The FLNG Gimi by Golar LNG Limited has reached commercial operations date (COD) for the 20-year lease and operate agreement with bp for the Greater Tortue Ahmeyim (GTA) project offshore Mauritania and Senegal
This marks a significant milestone for the project partners, as LNG production volumes have successfully been ramped up to a level equivalent to the annual contracted volumes of approximately 2.4 million tonnes per annum (mtpa), or around 90% of nameplate capacity of 2.7mtpa.
The achievement of COD follows first LNG in February and the first LNG cargo in April. The second and third LNG cargo were exported in May and early June respectively and a fourth cargo is currently loading. The fifth cargo is expected at the start of the third quarter. With this expected cargo timing, Kosmos Energy forecasts 3.5 gross cargos in the second quarter.
Achieving COD and the recent ramp up in cargo lifting activity highlights continued strong cooperation between the project partners and Golar.
Independent oil and gas company, Perenco, has recently commissioned a floating LNG (FLNG) vessel to advance gas commercialisation offshore Gabon while also repurposing flared gas
In line with Gabon's first large-scale gas development, this is a flagship project in the Cap Lopez LNG terminal that is set to come online in 2026.
The FLNG is currently undergoing construction in Dubai as it promises to reach a capacity of 700,000 tons of LNG and 25,000 tons of LPG anually, backed by storage infrastructure capable of holding 137,000 cu/m.
This US$2bn project is being supported by Perenco's affiliate Dixstone under a contract with engineering and construction company, Technomak, for the integration of the offshore FLNG barge.
The Cap Lopez project will significantly contribute to Perenco's natural gas strategy, while also serving as a means for energy diversification and larger economic growth of the country. It will also ensure energy security and industrialisation.
This development moves alongside Perenco's major optimisation project in the Republic of Congo as well. The company has initiated the construction of the Kombi 2 platform on the Kombi-Likalala-Libondo II permit. Amounting to more than US$200mn, the project will see new drilling phases, infrastructure upgrades and the optimisation of existing wells.
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As Eni advances exploration activities in the Baleine field offshore Cote d'Ivoire, it onboarded Expro for its autonomous iTONG system to ensure operational safety, efficiency, and sustainability
The technologically advanced tong system has simplified the well construction process by eliminating considerable rig time and labour time, keeping personnel away from the hazardous Red Zone of the rig floor. Less rig time further brought down the net CO₂ emissions.
By automating the connection make-up and break-out of casing and tubing joints, iTONG provides precise torque control from the push of a single button - operated safely from the driller’s cabin - while enabling full connection make-up validation.
Expro secured the Tubular Running Services (TRS) contract aboard the Deep Value Driller (DVD) drillship, which arrived in Cote d'Ivoire in late 2023.
Jeremy Angelle, vice president of well construction, said, “Since its introduction to Norway four years ago, iTONG has been recognised by major operators as a top-tier solution for tubular connection make-up and validation.
“In this case, its performance has exceeded expectations, with a 50% reduction in make-up times. The vision and commitment demonstrated by both Eni and Expro in introducing this technology to Africa exemplify a shared dedication to safer, more efficient operations.”
Jeremy added, “iTONG continues to redefine industry standards, improving safety, efficiency, and cost-effectiveness for offshore operations worldwide. Thanks to cutting-edge systems like iTONG, our R&D teams are leading the TRS industry in enhancing safety, reducing emissions, and driving global cost savings.”
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Subsea 7 has received a subsea contract in West Africa
This contract will see the company transporting and installing flexible pipelines, umbilicals, and associated subsea components for the connection of a floating production, storage and offloading (FPSO) vessel. It will also cover the pre-laying activities for an upcoming drilling campaign.
Project management and engineering work will begin immediately at Subsea7’s offices in Sutton, UK and Suresnes, France, and offshore activity is expected to start in 2026.
Jerome Perrin, Vice President Africa, Middle East, and Turkiye for Subsea7, said, “Our close and agile collaboration with our clients allows us to make possible cost-effective and reliable offshore solutions for their needs. We are pleased to be able to support this client in executing such a strategically important project in West Africa. ”
Two exploration wells on Block 2914 that fall under the purview of Petroleum Exploration License (PEL) 85 offshore Namibia have now been delivered by Rhino Resources and Halliburton.
