In The Spotlight
Lucia Witbooi, Vice President of the Republic of Namibia at NOGC 2026. (Image source: NOGC)
Local content in Namibia was first considered at a policy level in 2021, until back to back Orange Basin discoveries the year after pushed the Cabinet to formally sanction the structured development of a comprehensive framework
Thanks to high-profile discoveries like Shell's Graff-1 and TotalEnergies' Venus-1X fields, the sudden inflow of substantial foreign capital required channelising in a way that keeps benefiting Namibian locals across generations, which were addressed in the new framework. Following years of nation-wide consultations at both ministerial and industrial levels, the Cabinet has now approved the National Upstream Petroleum Local Content Policy. This will ensure legal security for local participation across the upstream petroleum value chain.
Namibia Oil and Gas Conference and Exhibition
Factors that set the tone for the recently held Namibia Oil and Gas Conference and Exhibition (NOGC) in Windhoek included:
- Capitalising petroleum opportunity
- Generate long-term national value
- Advancing investments and businesses
- Skills and jobs creation
“Discovery is not the destination. A resource beneath our waters becomes a national success only when it is responsibly developed and translated into tangible improvements in the lives of our people. It must become employment for Namibians, opportunities for our enterprises, skills for our young people, technology for our institutions, infrastructure for our economy, revenues for national development, and savings for future generations. This is why the theme of this conference is particularly appropriate,” said Lucia Witbooi, Vice President of the Republic of Namibia.
From Decision to Dividend: Making Namibia’s Oil Work for Namibians was the theme for the three-day conference hosted by the Economic Association of Namibia (EAN) in partnership with the Hanns Seidel Foundation (HSF) and the Namibia Investment Promotion and Development Board (NIPDB), with strategic partners the National Petroleum Corporation of Namibia (NAMCOR) and SNC Incorporated. The conference was officially endorsed by the Ministry of Industries, Mines and Energy.
“Our strategic plan for 2026 to 2030 carries one organising idea, which is to move this country from exploration to readiness, so that Namibia is ready onshore when production begins offshore. Namibia expects Namibian employment to be maximised, Namibian suppliers prioritised, skills and technology transferred, and meaningful Namibian participation, ownership and financing across the value chain.
"Fiscal certainty is a stable and transparent framework for petroleum revenues. Namibia does not move the goalposts. To our international partners: local content, properly done, is not a tax on your investment. An industry surrounded by capable Namibian suppliers, skilled Namibian workers and invested Namibian communities is an industry with social licence, political stability and a future measured in generations. That is what the policy builds, and my ministry will implement it with you, not against you. I am happy to state that our local banks have informed me that they are ready to receive bankable proposals from the oil and gas sector for their consideration,” said Modestus Amutse, the Minister of Industries, Mines and Energy.
From exploration to development
Namibia is currently transitioning from exploration towards development, and local content remains the core of this journey. The administration is increasingly focusing on:
- Enterprise participation
- Skills exchange and development
- Infrastructure building
- Financing and investment
“Oil is not the point; oil is actually the how. Our people are the why,” said Jason Kasuto, chairperson of the Economic Association of Namibia and managing director of Monasa Advisory & Associates.
The event saw Namibian business persons and policymakers strategising on ways to advance local participation at the Local Content Masterclass segment. There was also the NIPDB Local Content Pitching Session, where entrepreneurs pitched concepts and sought partnership opportunities with industry leaders and investors. Supplier workshops educated domestic businesses on international industry standards as the means to expand influence.
Block CI-27 powers Abidjan in Ivory Coast.
It has been more than a decade since Ivory Coast began thinking on an international scale to capitalise on its rich deepwater resources
This phase involved a complete overhaul of its legacy petroleum laws which were reframed with global investors' interests in focus. Petroleum sharing contracts became the standard default vehicle, generous cost-oil recovery limits were introduced, and profit-oil split brackets and royalty tax structures became clearly defined.
