In The Spotlight
Regional trade desks reported on Wednesday that sellers of sweet and heavy West African grades are finding it difficult to clear their export programmes.
Physical oil markets across the Atlantic basin are contending with mounting headwinds as cargoes of both Angolan and Nigerian crude struggle to find buyers, undermined by stubbornly high shipping costs and softening differentials.
Regional trade desks reported on Wednesday that sellers of sweet and heavy West African grades are finding it difficult to clear their export programmes. The paralysis highlights growing competition in international refining centres, where delivered costs dictate refiners' feedstock purchasing strategies.
Twin pressures on West African differentials
Market participants point to an accumulation of geopolitical and operational factors that have simultaneously reduced arbitrage profitability and weakened outright bids for Atlantic basin crude.
A market trader noted that the physical market was confronting a “combination of high freight costs, recovering Middle Eastern supply, and widening discounts,” which has left several Nigerian and Angolan cargoes struggling to clear within their typical trading cycles.
When maritime tanker rates surge, distant refiners in Europe and Asia demand steeper discounts on free-on-board (FOB) prices to offset the expense of transporting the barrels. Concurrently, the gradual return of regional competition from Middle Eastern producers has offered refiners closer, more economic options, compressing the natural premium historically held by Atlantic grades.
Angolan grades suffer steep discounts
The downward trajectory is particularly pronounced in heavy, sweet grades from Angola, which have experienced severe pricing declines over the course of a single trading week.
Offers for Angolan Dalia crude were heard at a discount of $20 to dated Brent on the Argus Open Market this week, according to another trader. This assessment represents a substantial deterioration compared to the discount of $9.95 to dated Brent recorded for the grade last week on the Platts platform.
Key observations shaping current West African trading include:
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Elevated vessel charter rates pricing long-haul barrels out of key export destinations.
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Recovering crude flows from Middle Eastern producers reducing reliance on Atlantic basin imports.
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Persistent overhang of unsold volumes across the prompt loading programmes.
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Angolan differentials going lower, which is directly weighing on the pricing of competing Nigerian grades.
Because Angolan and Nigerian streams often compete for similar processing units across Mediterranean and Northwest European refineries, the widening price discount on Angolan heavy barrels has exerted immediate downward pressure on lighter Nigerian export grades. Sellers of Nigerian crudes are being forced to adjust their physical differentials downward to remain viable against their regional neighbours.
Chevron’s Aseng gas milestone
Beyond the prompt crude market, the wider Gulf of Guinea upstream sector is monitoring significant long-term infrastructure progress in neighbouring waters.
US oil major Chevron has confirmed it remains on track to deliver first gas from its offshore Aseng gas project in Equatorial Guinea in 2028, a senior company executive said. The development represents a notable step forward in monetising offshore gas reserves across regional production hubs, even as short-term crude physical traders manage the volatility of global shipping bottlenecks and shifting refinery margins.
East African nation has established a clear timeline to transition into an active player in the global energy market. The commencement of commercial oil production is officially on track for June 2027.
Uganda is standing on the precipice of a historic economic transformation.
Nearly two decades after making its initial commercial hydrocarbon discoveries, the East African nation has established a clear timeline to transition into an active player in the global energy market. The commencement of commercial oil production is officially on track for June 2027. This milestone will be swiftly followed by inaugural exports facilitated by the East African Crude Oil Pipeline (EACOP), promising to fundamentally reshape the country’s trajectory.
The announcement was delivered by Kristina Kasebayo, Head of Compliance at the Uganda National Oil Company (UNOC), during a fireside chat at African Energy Week 2026 in Cape Town. By setting this firm schedule, the government has signalled its readiness to capitalise on resources carefully managed since their discovery in 2006. Rather than simply extracting raw material, the national strategy integrates export ambitions with substantial domestic processing capabilities, aiming to capture maximum value from its subterranean wealth.
"First oil will start before the end of our financial year – June 2027 – which will position us as an oil producing country," Kasebayo stated, confirming the eagerly awaited timeline.
Bridging the Vital Infrastructure Gap
For a landlocked nation, possessing subterranean wealth is only half the battle. The true complexity lies in establishing the logistical channels necessary to reach international buyers. Uganda has spent years meticulously designing the required export infrastructure, a monumental undertaking now nearing its conclusion.
The East African Crude Oil Pipeline serves as the linchpin of this export strategy. According to UNOC, the pipeline is already 92% complete. Once operational, this engineering project will transport Ugandan crude to a dedicated port facility in neighbouring Tanzania, unlocking direct access to global shipping routes.
Developing the upstream resources had to be perfectly matched by rigorous regulatory frameworks and complex cross-border agreements.
"The challenge was never getting the oil out of the ground, but having the infrastructure and regulation in place," Kasebayo explained, highlighting that all requisite legal agreements have been successfully secured.
Prioritising Domestic Value and Energy Security
While international crude exports will generate significant revenue, Uganda remains equally committed to bolstering its national energy security. A cornerstone of the government’s master plan is the construction of a domestic oil refinery. This facility is designed to reduce the nation's reliance on imported petroleum products, ensuring a stable, localised fuel supply.
