases in gas readings after drilling connections indicated hydrocarbons flowing actively towards the wellbore.
“We have had an active and productive 2025 in which we advanced the Company on multiple strategic fronts. We completed drilling our second well in the Damara Fold Belt resulting in encountering of significant hydrocarbons, extended our acreage position into Angola at a low cost of entry and expanded our asset portfolio into offshore Gabon to help balance our investment risk profile. These actions set the Company up for several important milestones in 2026.
We are preparing for the production test at Kavango West 1X next year after only our second exploration well drilled in the Damara Fold Belt, a unique position to be in when exploring a new basin. Our teams are working on procuring the equipment needed for this test which is expected to commence operations by the end of the first quarter of 2026.
While recently visiting Namibia after our Kavango West 1X well results, the partnership group operated by ReconAfrica and including NAMCOR and BW Energy, had the privilege of meeting Her Excellency President Nandi-Ndaitwah. We are grateful for the President’s recognition of the significance of hydrocarbons encountered in the Kavango West well and how the partnership can help support onshore hydrocarbon development and the long-term energy supply for Namibia,” said Brian Reinsborough, President and CEO.
To reach optimised production results, Vaalco Energy has begun the spudding of 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.
George Maxwell, Vaalco’s Chief Executive Officer, commented, “We are excited to commence our drilling campaign in offshore Gabon and are beginning the near-term series of value creation catalysts that we outlined to the market in our Capital Markets Day presentation this past May. The drilling rig arrived in late November, and we have spud our first well, the ET-15. We are initiating the programme at the Etame platform with this infill well and the pilot holes. After drilling at the Etame platform, we expect to move the rig to the SEENT and Ebouri platforms where we have several wells and workovers planned to enhance production, lower costs and potentially add reserves. As we enter 2026, with major projects underway in both Gabon and Côte d’Ivoire, we are looking to drive meaningful growth that we believe will translate into value for our shareholders for the remainder of the decade.”
As previously announced, the Company secured a drilling rig in December 2024 in conjunction with its Phase Three Drilling Programme, with an affiliate of Borr Drilling.
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