Global offshore influence
World-class discoveries by Italian major Eni like Baleine and Calao followed soon after, and these deepwater developments of immense scale were achieved in record two years -- a feat previously unheard of. Vaalco Energy brought the Baobab field in Block Cl-40 online early this year with license extension through 2038 for development drilling plans. In May, Viridien started CDI25 -- a seismic reimaging project in the Tano Basin, Ivory Coast, which will be a drill-ready multi-client dataset for explorers. Ivory Coast's offshore influence as a coveted destination for global operators shot up, thanks to its administrative overhaul.
Banking on this investor-friendly environment, Panoro Energy has been the latest to enter Ivory Coast with the acquisition of DNO's entire 9.09 per cent interest in offshore Block CI-27.
New player in high quality, gas producing Block CI-27
Panoro Energy sees the gas producing block as high-quality and anticipates more than 20,000 boepd from it in terms of group production. It will increase pro forma group production by ~23 per cent and group 2P reserves by ~11 per cent.
As Ivory Coast's largest reserves of non-associated gas, Block CI-27 powers the country's largest city and economic capital, Abidjan. This high profile Block, however, generates yield at a unit cost as low as US$6/boe from four offshore fields (Foxtrot, Mahi, Manta and Marlin) tied back to two fixed platforms.
This entry adds to Panoro's upstream ambitions in Africa, marking the beginning of its long-term interests in Ivory Coast, which might surpass Block CI-27. The Block gives Panoro the perfect gateway to one of Africa's strongest hydrocarbon regions, promising high output at low cost with well managed gas and liquids production and reserves.
In 2025, Block CI-27 produced 195 MMscfd, meeting more than 70 per cent of the country’s gas demand. Operator, Foxtrot International, has initiated a five well infill drilling campaign for enhanced recovery, sustaining production plateau around the 190 to 200 MMscfd level with scope to increase to around 230 MMscfd dependant on demand.
Gross remaining reserves are estimated at 540 Bscf and 5 MMbbls with a further 380 Bscf and 9 MMbbls of resources offering material reserve replacement and growth opportunities in the future, holding potential to produce well beyond the current PSC term.
Block CI-27 is privately held Foxtrot whose principal business is a 27.27 per cent effective participating interest. DNO CI LLC holds an indirect 33.33 per cent interest in Foxtrot International and therefore an indirect 9.09 per cent interest in the Asset. Other joint-venture partners in the Asset include PETROCI and SECI S.A
Made for a consideration of US$80mn on a cash free / debt free basis, the transaction will be financed through a combination of equity, comprising seven million new Panoro shares for DNO, and debt of a fully placed US$50mn senior unsecured bond issuance.
Diversifying Panoro's African portfolio
“This high-quality acquisition represents a continuation of Panoro’s strongly accretive growth strategy and follows the transformational acquisition of an additional interest in Block G offshore Equatorial Guinea from Kosmos Energy which we announced in February and completed in June 2026. The addition of an indirect 9.09 per cent interest in Block CI-27 offshore Ivory Coast brings material reserves and production to Panoro, while further diversifying our African portfolio both geographically and from a commodity perspective through long-life, gas-weighted production supported by stable, low-volatility pricing and sales arrangements that are de-linked from oil prices.
"Our new entry into Ivory Coast, one of the fastest growing economies in West Africa, is particularly attractive given the country’s strong private investment, structural economic diversification and expanding hydrocarbon sector, all of which provide long-term support for this strategic acquisition and follow-on growth opportunities in country as and when they arise.
"We look forward to establishing an excellent cooperation with the field partners including the operator Foxtrot International, the national oil company of Ivory Coast PETROCI, SECI SA and also the Ministry of Mines, Petroleum and Energy.
"Importantly, this landmark acquisition is accretive for Panoro shareholders on all standard industry metrics and will further enhance our ambition to continue delivering long-term, sustainable shareholder returns,” said Julien Balkany, executive chairman of Panoro.
Chevron will be assessing the tie-back potential of the discovery.