Key project milestones and timelines include:
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February 2027: The target date for reaching a final investment decision (FID) regarding the domestic refinery.
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June 2027: The scheduled commencement of commercial oil extraction from the upstream fields.
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2030: The projected completion date for the refinery, enabling large-scale domestic processing.
By combining the capacity for raw exports with domestic refining, the government aims to insulate the local consumer market from global supply chain volatilities whilst creating new industrial opportunities.
"We intend to take FID for the domestic refinery in February 2027 and expect the refinery to be complete by 2030," Kasebayo noted, outlining a clear roadmap for the downstream sector.
Introducing ‘Pearl Sweet’ to the Global Market
As the physical infrastructure falls into place, Uganda is strategically branding its sovereign resource for the international market. The country’s crude will be officially marketed under the name 'Pearl Sweet', a culturally significant nod to its historic moniker as the Pearl of Africa.
This forward-thinking branding strategy is already yielding positive results. The unique characteristics of the crude grade have garnered favourable international recognition, ensuring a receptive market once the taps are opened. With EACOP nearing the finish line and upstream preparations entering final stages, Uganda is an emerging energy supplier ready to engage with global buyers.
The next few years will prove absolutely pivotal as the government and UNOC work collaboratively to finalise the remaining technical details. If the current momentum is maintained, Uganda will soon realise its ambition of achieving energy independence whilst cementing its status as a vital contributor to the African energy landscape.
Drilling operations have begun in the deepwater Baobab field. (Image source: Vaalco)
Vaalco Energy has announced the successful completion of its Phase 3 drilling programme offshore Gabon, and the commencement of drilling on its Baobab Phase 5 programme offshore Côte d’Ivoire
Offshore Gabon
Vaalco holds a 58.8% working interest in and operates the Etame Marin block, located offshore Gabon. Vaalco has successfully drilled, completed and placed on production the ETSEM-3H development well in an attic position within the SE Etame field, with a lateral wellbore of 300 meters of net pay in high-quality Gamba reservoir sands. Achieved stabilized initial flow rate of approximately 2,000 gross barrels of oil per day (“BOPD”), 1,140 BOPD net to Vaalco. This represents the final well in the Phase 3 drilling programme which is now complete, and Drill rig (Borr Norve) has been demobilised from the field.
Offshore Côte d’Ivoire
Following completion of its planned dry dock refurbishment in February 2026, the Baobab FPSO returned to Côte d’Ivoire and was successfully reconnected to field infrastructure in early April 2026.
Production resumed from all producing wells in June 2026. Followng the successful re-start of the deepwater Baobab field, the Baobab Phase 5 drilling operations have begun with the batch-setting of top-holes by the operator. After the top-hole sections of all wells are drilled, the wells will then be completed and placed on production sequentially. The current plan for the Phase 5 drilling campaign consists of four producers, three water injectors and two workovers. The first producer well is anticipated to come online towards the end of 2026, with meaningful production growth expected in 2027.
Vaalco acquired a 27.4% non-operated working interest in Block C1-4o offshore Côte d’Ivoirein 2024 through its acquisition of Svenska, , containint the Baobab producing field and the significant Kossipo discovery. It is now confirmed as operator of the Kossipo field with a 60% working interest, with a field development plan being actively progressed toward completion in the first half of 2027.The company sees Côte d’Ivoire as strategically expanding its West African focus area with a sizable producing asset that has significant upside potential and future development opportunities, and regards Côte d’Ivoire as an investment-friendly country.
Vaalco owns a diverse portfolio of production, development, and exploration assets spanning Côte d'Ivoire, Egypt, Equatorial Guinea, and Gabon. It sees the Baobab restart and recent drilling results in Gabon as playing a significant role in supporting its future growth plans.
George Maxwell, Vaalco’s chief executive officer, commented, “Our continued success and organic project pipeline support Vaalco’s strategic focus on growing production, reserves and value for our shareholders.'
The recent European Norm 17975 addresses ‘grey zone’ energy-related risks during machine and pipeline interventions and proposes a task based framework for safe and efficient work. The norm can further increase the safety and efficiency of Lockout/Tagout programmes in a wide range of industries
A task based safety framework
10%-15% of fatal workplace accidents in Europe’s industries are related to maintenance operations according to data from the European Agency for Safety and Health at Work. Many of these result from underestimating risks involved in specific tasks such as machine greasing, sensor adjustment or a quick cleaning that are not always seen as ‘maintenance activities’. They are kept outside the scope of Lockout/Tagout programmes even though workers are exposed to similar risks. European Norm (EN) 17975 addresses these grey zone risks by using task based risk analyses as a starting point.