Orchestrated from Halliburton's new operational bases in Walvis Bay, Swakopmund and Luderitz, the operation was made possible with world-class technology and local collaboration.
Antoine Berel, vice president, Halliburton sub-Saharan Africa, said, "This success is an example of what’s possible when world-class technology, local collaboration, and a shared long-term vision come together. Our newly established infrastructure across Namibia enabled this discovery, which will help unlock Namibia’s energy potential and build the capacity to support the country’s future as an energy hub in Africa."
As Namibia attracts international interest in its offshore basins, the success of this campaign sets a new standard for energy development in the region.
“At the onset of the drilling campaign, we communicated to our partners that Rhino’s exploration efforts in Namibia should simultaneously prove geological potential and deliver long-term benefits for the country. The discoveries on Block 2914 are a promising start to this journey, which will contribute to the foundation we are laying for Namibia’s burgeoning oil and gas industry — one built on knowledge and skills transfer, local capacity building and the upliftment of young Namibians,” said Travis Smithard, CEO of Rhino Resources.
The Rhino-Halliburton Technology Centre at the University of Namibia (UNAM) Southern Campus came into being in October last year to advance geoscience education and research nationwide.
Valaris Limited has been awarded a five-well contract offshore West Africa for drillship VALARIS DS-15
The VALARIS DS-15 is equipped with BOP stacks that comprise 10,1000 psi annulars, seven ram and 15,000 psi blowout preventer (BOP) which are critical for well control.
The US$135mn-worth contract that will span nearly 250 days, is scheduled to commence in the third quarter 2026.
Including upfront payments for rig upgrades and mobilisation, the total contract value does not include the provision of additional services. There are priced options for up to five wells with an estimated total duration of 80 to 100 days.
President and chief executive officer Anton Dibowitz said, “We are excited to have secured another contract for one of our high-specification drillships. As part of this contract, the rig will be upgraded with an enhanced managed pressure drilling system. We believe this contract reflects the market’s preference for contractors that can deliver complex drilling solutions with high-specification, seventh generation drillships. In addition, this contract adds to our presence offshore West Africa, where we are well positioned for future contracting opportunities.”
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Recoverable barrels of oil from a well in the Bourdon prospect in the Dussafu Licence offshore Gabon have successfully surpassed millions following drilling
The second sidetrack DBM-1 ST2 well that has been drilled by the Norve jack-up rig for BW Energy has revealed 56 million barrels oil estimates in place. Of these, approximately 25 million barrels are considered recoverable.
Confirming the substantial oil discovery with good reservoir and fluid quality, Carl K Arnet, CEO of BW Energy, said, “The appraisal well confirms the potential for establishing a new development cluster with a production facility following the MaBoMo blueprint. We expect at least four producing wells.”
“We continue to successfully expand the Dussafu reserve base which, together with multiple additional prospects yet to be drilled, will support long-term production and value-creation in Gabon.”
Initial data shows that oil from Bourdon field has the lowest viscosity of the Dussafu discoveries measuring an average of 3.5 centipoise (cp), compared to 5 cp and 7 cp for the Hibiscus / Tortue and Ruche fields, respectively.
Evaluation of logging data and formation pressure measurements confirm approximately 11.2 metres of pay in an overall hydrocarbon column of 35.2 metres in the Gamba formation, drilled to a depth of 4,731 metres.
Bourdon is located approximately 15 kilometres west of FPSO BW Adolo and 7.5 kilometres southeast of the MaBoMo facility. The discovery will enable the Company to book additional reserves not included in its 2024 Statement of Reserves.
A well engineer from Slb recently demonstrated the tackling of injectivity issues on an offshore well during the Society of Petroleum Engineers’ (SPE) Nigeria Annual International Conference and Exhibition.
Characterised by high-permeability and unconsolidated sands in a prolific turbidite reservoir, pressure maintenance at the AX field were initially conducted by deviated frac-pack injectors which fell short in keeping issues such as fines migration and other formation damage mechanisms in check.
To address this issue, horizontal injectors were chosen, offering larger flow areas and lower velocities to mitigate sand production risks. This, however, did not turn out enough for the AX9 well, as water injectivity level still remained markedly low. It required proactive intervention to curb formation damage while ensuring long-term well integrity. Advanced surveillance techniques, including Hall plot analysis, were deployed to confirm that injectivity decline was caused by internal formation damage rather than wellbore restrictions. Mineralogical analysis revealed the presence of fines-prone clays such as Smectite, Illite, and Kaolinite, which contributed to plugging and injectivity impairment.