Chevron Corporation-subsidiary, Cabinda Gulf Oil Company Limited (CABGOC), has discovered oil and gas condensate at the 105-4X exploration well in Block 0 offshore Angola
Drilled in the prolific Lower Congo Basin, the well encountered an oil and gas condensate column of more than 600 meters (2,000 feet) in the primary Pinda reservoir, with more than 90 meters (300 feet) of net pay in excellent reservoir quality.
In line with its optimised production approach, Chevron will be assessing the tie-back potential of the discovery as the major has existing facilities nearby.
“This discovery is another important milestone for Chevron’s over 70-year history in Angola,” said Kevin McLachlan, vice president - exploration, Chevron. “By combining high-impact exploration with infrastructure-led opportunities close to existing facilities, we are growing our resource base, creating value, and demonstrating that our strategy is delivering, as well as our continued confidence in Angola’s resource potential.”
Block 0 is operated by CABGOC, which holds a 39.2 per cent working interest, and is co-owned by Sonangol E&P (41 percent working interest), TotalEnergies (10 percent working interest) and Azule Energy (9.8 percent working interest).
This discovery will significantly add to Chevron's well-established exploration programme in sub-Saharan Africa, from where it sources a combined production count of 300 thousand barrels of oil equivalent per day net. Existing resource base and active exploration programme across the region is positioned to sustain and grow production into the future.
Over the last year, Chevron has been focussed on selecting high quality exploration acreage from Africa to its existing portfolio. In Nigeria, the company farmed into two offshore blocks last year (PPL2000 and PPL2001) and was awarded a deepwater block PPL2010 in the country's latest bid round. Chevron has also had three near-field exploration successes – Meji NW-1, South Delta AA and Awodi-07 – in Nigeria since late 2024, where it is continuing an ongoing exploration and appraisal program. In Guinea-Bissau Chevron has secured three blocks including the newly acquired Block 4B which closed on 13 August 2026, while in Equatorial Guinea it has secured an additional five-block reconnaissance licenses.
Aligned with its exploration strategy, Chevron is preparing a high-impact, multi-well exploration programme across the region, including Namibia’s Nabba-1X well on PEL90 before year-end.
These initiatives underscore Chevron's confidence in the region's resource potential and its disciplined approach to building long-term value through high-impact, frontier exploration.
Jarvie-1 rig will drill horizontal sidetrack laterals. (Image source: ReconAfrica)
Reconnaissance Energy Africa has completed vertical production testing on the Kavango West 1X (KW1X) well onshore Namibia, and is preparing to mobilise the Jarvie-1 rig to commence open-hole horizontal production testing operations in the Huttenberg formation, targeting up to 1,000 metres
The vertical production testing programme helped identify up to two well zones that contained hydrocarbons capable of flowing to surface. Natural gas and potential liquids flowed to surface from the upper Huttenberg as well as the upper Elandshoek zones. While targeting the Huttenberg zone of interest, flow was generated immediately upon perforation, even before subjection to acid stimulation, and was flared through the relief flare stack.
To achieve similar promising results from the four other zones of the well which are considerably shallower than the Elandshoek, open-hole horizontal production test was the best option available to target reservoir section previously untouched by production casing, cement and perforations. Completing the well open hole, without casing or cement, tends to maximise flow from fractures. This decision was reached on the basis of original well log analysis that indicated 75 metres of pay while confirming presence of matrix porosity between large natural fractures with inclinations of 50-90 degrees. These largely vertical fractures need complementing with perpendicularly drilled horizontal wells to hit the sweet spot.
“We are excited to report another critical milestone of the KW1X production test, which is achieving our primary objective of proving the flow of hydrocarbons to surface, this time from the uppermost zone of the Huttenberg formation. The vertical cased-hole phase of testing at KW1X is now complete and with the significant data and technical information gathered from this test, we have a high level of confidence moving forward with an open-hole horizontal production test in the Huttenberg formation.
"Importantly, KW1X's well results do not just validate a single structure; it also opens running room across the block. We have mapped 22 structures using existing seismic data and anticipate the inventory could grow with additional seismic coverage on PEL 73. We also believe our acreage in Angola could add additional structures to our inventory. These results have made critical steps to derisk and open a new play fairway.