“EN 17975 does not require an energy zero state for every machine or pipeline during every intervention”, said Mustafa Ekseri, EMEA Safety Engineer at Brady Corporation, a supplier of quality Lockout/Tagout solutions. “Not having to halt an entire production line for every intervention can save valuable time - if it is possible in a safe way. To achieve this, EN 17975 proposes a layered approach based on risks related to specific tasks on specific machines and pipes. These risks are to be highlighted in a risk analysis. In absence of a risk analysis, machine zero energy states remain the safety standard. In that sense, EN 17975 builds on ISO 14118 by providing more options for compliance with European workplace safety legislation. Impacted activities can be defined using EN 17007 and EN 13306 and are also listed in EN 17975.”
Risk analysis guidance
With machine and pipe intervention safety hinging on identified risks, industries will need thorough task-based risk analyses. Guidance can be found in other standards. “ISO 12100, primarily intended for machinebuilders to take into account their customers’ workplace safety, can be used as a basis for machine intervention risk analyses. ISO 31000 provides guidelines for managing risk in general, including 8 core principles, a framework and a process.”
“EN 17975 proposes 6 steps to analyse the risk in any machine intervention task, starting with the identification of the task, all the way to a feedback loop for continuous improvement. That includes a thorough energy source inventory and identification. The standard also requires a risk analysis update before applying Standard Operating Procedures, and during maintenance activities. In addition, EN 17975 advocates clearly identified degraded situations that may deviate from the standard risk assessment.”
Task-based isolation
EN 17975 uses a task based risk approach that was captured earlier in the French norm X60-400. Based on a task risk analysis, the European Norm proposes four types of risk control processes:
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Neutralisation: a process that, through design of the control systems, shuts down an item of equipment so that a list of predetermined tasks can be conducted in safety.
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Standard isolation: a process that results in the removal – by locking in position a single or double isolating device – of all energies & fluids where the presence, accidental retention, unexpected appearance does not have hazardous consequences for workers, the environment, and items.
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Reinforced isolation: a process that results in the removal – by separation or by a combination of isolating and opening devices (e.g. valve, tap, etc.) – of all energies & fluids where the presence, accidental retention, unintended appearance does not have hazardous consequences for workers, the environment, and items.
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Specific provisions: a process that results in the implementation of organisational or technical measures enabling observation, diagnostics, testing activities and work on settings for the item in service to be carried out safely, with energies & fluids present.
“All four risk control processes require an inventory of energies and fluids per machine with their effects on people, property and the environment, a mapping of the isolating devices and an identification sheet of energies, fluids, components and lockout devices. It also requires a shared risk assessment grid and process. EN 17975 describes the aim, application conditions, type of activities and other relevant factors for each of the 4 risk control processes.”
Lockout/Tagout guidance
Complying with EN 17975 requires a human, organisational and technical approach, all of which are outlined in the norm.
EN 17975 identifies 9 steps to carry out reinforced and standard isolations by Lockout/Tagout of energies and fluids. Steps involve separation of energies and fluids, isolation, lock out, tagout, identification, dispersion of energies, check, contain and inspect. “The ‘check’ step in EN17975 is already widely known in the industry as the ‘Tryout’ in Lockout/Tagout/Tryout or LoToTo. It is a vital step to help make sure that measures are implemented correctly and that they are still effective.”
“Brady safety engineers can help industries implement isolations by writing machine- and task specific lockout procedures. These can include all 9 steps from EN 17975, and they must be based on company task risk assessments. In addition, we can offer the right Lockout/Tagout tools for procedure compliance, set up a hands-on demo by locking out a specific machine, and provide training to relevant employees. Alternatively, a gap analysis can be made that identifies steps to be taken from the current state to arrive at compliant, best practice Lockout/Tagout.”
Impact on existing safety programmes
EN 17975 is not a legal requirement. “The standard however considerably facilitates compliance with EU workplace safety legislation. It sets a clear expectation for any machine intervention: if no risk analysis for the task is available, a machine zero energy state is required.”
“Because many safety programmes already involve complete machine isolation from every energy source, for every task, it is likely that the new norm will impact existing Lockout/Tagout-programmes. Based on the risk analysis, machine zero energy states may not be needed for every type of intervention.”
“Adversely, some tasks that were considered ‘small and safe’ may unveil more risk after a thorough risk analysis. This means a single machine could have several Lockout/Tagout procedures. The right procedure can be included with, or communicated via a QR-code on a work permit for example.”
“Some forms of automated safety may not be sufficient for every task without an underlying risk analysis. Take a safety cage for example, equipped with sensors that deactivate moving machine parts the moment someone enters the cage. Do these nullify any residual energy that may pose a risk? Is gravitational, and other potential energy taken into account? The goal of EN 17975 is to prevent accidents, and to avoid a false sense of safety that does not provide any real protection.”
With the European Norm 17975, industries in Europe can now rely on a common standard for compliance with EU and national safety legislation that involve risk control processes of energies and fluids in maintenance activities.
Get the Brady EN 17975 Lockout/Tagout webinar recording
Go from zero machine energy to zero intervention risk with task based Lockout/Tagout, driven by the European Norm 17975. Get your copy of the EN 17975 webinar from an experienced, worldwide Lockout/Tagout solution provider.