This gave birth to a stimulation strategy tailored to AX9’s specific reservoir characteristics. Early intervention was initiated while the well was still operating in matrix mode, ensuring maximum benefit from the stimulation process. In line with the AX9 formation, a matrix acid stimulation plan was developed utilising a nitrified mud acid system with continuous foam diversion. The metculous preparation of critical components were involved from high-pressure nitrogen units and fluid pumps to IWOCS systems, among others.
The nitrogen foaming-supported treatment sequence involved multiple stages, including ammonium chloride pre-flushes, acid pre-flushes, a main stage of 13.5:1.5 mud acid, and post-flushes. This made sure even acid distribution and effective fines removal.
Post-treatment the injection rate improved to 43 kbwpd, with a substantial pressure drop of 21% and the injectivity index rose from 20 to more than 80-100 bpd/psi. Besides the improved injection rates, the treatment helped boost production by an additional 5,000 barrels per day approximately.
Following 2024's extensive eight-well production drilling campaign in the Dussafu Marin permit offshore Gabon, operator BW Energy and partner Panoro Energy have managed to hit their production targets of 40,000 barrels of oil per day (bopd) in November 2024, and has remained consistent since.
This was made possible by a robust workover and electrical submersible pump replacement programme with the help of Borr Drilling's Norve jack-up rig. An effective artificial lifet method, ESPs help pump production fluids from low pressure situations. It is easy to maintain, and is considered a cost effective alternative to vertical turbine, split case and positive displacement pumps.
At approximately 37,153 bopd in the fourth quarter of 2024, the site crossed a milestone as it was the highest quarterly rate achieved since 2018, when the block first started producing.
The current production rate might jump by another 10%, given the scope for the FPSO nameplate capacity to reach beyond 40,000 bopd.
After the 2024 production campaign concluded in October, with the installation of a conventional electrical submersible pump (ESP) system for the DHIBM-7H well as it was brought online, the rest of the seven Hibiscus / Ruche production wells also underwent a workover and ESP replacement programme in January this year.
According to Panoro Energy's Chief Executive Officer, John Hamilton, the Dussafu drilling campaign was expanded to eight wells in order to accomodate first track development of the final two discoveries made in May 2024.
“Our current focus is on fully transitioning all the new wells to conventional ESP systems and restoring production at the three shut-in wells, after which we will drill the exciting Bourdon prospect in line with our infrastructure lead exploration and appraisal strategy aimed at unlocking the substantial organic upside that exists on the block,” said Hamilton, while speaking on the drilling campaign.
As part of its 2025-26 programme in Gabon, Borr Jack-Up XIV Inc will be deployed by Vaalco Energy for the drilling of multiple development wells and appraisal/exploration wells.
"We are excited about the major projects planned for 2025 that are expected to deliver a step-change in organic growth across our portfolio in the coming years. In Gabon, we continue to work with our joint owners at Etame on our shared goal of executing another successful drilling campaign designed to enhance production and add reserves. We have signed a contract with Borr that we believe allows us the flexibility to optimise our drilling and workover plans offshore Gabon.
“We anticipate the programme to begin in mid-2025 with the sequencing and exact number of wells yet to be finalised. We are planning on multiple wells in the Etame field, multiple wells at our SEENT platform and a redrill and several workovers in the Ebouri field to access production and reserves that were previously shut in and removed from proved reserves due to H2S. Over the past three years, we have delivered on our focused strategy and believe we will continue to do so with the organic growth programmes across our diversified portfolio over the coming years,” said George Maxwell, the Chief Executive Officer of Vaalco Energy.
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Nigeria is increasingly looking towards developing its brownfield assets to boost production.
This can be achieved with the right technological interventions, giving way to enhanced oil recovery that can substantially meet the region's refining capacity. Compared to greenfield projects that require considerable investments from scratch, brownfield developments cuts down on carbon footprints, thus allowing operators to meet their sustainability requirements. Ideal technological interventions comprise a package offering e-line, slick line, coiled tubing services, well remediation, well control, and idle well management services. Well intervention operations can range from well conversion, casing run operation on a wild cat well, slot recovery, installation of emergency casing head housing slip, well work-over, and drilling and completion, to name a few.