Confirming the KW1X results with a flow rate test on a horizontal sidetrack as soon as possible will ultimately support resource and reserve bookings and a final investment decision on this emerging Damara Fold Belt Play," said Reconnaissance's President and CEO, Brian Reinsborough.
Horizontal development of the Damara Fold Belt structures is also expected to reduce surface land disturbance as well as the number of wells required per structure, resulting in lower field development costs and improved capital efficiency.
Based on formation imaging log analysis from wells drilled through the Otavi reservoir, the Jarvie-1 rig will drill the horizontal sidetrack laterals near fractures ranging 1.0 to 12.7 per metre running parallel to the fold structure. Two high pressure pumps, a swabbing unit and additional supporting equipment have been procured to effectively initiate the drilling and production testing operations. ReconAfrica has contracted H2OIL to conduct surface operations and provide additional surface equipment, including an appropriately sized separator unit. Halliburton will continue to provide downhole equipment and services.
The agreement gives Equinor access to a drill-ready prospect. (Image source: Equinor)
Equinor has stepped into Namibia with the acquisition of a 17.4% participating interest in Petroleum Exploration Licence 90 (PEL 90) in Orange Basin
The strategically secured agreement with Chevron subsidiary, Harmattan Energy, gives Equinor access to a drill-ready prospect that is scheduled for testing this year.
“This transaction aligns with our strategy to strengthen and replenish our international portfolio through focused and disciplined growth. Namibia is a promising basin that adds attractive option value to our portfolio and complements our broader Atlantic Margin position,” said Philippe Mathieu, executive vice president for exploration and production international.
The licence relates to Block 2813B in the Orange Basin, offshore Namibia, and is operated by Chevron. Prior to the transaction, Chevron’s subsidiary owned an interest of 52.5% in PEL 90, with the other partners in the licence being QatarEnergy (27.5%), Custos-subsidiary Trago Energy (10%) and the state-owned oil company NAMCOR (10%).
From Harmattan's end, this seems like a risk diversification move since January when the company had reported no commercial hydrocarbons from the licence's Kapana 1-X exploration well.
Harmattan, however, had acknowledged the data acquired from exploration operations as hopeful in terms of future programmes on PEL 90. “The geologic insights and improved confidence in the future programme on PEL 90 from these operations provides strong support for continued progress and value in our portfolio in Namibia’s Orange Basin,” said Knowledge Katti, chairman and CEO of Custos.
“We look forward to the many opportunities ahead to further unveil the quality of our unmatched position in the heart of the Orange Basin including the future activity on PEL 90 and the ongoing activity on PEL 83”. added Robert Bose, CEO of Sintana Energy, which enjoys a 49% indirect interest in Custos Energy.
The new agreement widens the scope of collaboration.
To put in place decarbonisation practices while working together on concessions, Algeria's state-owned oil company, Sonatrach, has signed a new Memorandum of Intent with Italian oil major, Eni, with international best practices in mind
The latest signing is built on a three-year Memorandum of Intent that was originally secured in 2023, committing to reducing gas flaring, valourising recovered gas, and mitigating emissions associated with upstream activities in Algeria.
The new agreement widens the scope of collaboration, including natural CO₂ removal initiatives through forestry projects, and advance monitoring, quantification and reduction of methane emissions based on international Oil & Gas standards.
The new Memorandum of Intent builds on the previous one by further broadening the scope of cooperation and introducing new areas of collaboration. In particular, the parties will cooperate in the field of natural CO₂ removal initiatives through forestry projects and will strengthen activities for the monitoring, quantification and reduction of methane emissions through the adoption relevant international oil & gas standards.
The technical analyses, capacity building initiatives and field visits that made up the carefully structured 2023 agreement have materialised in reduced fugitive and venting emissions, and flaring while boosting energy efficiency and unlocking opportunities for carbon capture, utilisation and storage. It has also produced technicians with new skills in generating the right measurements in terms of greenhouse gas and methane emissions reductions.