Discover more about:
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the unique European framework EN 17975 provides to achieve safety and efficiency
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how EN 17975 focuses on task-based safety, rather than machine zero energy states
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how EN 17975 can be used to address ‘Grey zone’ risks
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4 risk-based energy isolation levels presented by EN 17975
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6 steps to control risks
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Lockout/Tagout procedure writing
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Lockout/Tagout device and padlock types
Get the webinar recording now >
Draw inspiration from our free guidebook on how to best implement Lockout/Tagout. Download the free guide >
BRADY EMEA
Mustafa Ekseri works as a Safety Engineer for Brady Europe, Middle East and Africa. He is involved in planning, writing procedures and rolling out Lockout/Tagout programmes at manufacturing and logistics workplaces throughout Europe. He is a Prevention Advisor Level 2, a Belgian legally regulated curriculum that equips professionals to handle safety and health risks in businesses.
Morocco is looking to develop its hydrocarbon resources to reduce its dependence on imported energy. (Image source: Adobe Stock)
Geoscience specialist Viridien has announced a landmark multi-client collaboration agreement with the Office National des Hydrocarbures et des Mines (ONHYM), Morocco's national agency for hydrocarbon and mineral resource development
The collaboration defines a joint framework for providing integrated subsurface data and analytics across Morocco's extensive and underexplored offshore and onshore sedimentary basins.
Through this collaboration, Viridien and ONHYM are looking to set new standards for subsurface evaluation, technical rigour and knowledge exchange, reinforcing Morocco's standing as an attractive destination for hydrocarbon investment in North Africa.
Amina Benkhadra, CEO of ONHYM, said, “This collaboration reflects ONHYM’s commitment to fostering innovation and international partnerships that unlock Morocco’s hydrocarbon potential. By combining our regional expertise and geoscientific knowledge with Viridien’s advanced technologies and capabilities, we are creating a powerful platform to enhance subsurface understanding, attract investment and accelerate exploration opportunities across Morocco.”
Dechun Lin, head of Earth Data, Viridien, said, “This collaboration marks a pivotal moment for Viridien as we deepen our presence in Africa and forge an enduring, partnership-driven relationship with ONHYM. By integrating our industry-leading imaging and data science capabilities with ONHYM's regional expertise, we are well positioned to support Morocco’s hydrocarbon potential.”
The development comes as Morocco, which remains heavily dependent on imported energy, is accelerating exploration and infrastructure development for gas in particular, with a view to diversifying energy supply for growing power generation and industry demands. Several key basins, both onshore and offshore, have demonstrated commercial gas potential.
Petralon 54 has revamped its production capacity significantly.
Petralon Energy is an African exploration and production company with proven capacity to acquire, develop, finance, and operate oil and gas assets
Operating through its subsidiary Petralon 54, the company holds a 100% working interest in the Dawes Island Field in the Eastern Niger Delta.
In just under six months, Petralon 54 has revamped its production capacity significantly through its recently established DI-3 well. Operations began on 14 March 2026 and has since delivered average additional daily production of approximately 2,800 barrels of oil per day (bopd), bringing the field's combined production capacity to approximately 4,800 bopd.
DI-2 has been onstream since October 2025 and DI-3 builds directly on the performance of its predecessor. Together, the two wells have sustained back-to-back drilling programme on a field that was non-producing at the time of Petralon's acquisition in 2021. Till date, the company has exported over 350,000 barrels of oil from the field via the Bonny Oil and Gas Terminal, which is located around 30km from the field. The DI-3 well became operational with zero lost-time incidents and it reflects the company's commitment to world-class health, safety, and environmental standards across its operations.
Dawes Island is located approximately 15km from Port Harcourt in the Eastern Niger Delta. The island covers roughly 46 sq km and holds an estimated 17.6 mn barrels of recoverable oil. “Our success at Dawes Island was built on the conviction that Nigerians could acquire, develop, and operate world-class energy assets. That conviction once required courage, today, it stands on proof. The easy thing after DI-2 would have been to pause, but the determination and resilience of every single member of the Petralon team drove us forward, and DI-3 is the result of that effort. Progress like this is only possible through the strong collaboration we have built with our host communities, our regulator, and our partners. This is only the beginning of what Dawes Island can deliver," said Ahonsi Unuigbe, founder and chief executive officer of Petralon Energy.
Through the commencement of DI-3 production, Petralon Energy validates another major step in the phased development of Dawes Island. The company stays focused on growing production, strengthening its position as a leading indigenous operator in Nigeria's upstream sector, and advancing its longer-term ambition for the field.
ADIPEC 2026 will welcome its strongest-ever participation from Asia, with 353 companies and six country pavilions – China, India, Japan, Malaysia, Singapore and South Korea – taking part in this year’s event
The Asian organisations will join more than 2,250 exhibitors across 16 halls and 30 international pavilions, where companies from across the global energy value chain will showcase technologies, infrastructure solutions and industrial capabilities. Asia will also be strongly represented across the conference programme, with senior leaders from across the region among ADIPEC’s more than 1,800 confirmed speakers.