To facilitate more brownfield developments, the Nigerian administration is working to increase collaboration between the local communities, government and the private sector.
Recently, Nigeria-based offshore construction company called Intrepid Energy Limited joined hands with United Kingdom's Aquaterra Energy to deliver a bespoke subsea well intervention equipment package for a project in Nigeria.
“Working with Aquaterra Energy marks a significant step forward for our intervention operations in Nigeria. Their specialised technology enhances our ability to execute intervention programmes efficiently, maximising performance across our assets. By combining Aquaterra’s technical expertise with our deep understanding of the local operating environment, we’re confident this collaboration will enhance production outcomes and create lasting value for our operations in the region,” said Seun Alonge, CEO at Intrepid Energy Limited.
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Aquaterra Energy, a leading provider of offshore engineering solutions, has secured a multi-million-dollar, multi-year contract with Intrepid Energy Limited (IEL) to supply a tailored subsea well intervention equipment package for a project in Nigeria
The turnkey well access system will enable IEL to conduct intervention operations across multiple mature oil wells, enhancing reservoir production.
The contract covers a complete seabed-to-surface intervention package, including Aquaterra Energy’s TRT tieback tooling for production bore and annular access, a lightweight well pressure control system, and an ISO 13628-7 qualified open water intervention riser with an integrated tensioning system. In addition to supplying the equipment, Aquaterra Energy will provide ongoing offshore engineering support throughout the project.
Designed for deployment from jack-ups and lift boats, the 7-3/8” lightweight well access solution offers a cost-effective and operationally efficient alternative to floating vessels, reducing intervention costs while maintaining safety and performance standards.
Andrew McDowell, Delivery Director at Aquaterra Energy, stated, “Our expertise in offshore engineering allows us to develop tailored intervention solutions that address the operational challenges of subsea well access. This system has been engineered for efficiency, ease of deployment, and safety, helping IEL optimise intervention activities across Nigeria while reducing costs. By delivering a complete, integrated package, we are simplifying complex operations and enabling operators to maximise production potential.”
Engr Seun Alonge, CEO at Intrepid Energy Limited, added, “Working with Aquaterra Energy marks a significant step forward for our intervention operations in Nigeria. Their specialised technology enhances our ability to execute intervention programmes efficiently, maximising performance across our assets. By combining Aquaterra’s technical expertise with our deep understanding of the local operating environment, we’re confident this collaboration will enhance production outcomes and create lasting value for our operations in the region.”
The project is set to span multiple years, with Aquaterra Energy providing continuous technical support through a dedicated team of engineers.
George Morrison, CEO at Aquaterra Energy, commented, "Delivering reliable and efficient well access solutions for shallow water subsea operations is central to how we support offshore operators. This collaboration with IEL reinforces our commitment to providing cutting-edge engineering solutions that enhance efficiency and reduce operational costs. With West Africa playing an important role in the global energy sector, we’re proud to continue supporting its offshore industry with our expertise and innovative technologies.”
In a major realisation of its production and cost optimisation objectives, the Nigerian National Petroleum Company (NNPC), along with joint venture partner First Exploration & Petroleum Development Company (First E&P), has announced a significant hydrocarbon discovery in the Songhai field, located in OML 85 in the shallow offshore region of Bayelsa.
Spudded as part of efforts to increase and sustain the joint venture's oil production over the next five years, the well was drilled to a total depth of 8,883 feet measured depth (MD) in 30 metres of water. It encountered hydrocarbons across eight reservoirs, logging over 1,000 feet of hydrocarbon-bearing sands, most of which reveals promising reservoir properties. There has been an indication of substantial oil and gas volumes for commercial exploration. The derived well data will now be integrated for thorough research and analysis to calculate resource estimates and optimise field development plans.
"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," said Segun Owolabi, General Manager, Exploration and Development at FIRST E&P.
"This aligns with NNPC Limited’s mandate to drive production growth and cost optimization. The success at Songhai Field reflects our commitment to strategic partnerships, advanced technology, and efficient operations to maximize Nigeria’s hydrocarbon potential sustainably," said Seyi Omotowa, Chief Upstream Investment Officer of NUIMS. "The discovery also highlights the role of strategic collaboration in expanding Nigeria’s hydrocarbon reserves," he added.
"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," said NNPC’s Group Chief Executive Officer, Mallam Mele Kyari.
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