The most innovative outcome of the 2023 agreement has been the Leak Detection and Repair (LDAR) campaign, which was carried out across 800 km of pipelines, with around 7,500 monitored points and relevant reduction of fugitive emissions. LDAR measurement campaigns are now conducted autonomously on a routine basis in all joint ventures jointly operated by Eni and Sonatrach.
The evaluation of the baseline emissions was also carried out in six upstream assets operated by Eni and Sonatrach in the country.
Offshore Sao Tome and Príncipe is a challenging subsurface environment. (Image source: TGS)
Energy data and intelligence provider, TGS, has partnered with the National Petroleum Agency of Sao Tome and Príncipe (ANP-STP) to commence the Sao Tome and Príncipe 2D PSDM Reprocessing project
TGS will be leveraging four of its originally acquired input surveys on the region between 1999 and 2005 to reprocess about 14,651 km of 2D seismic data. While the last reprocessing was done in 2014, TGS will be upgrading it with a modern, comprehensive workflow, built on the combined strength of advanced pre-processing with velocity model building via Dynamic Matching elastic Full Waveform Inversion (E-DMFWI) and Kirchhoff Prestack Depth Migration (KPSDM). This will significantly refine imaging quality, ensuring maximum interpretation confidence.
Offshore Sao Tome and Príncipe is a challenging subsurface environment, characterised by volcanic activity, shallow channelisation and pervasive mass transport complexes that have made legacy seismic imaging and target depth positioning difficult. The 2D PSDM Reprocessing project will address these challenges specifically so that operators get clearer and geologically consistent insights into previously inaccessible subsurface areas.
TGS will take one complex setting at a time to generate sharp images so that clients have a solid technical basis to judge prospects and maturation for confident investment decision-making ahead of future licensing activity in the basin.
A priority subset of lines will be delivered within seven months, with final products for the full dataset expected in Q3 2027.
"This reprocessing project reflects our continued commitment to invest in the exploration potential of Sao Tome and Príncipe's offshore basin. By applying our most advanced imaging technology to this dataset, we are giving operators the subsurface clarity needed to confidently assess subsurface prospectivity, identify prospects and assign budget ready for future exploration success," said David Hajovsky, executive vice president-multi-client at TGS.
"This project is one of many that underscores TGS' broader commitment to supporting exploration success across the wider West African margin, where our sustained investment is helping operators de-risk plays and discover new opportunities ahead of acreage capture and support existing work commitments.”
This project is supported by industry funding.
Jarvie-1 rig will drill horizontal sidetrack laterals. (Image source: ReconAfrica)
Reconnaissance Energy Africa has completed vertical production testing on the Kavango West 1X (KW1X) well onshore Namibia, and is preparing to mobilise the Jarvie-1 rig to commence open-hole horizontal production testing operations in the Huttenberg formation, targeting up to 1,000 metres
The vertical production testing programme helped identify up to two well zones that contained hydrocarbons capable of flowing to surface. Natural gas and potential liquids flowed to surface from the upper Huttenberg as well as the upper Elandshoek zones. While targeting the Huttenberg zone of interest, flow was generated immediately upon perforation, even before subjection to acid stimulation, and was flared through the relief flare stack.
To achieve similar promising results from the four other zones of the well which are considerably shallower than the Elandshoek, open-hole horizontal production test was the best option available to target reservoir section previously untouched by production casing, cement and perforations. Completing the well open hole, without casing or cement, tends to maximise flow from fractures. This decision was reached on the basis of original well log analysis that indicated 75 metres of pay while confirming presence of matrix porosity between large natural fractures with inclinations of 50-90 degrees. These largely vertical fractures need complementing with perpendicularly drilled horizontal wells to hit the sweet spot.
“We are excited to report another critical milestone of the KW1X production test, which is achieving our primary objective of proving the flow of hydrocarbons to surface, this time from the uppermost zone of the Huttenberg formation. The vertical cased-hole phase of testing at KW1X is now complete and with the significant data and technical information gathered from this test, we have a high level of confidence moving forward with an open-hole horizontal production test in the Huttenberg formation.