Confirmed participating companies include Sinopec, CNPC, CNOOC, Petronas, PTTEP, INPEX, Mitsubishi Heavy Industries, Hengyun, Baofeng Steel Group Co. Ltd, Beijing JJC Technology Co. Ltd., Mitsui & Corp, Daechun, DRC, GS Energy Corporation, HADO, Panduit, TMEIC, CATL, Envision Energy, FLARE INTERNUSA, PT Petra Konsulindo Utama, KYK Group, Thai Benkan Co. Ltd., Bajaj Power Equipments Ltd., Babcock Power APAC Pvt Ltd, and Axis Solutions Ltd.
Hosted by ADNOC and held under the patronage of His Highness Sheikh Mohamed bin Zayed Al Nahyan, President of the UAE, in his capacity as Ruler of Abu Dhabi, ADIPEC will connect Asian policymakers, producers, buyers and industry leaders with the global investors, technology companies, project developers and partners as the region’s expanding economies drive new requirements for energy supply, infrastructure, capital and technology.
Asia is expected to be the primary engine of global energy demand growth over the coming decades. China is forecast to account for close to half of worldwide electricity demand growth through 2030, while India is expected to remain the single largest contributor to global energy demand growth through 2035. Southeast Asia is projected to contribute around a quarter of global energy demand growth through 2035 as industrialisation, urbanisation and digitalisation accelerate across the region.
Meeting that demand will require significant investment in energy supply and infrastructure, particularly as electricity consumption and data-centre capacity continue to grow.
For Asia, sustaining economic growth means securing reliable, affordable energy for its industries, cities and digital infrastructure today, while investing in the supply, capacity and more resilient energy systems it will need over the next decade. ADIPEC 2026 brings that agenda to Abu Dhabi, connecting the region’s growing requirements with the global organisations, capital and capabilities that can help deliver them.
Abdulmunim Saif Al Kindy, Chairman, ADIPEC 2026, said: “Asia is at the centre of global energy demand growth. As economies expand and energy needs rise, meeting that demand will require greater collaboration between producers, buyers, investors and technology leaders, alongside continued investment in supply and capacity. That is why ADIPEC is attracting record participation from across Asia, providing a platform where strategies are advanced, partnerships are formed and opportunities are turned into action.”
“Abu Dhabi is particularly well positioned to support this growth. Its proximity to some of the world’s fastest-growing energy markets, long-standing partnerships across Asia, and track record of providing reliable, flexible and competitive energy supply put it at the heart of supporting the region’s next phase of economic growth.”
Reflecting Asia’s growing influence on global energy markets, confirmed speakers at ADIPEC include:
• Wang Yuetao, Chairman, ZhenHua Oil
• Takayuki Ueda, Representative Director, President & CEO, INPEX
• Rajarshi Gupta, MD & CEO ONGC, Videsh Ltd
• Prof. Haruhiko Ando, CEO, Japan Cooperation Centre for Petroleum and Sustainable Energy
• Charlotte Wolff-Bye, VP & Group Chief Sustainability Officer, Petronas
• Prashant Ruia, Group CEO, Essar Group
• Koji Yamamoto, CTO and Senior Councilor, JOGMEC
• Nobuo Tanaka, CEO, Tanaka Global
• Massimo Danieli, CEO, Business Unit Grid Automation, Hitachi Energy
These executives will join more than 1,800 speakers participating across ADIPEC’s 13 conference programmes, where issues critical to Asia’s energy and economic development will feature prominently. Within the Strategic Conference, the Natural Gas & LNG programme will bring producers, buyers and infrastructure developers together to examine how supply can be expanded and diversified for import-dependent Asian markets, from contracting and market access through to the shipping and regasification capacity needed to maintain flexibility.
The Grids, Infrastructure & Industrial Execution programme will address the generation, transmission, storage and infrastructure capacity required to support Asia’s industrial, urban and digital growth, while the Finance & Investment programme will look at how capital can be mobilised for the region’s expanding infrastructure pipeline, including the risk allocation to commercial structures that move projects from plan to delivery.
The Maritime & Logistics programme will focus on the ports, fleets and shipping routes connecting global energy producers with Asian buyers, and the partnerships needed to maintain supply chain reliability as volumes grow.
Meanwhile, the AI, Digital & Technology Innovation programme will examine how artificial intelligence, automation and advanced analytics are being embedded into energy systems to sharpen performance and decision-making, alongside the increasing power requirements created by Asia’s rapidly expanding data-centre and digital economy.
New Leadership Dialogues will bring these themes directly into the boardroom, including a session on ‘Asia’s power squeeze: integrating renewables and gas in high-growth power systems’ and a Boardroom Roundtable on ‘The new technology frontier: Asia’s role in shaping global innovation’. ADIPEC will confirm speakers for these sessions in the coming weeks.
Christopher Hudson, President, dmg events, the organisers of ADIPEC, said: “Asia’s influence on the global energy system now extends far beyond demand. The region is increasingly shaping technology, manufacturing, infrastructure and the commercial relationships behind the industry’s next phase of growth.
“ADIPEC has always evolved with the industry, responding each year to where the biggest shifts are happening and where the greatest opportunities lie. Our role is to create the platform where those changes can be translated into decisions, partnerships and progress.”
ADIPEC 2026 will take place from 2-5 November in Abu Dhabi and is expected to welcome more than 239,000 attendees from across the global energy ecosystem.
Drilling operations have begun in the deepwater Baobab field. (Image source: Vaalco)
Vaalco Energy has announced the successful completion of its Phase 3 drilling programme offshore Gabon, and the commencement of drilling on its Baobab Phase 5 programme offshore Côte d’Ivoire
Offshore Gabon
Vaalco holds a 58.8% working interest in and operates the Etame Marin block, located offshore Gabon. Vaalco has successfully drilled, completed and placed on production the ETSEM-3H development well in an attic position within the SE Etame field, with a lateral wellbore of 300 meters of net pay in high-quality Gamba reservoir sands. Achieved stabilized initial flow rate of approximately 2,000 gross barrels of oil per day (“BOPD”), 1,140 BOPD net to Vaalco. This represents the final well in the Phase 3 drilling programme which is now complete, and Drill rig (Borr Norve) has been demobilised from the field.
Offshore Côte d’Ivoire
Following completion of its planned dry dock refurbishment in February 2026, the Baobab FPSO returned to Côte d’Ivoire and was successfully reconnected to field infrastructure in early April 2026.
Production resumed from all producing wells in June 2026. Followng the successful re-start of the deepwater Baobab field, the Baobab Phase 5 drilling operations have begun with the batch-setting of top-holes by the operator. After the top-hole sections of all wells are drilled, the wells will then be completed and placed on production sequentially. The current plan for the Phase 5 drilling campaign consists of four producers, three water injectors and two workovers. The first producer well is anticipated to come online towards the end of 2026, with meaningful production growth expected in 2027.
Vaalco acquired a 27.4% non-operated working interest in Block C1-4o offshore Côte d’Ivoirein 2024 through its acquisition of Svenska, , containint the Baobab producing field and the significant Kossipo discovery. It is now confirmed as operator of the Kossipo field with a 60% working interest, with a field development plan being actively progressed toward completion in the first half of 2027.The company sees Côte d’Ivoire as strategically expanding its West African focus area with a sizable producing asset that has significant upside potential and future development opportunities, and regards Côte d’Ivoire as an investment-friendly country.
Vaalco owns a diverse portfolio of production, development, and exploration assets spanning Côte d'Ivoire, Egypt, Equatorial Guinea, and Gabon. It sees the Baobab restart and recent drilling results in Gabon as playing a significant role in supporting its future growth plans.
George Maxwell, Vaalco’s chief executive officer, commented, “Our continued success and organic project pipeline support Vaalco’s strategic focus on growing production, reserves and value for our shareholders.'
Regional trade desks reported on Wednesday that sellers of sweet and heavy West African grades are finding it difficult to clear their export programmes.
East African nation has established a clear timeline to transition into an active player in the global energy market. The commencement of commercial oil production is officially on track for June 2027.
The survey will span across 34,000 kms offshore Egypt. (Image source: TGS)
Energy data and intelligence provider, TGS, has partnered with Egyptian Natural Gas Holding Company (EGAS), to initiate a large-scale 2D seismic reimaging campaign, the EGY-2DRE2026 project
The survey will span across 34,000 kms offshore Egypt, which will be further integrated to the GeoStreamer 2016, 2018 and 2023 surveys. The compilation will comprise other available conventional 2D data as well, building single and consistent regional framework for interested operators to refer to across the offshore basins. The vast and insightful dataset will be fed into an advanced velocity model building and pre-stack depth migration workflow, including TGS' proprietary DM-eFWI technology, to generate credible images of pre-, intra- and post-Messinian salt intervals in high definition.
The reimaged dataset that spans offshore Nile Delta, Herodotus Basin, and wider Eastern Mediterranean Basin will support clients to better resolve these intervals, giving a sharper, basin-wide structural framework to support prospect identification and maturation. This will play a significant role in decision making for operators to channelise exploration budgets in the right direction ahead of upcoming licensing rounds.
To support resource development, TGS has lately been taking up region-specific projects in Africa that aligns with a rising global demand for basin-wide reimaging and data integration across frontier and mature basins globally.
Final products for a priority subset of 2D lines are scheduled for delivery in Q2 2027, with the remaining full project scheduled for completion in Q1 2028.
"EGY-2DRE2026 will give our customers a modern, regionally consistent view of a basin that has historically been difficult to image beneath its complex Messinian section," said David Hajovsky, Executive Vice President, Multi-Client at TGS. "By combining our latest imaging technology with the depth and breadth of our existing coverage, we're able to de-risk exploration decisions and support our customers as they evaluate future opportunities in this highly prospective part of the Egyptian offshore."
The project is supported by industry funding.