"Importantly, KW1X's well results do not just validate a single structure; it also opens running room across the block. We have mapped 22 structures using existing seismic data and anticipate the inventory could grow with additional seismic coverage on PEL 73. We also believe our acreage in Angola could add additional structures to our inventory. These results have made critical steps to derisk and open a new play fairway.
Confirming the KW1X results with a flow rate test on a horizontal sidetrack as soon as possible will ultimately support resource and reserve bookings and a final investment decision on this emerging Damara Fold Belt Play," said Reconnaissance's President and CEO, Brian Reinsborough.
Horizontal development of the Damara Fold Belt structures is also expected to reduce surface land disturbance as well as the number of wells required per structure, resulting in lower field development costs and improved capital efficiency.
Based on formation imaging log analysis from wells drilled through the Otavi reservoir, the Jarvie-1 rig will drill the horizontal sidetrack laterals near fractures ranging 1.0 to 12.7 per metre running parallel to the fold structure. Two high pressure pumps, a swabbing unit and additional supporting equipment have been procured to effectively initiate the drilling and production testing operations. ReconAfrica has contracted H2OIL to conduct surface operations and provide additional surface equipment, including an appropriately sized separator unit. Halliburton will continue to provide downhole equipment and services.
Block CI-27 powers Abidjan in Ivory Coast.
Chevron will be assessing the tie-back potential of the discovery.
MegaSurveys are 3D seismic datasets synchronised across large contiguous areas. (Image source: TGS)
Energy data and intelligence provider, TGS, has signed an agreement with the Ministry of Hydrocarbon and Mining Development of the Republic of Equatorial Guinea to create MegaSurvey, a large-scale multi-client seismic product for offshore exploration
Beginning with the post-stack reprocessing of approximately 27,273 kilometers of 2D seismic data and around 35,000 square kilometers of 3D seismic data, the project is set to be completed in Q3 2026.
3D seismic datasets synchronised across large contiguous areas, MegaSurvey eliminates uncertainty by enabling nearly accurate geological interpretation, with clarity in structural and stratigraphic frameworks.
The agreement marks the first phase of a broader plan to create a harmonized and seamless seismic data product across Equatorial Guinea’s offshore basins. The full product vision includes approximately 46,343 line kilometers of 2D seismic data and more than 59,000 square kilometers of 3D seismic data.
David Hajovsky, Executive Vice President, Multi-Client at TGS, commented: “The Equatorial Guinea MegaSurvey is the first of its kind in the country and will apply TGS’s latest imaging technology to address key subsurface challenges and support exploration risk reduction across the Rio del Rey and Rio Muni basins. The product is designed to provide customers with a basin-wide regional screening tool, supporting prospect identification, prospect ranking and planning for future work commitments.”
By integrating and reprocessing legacy datasets into a consistent regional framework, the MegaSurvey will provide new insight into the prospectivity of Equatorial Guinea’s offshore basins and support informed exploration decision-making.
Offshore Sao Tome and Príncipe is a challenging subsurface environment. (Image source: TGS)
The survey will span across 34,000 kms offshore Egypt. (Image source: TGS)
Construction vessels FDS and Shen Da will be deployed.
Saipem has bagged a million euro contract offshore Ivory Coast for the third development phase of Eni's Baleine project
Saipem will be overseeing the engineering, fabrication, transportation and installation work at water depths up to 1,300 meters, building approximately 50 km of rigid pipelines and associated subsea structures. The project aligns with the energy services provider's reputation in delivering complex energy infrastructures of strategic importance to global operators.
Construction vessels FDS and Shen Da will be deployed for around three years to support operations of scale, involving the transportation and installation of flexible risers, flexible jumpers, subsea production systems and a 3-km-long flexible gas export flowline, as well as 22 km of subsea umbilical.
The strategically significant offshore project's engineering, procurement and construction works across multiple wells will be undertaken by SLB's OneSubsea joint venture. This will involve the installation of complete subsea production systems (SPS) for 13 wells.