Offshore Sao Tome and Príncipe is a challenging subsurface environment. (Image source: TGS)
The TESCOM RC-X motorised injection rate control valve. (Image source: Emerson)
Emerson has launched the TESCOM RC-X motorised injection rate control valve, which helps offshore refineries achieve accurate, repeatable chemical injection, reducing chemical waste, downtime and overall operating costs
Flow assurance is critical for offshore production facilities, especially as the industry moves to deeper water, longer tiebacks, deeper wells and higher temperature and pressure reservoirs, where conditions such as hydration, corrosion or the buildup of wax, asphaltene, scale and emulsion can restrict flow.
Chemical treatment can help mitigate these blockages, but there are dangers with over or under injection of chemicals. Over injection increases chemical consumption and resulting costs as well as additional field trips to replenish chemical storage tanks. It can also adversely impact downstream processing or treatment programmes and result in contamination penalties. Under injection can be ineffective, risking mechanical integrity and production output.
“Proper chemical dosing in deepwater and high-pressure/high-temperature refining environments can prevent blockages and flow instability, helping to ensure optimum fluid behaviour, protect asset integrity and stimulate production,” said Julia Villa, product marketing manager with Emerson´s fluid and motion control business, noting the TESCOM RC-X control valves enable accurate dosing that reduces downtime and chemical waste associated with over injection.
The value is specifically designed to work with Micro Motion Coriolis flow meters in offshore chemical injection processes, which deliver reliable flow measurement for liquids, gas or slurries.
Product features
- Precise flow assurance - With a short-stroke design (less than 1/8 of an inch), TESCOM RC-X control valves are accurate up to 15,000 pounds per square inch (psi) and offer ultra-low flow rates of 0.02-500 liters per hour and repeatable function with 4-20 milliampere (mA) control
- Electric actuation eliminates air requirements, an advantage when compressed air is unavailable or unreliable.
- Available in medium- and high-pressure models
- Lightweight and compact
- Fewer moving parts than comparable products, reducing risk of mechanical failure over time, performing more consistently and requiring less maintenance.
- Explosion-proof, waterproof (IP67-rated) and corrosion resistant (compliant to NACE MR0175).
SLB to deploy subsea production system for Rovuma development.
The new standard represents an important step towards optical modem interoperability for subsea systems. (Image source: SWiG)
First gas from NT-1 and NT-2 is targeted for December.
The giant Ntorya gas field development in Tanzania is anticipated to deliver vital domestic energy supplies, alleviate local energy poverty, and drive long-term industrial and economic growth for the country
Tanzanian government authorities have recognised the urgency of the project's advancement and to make sure there is no delay, an optimised timetable has been established in consultation with the joint venture partners involved in the field's development. Designed with an aim to achieve first gas production by December, the packed schedule includes critical well workovers, testing, and accelerated drilling. Fully funded field operations and pipeline infrastructure integration will prepare the site for production generation.
Aminex has reached an agreement on the sequencing and implementation of the Ntorya gas development following a meeting convened by the Tanzanian Ministry of Energy
Key stakeholders convene
Representatives of the Ministry of Energy, the Petroleum Upstream Regulatory Authority (PURA), the Tanzania Petroleum Development Corporation (TPDC), ARA Petroleum Tanzania Limited (APT), the operator of the Ruvuma PSA, and Aminex's wholly owned subsidiary, Ndovu Resources Limited (Ndovu) were present at the meeting.
While the government did not approve the operator's proposal to extend and delay the project timetable, it did confirm a revised implementation schedule with all the parties involved. This schedule comprises workover of the Ntorya-1 well (NT-1) in October, the testing of the Ntorya-2 well (NT-2) in November and the drilling of a newly planned NT-Central well (NT-C) in December.
First gas from NT-1 and NT-2 is targeted for December. Drilling of the Chikumbi-1 well (CH-1) is to proceed after NT-C is drilled. Following the change of management at ARA Petroleum LLC and a technical reappraisal of the Ntorya project, APT had proposed bringing forward NT-C, previously planned as a development well for a later phase of field development, in place of CH-1, with the drilling of CH-1 deferred. The revised implementation schedule plans to drill the NT-C first, followed by the drilling of CH-1.
It was also confirmed at the meeting that the Ntorya to Madimba pipeline will be completed in time to receive first gas from the Ntorya field in December 2026.
APT confirmed to the parties that it had all necessary funds to carry out the revised programme for the development of the Ntorya field.
The parties agreed that APT should execute the planned activities in accordance with the revised implementation schedule and without unnecessary delay. The revised programme will now be progressed through the formal Joint Venture approval process in accordance with the Joint Operating Agreement.
Economic impact of the project
Charles Santos, executive chairman of Aminex, said, "I would like to thank Dr James Mataragio, Permanent Secretary for Petroleum at the Ministry of Energy, for convening the meeting last week and for the constructive approach taken by all parties. Our focus now is on working together to implement the agreed programme and deliver first gas without further delay.
"The revised implementation programme establishes clear near-term operational milestones, targets first gas for December 2026 and provides for the drilling of a newly planned well, NT-Central, while ensuring that the CH-1 well is also drilled.