This contract will support the entire well life cycle, starting with the installation of subsea trees, umbilical, manifolds, multiphase flowmeters and control systems, through to commissioning and life-of-field services. This integrated approach will streamline execution and support the project’s fast-track development schedule.
"Baleine Phase 3 brings together scale and execution certainty," said Mads Hjelmeland, chief executive officer of SLB OneSubsea. "Through our subsea production system technology and by leveraging our established local presence, we are supporting Eni’s efforts to advance a complex, deepwater project efficiently while contributing to the long-term development of offshore resources in Côte d’Ivoire."
TechnipFMC, too is contributing to the fast track development, establishing a network of flexible flowlines and risers to be connected to a new floating production unit.
Jonathan Landes, president-subsea for TechnipFMC, said, “This award marks the continued expansion of our collaboration with Eni. We are excited to apply our expertise to provide a robust flexible pipe solution with schedule certainty in support of this fast-track project.”
The submissions reveal an industrial shift towards smart, resilient and efficient energy systems.
MODEC's mooring system to support Coral Norte.
Flow rates were determined from the Metlawi reservoir.
A new gas discovery offshore western Libya has been confirmed by the National Oil Corporation (NOC) and Eni North Africa, following the drilling of the exploration well J1-4/16
After reaching a final depth of 10,458 ft, flow rates across two tests from the Metlawi reservoir stood at 14 million cubic feet per day through a 32/64-inch choke in the first test, and 24 MMcf/d through a 62/64-inch choke in the second.
Lying approximately 95 kilometers from the coast, the well forms part of Contract 4/16, where Eni is the operator, and also remains the final well in fulfilling nine contractual obligations for offshore Contract Block D, as stipulated in the agreement signed in June 2008.
This discovery can potentially add to Libya's production count, which saw an impressive rise last year. According to a table of the average daily crude oil production and total (cumulative) production figures for the past 10 years that was recently released by NOC Libya, 2025 had recorded the highest average production rate in comparison to the last decade, at 1.374 million barrels per day. Total crude oil production for the year reached 501 million barrels, marking a posititve shift in the NOC’s strategy to boost crude oil production rates.
Eni is set to launch three exploration plays in Libya – shallow, deepwater and ultra-deep offshore, and is also deeply invested in the region's gas with the US$10bn Greenstream pipeline and a CO2 capture and storage plant in Mellitah.
Reservoir properties were above pre-drill estimates.
TechnipFMC to support Eni's Baleine project offshore Ivory Coast.
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.
Tony Attah, managing director and chief executive officer, Renaissance Africa Energy Company. (Image source: Alain Charles Publishing)
At international Energy Week in London, Tony Attah, CEO of Renaissance Africa Energy Company, gave an impassioned presentation calling for Africa’s energy transition to be on African terms, urging global support and hailing the divestment of energy resources from international ownership into African hands
Attah began by acknowledging the role of the energy transition to protect the planet and ensure sustainability, but emphasised the need for a just and equitable transition, respecting Africa’s current realities.
“We need to talk about Africa’s energy transition on African terms. We are not challenging the timelines that have been set by Europe and the rest of the world; we are only insisting that these goals be achieved in the way of Africa’s current realities,” he said.
Attah noted the dual changes in Africa: the energy transition itself and the new phase of African ownership and participation in energy systems. Discussing the global energy context, he noted the rising energy demand and fragility of global energy systems, as evidenced by the Russia Ukraine war. Energy demand is still rising, with consumption of all energy sources, both renewables and fossil fuels, hitting record levels. And while global CO2 emissions have reached record levels for a fourth consecutive year, Africa is contributing just 4% of those emissions, but is still paying the price.
The world, including Africa will need more energy due to population growth and the rise of living standards, with global energy demand projected to grow by around 50% between 2018 and 2050. Africa’s population forecast to rise by 67% between 2018 and 2050, from 1.5bn to 2.5bn with Nigeria’s forecast to double from 200 to 400mn in the same time frame, raising the stark possibility of an energy deficit.
Energy paradox
Attah highlighted Africa’s energy paradox, noting its rich energy resources but widespread energy poverty. “We have world class solar energy resources, 40% of the global solar resource base, strong wind, major hydro and geothermal prospects, critical minerals and substantial hydrocarbons, yet we face an energy paradox where millions of Africans remain energy poor and by implication socially and economically very poor. Over 500 million Africans, nearly 43% of the population, lack direct access to electricity, and over 850 million people lacking access to clean cooking solutions, relying on traditional biomass like wood and charcoal, with a negative impact on health.
800,000 people die annually in Africa due to lack of clean energy including 100,000 in Nigeria, he noted, where 80 million Nigerians lack access to electricity. The country loses over US$29bn a year due to unreliable power supply, and 60% of manufacturing costs are attributed to lack of energy.
Africa needs to define its energy transition based on its current realities, he said.
“You cannot decarbonise the system that you have not yet built, and you cannot transition from the energy you do not have. That is the reality. This is the narrative that we as Renaissance are seeking to help reshape and change in the interests of Africa.”
Turning to the foundation of Renaissance Africa Energy Co, which will celebrate its first anniversary this March, he explained that IOC divestment had enables its shareholders to acquire Shell Nigeria’s onshore shallow water assets, marking a transition from international to African operatorship. These assets have now been successfully operated over the last 11 months. He acknowledged the Nigerian government’s speedy approval of the divestments and the major reforms that have energised the industry, as well as the support of NNPC.
“As our name connotes, it’s a new beginning and perhaps the greatest opportunity for Nigeria and indeed Africa that this energy renaissance is African owned and Africa led,” he noted, adding that the company has a bold vision to be Africa’s leading energy company enabling energy security and industrialisation in a sustainable manner. “This mission will be underpinned by our core values of collaboration, respect, integrity, safety and performance.”
The company has increased oil production by 100,000 in 100 days and contributes 2bn scf of gas to the global gas market, and is working to set the company on a growth path aligned with Nigeria’s ambition to produce 2mn BOPD by 2027 and 3mn bopd by 2030.
“African companies are not just replacing international companies. We are redefining the objectives of the assets linking production to power, to industry, to jobs, domestic value and by implication, economic and social political stability of Africa.”
Need for global support
Attah underlined the need for global support to enable Africa’s energy transition, including finance, technology and reliable infrastructure, to enable Africa to convert potential into progress, highlighting that Africa is rich in resources, talent and ambition and noting its young population.
“Africa should be enabled to lead its energy future on its own terms,” he stressed. “If the world wants Africa to replace diesel and biomass as the main energy source, then gas to power, grids and domestic systems must be financed and supported to power industries with lower emissions. Africa needs proven technologies deployed at scale, designed for reliability and real operating conditions. Gas, renewables, storage, grids must work together as systems. Africa’s transition will endure only if we invest in people, governance and operating discipline so Africa-led companies deliver competitively and responsibly for decades to come,” he said. “This is why the current shift in ownership matters.”
Attah highlighted the need for Africa governments to create certainty, stability and an enabling environment for investors to thrive, and urged global business to partner with Africa for mutual benefit, to integrate global energy systems and global financial institutions and release funds to unleash growth.
“If we get this right, we will build globally, more robust energy systems that will power industries strengthen societies, deliver dignity and reduce emissions in a manner that will enable climate change goals to be achieved sustainability, at least looking through the Africa lens,” he concluded. “Africa’s energy transition will not slow the global transition, it will strengthen it, because when Africa powers its people, builds its industries and grows responsibly the world does not lose; if anything its wins, and the vagaries associated with Africa’s underdevelopment will be a thing of the past.
He ended with the rallying cry, “Let the Africa energy renaissance begin!”
Lucia Witbooi, Vice President of the Republic of Namibia at NOGC 2026. (Image source: NOGC)
Early confirmed speakers at ADIPEC 2026 demonstrate global relevance. (Image source: DMG World Media)
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