"Together, these activities form just the beginning of the development of the giant Ntorya field which is expected to deliver large volumes of gas supplies to Tanzanians, helping alleviate energy poverty, boost industrial development and fuel Tanzania's economic growth."
Puma Energy Ghana boosts LPG distribution through local partnerships.
The coming months will see a significant increase in operational activity at Ntorya.
The consistent market launches come from optimised production.
In line with Nigeria's strategy to expand reach in export market, the Nigerian National Petroleum Company Limited has globally released its new crude grade – Cawthorne
With an API gravity of 36.4 that denotes the light and sweet kind, the Cawthorne crude rules global market demand because of its unmatched petrol and diesel yields. Comparable to Bonny Light, Cawthorne crude blend is the latest from Nigeria’s basket of crude grades, building on recent additions such as Nembe and Utapate.
The consistent market launches come from optimised production, helping Nigeria to solidify its base in the export market with diverse offerings. The Cawthorne Floating Storage and Offloading (FSO) vessel, which is strategically positioned offshore Bonny, Rivers State for enhanced energy security and operational efficiency in easy crude evacuation from OML18, comprised the maiden 950,000 barrels cargo for export. Loaded on an MT Eburones vessel, it headed to the Netherlands, and unto the global market.
As Nigeria aims to attain crude production of three million barrels per day and gas output to 12 billion cubic feet per day by 2030, the international launch of Cawthorne will unlock value from its asset base and deepen market competitiveness.
“This milestone reflects the direction we have set for NNPC Limited—one anchored on execution, partnership, and value creation. We are moving decisively from resource potential to resource monetisation, ensuring that every asset delivers measurable commercial outcomes.
"The successful export of the Cawthorne crude grade is not an isolated achievement; it is part of a broader, deliberate strategy to grow production, deepen market relevance, and strengthen Nigeria’s position as a reliable global energy supplier. We remain firmly focused on delivering sustainable growth in line with national objectives and global market expectations,” said Bashir Bayo Ojulari, Group Chief Executive Officer of NNPC Ltd, as he acknowledged President Bola Ahmed Tinubu’s leadership and OML 18 partners' strong collaboration in achieving the milestone.
Technological innovation, strategic partnerships, and operational discipline will remain central to NNPC Limited's vision as the organisation works towards value creation from Nigeria's vast hydrocarbons resources.
The MoU was signed in China. (Image source: NNPC)
Africa’s refining landscape is diverging.
Energy leaders from across Africa will participate in the Strategic Conference. (Image source: dmg events)
The upcoming edition of ADIPEC 2026 will feature a strong contingent of African government leaders, underlining the continent's growing importance in shaping the future of global energy markets
Held under the patronage of His Highness Sheikh Mohamed Bin Zayed Al Nahyan, President of the United Arab Emirates, and hosted by ADNOC, ADIPEC 2026 will take place in Abu Dhabi from 2 to 5 November 2026, convening policymakers, industry executives, technology innovators and investors from around the world.
Senior ministers and energy leaders from across Africa are expected to participate in the event's Strategic Conference and high-level discussions, bringing perspectives from some of the world's fastest-growing energy markets. Their participation reflects increasing collaboration between African nations, the Middle East and international partners to expand energy access, attract investment and advance sustainable economic development.
Among the confirmed speakers are: Rt. Honourable Ekperikpe Ekpo, Nigeria's Minister of State for Petroleum Resources (Gas); Honourable James Opiyo Wandayi, Kenya's Cabinet Secretary for Energy and Petroleum; Honourable July Moyo, Zimbabwe's Minister of Energy and Power Development; and His Excellency Dr. Khalifa Rajab Abdulsadek, Libya's Minister of Oil and Gas.
Also participating are: His Excellency El Hadji Abdourahmane Diouf, Senegal's Minister of Energy and Petroleum; His Excellency Tiémoko Traoré, Mali's Minister of Energy and Water; and His Excellency Karim Badawi, Egypt's Minister of Petroleum and Mineral Resources. They will be joined by Proscovia Nabbanja, Chief Executive Officer of Uganda National Oil Company (UNOC), representing one of Africa's most closely watched emerging energy companies.
Africa is home to vast oil, gas and renewable energy resources and is expected to play a pivotal role in meeting rising global energy demand while supporting economic growth across the continent. Many countries are pursuing strategies that balance energy security, industrial development and emissions reduction, creating new opportunities for investment, technology deployment and cross-border collaboration.
At ADIPEC 2026, African leaders will engage with global decision-makers on topics including energy security, gas development, infrastructure investment, energy access, digitalisation and the pathways to a lower-carbon future. Their presence will reinforce ADIPEC's role as a leading platform for international dialogue and partnership, bringing together governments and industry to accelerate progress toward a more secure, affordable and sustainable energy system.
To register to attend ADIPEC 2026, visit https://www.adipec.com/
The event will convene the global energy industry in Abu Dhabi. (Image source: dmg events)
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