In The Spotlight
The agreement was signed in the Angolan capital Luanda. (Image source: QatarEnergy)
Interests in Blocks 8 and 22 offshore the Republic of Angola has been secured by QatarEnergy, alongside its partners Shell and Sonangol E&P
The energy major from Qatar signed an agreement with Angola’s National Agency for Oil, Gas, and Biofuels (ANPG) to formalise the interests.
Under the agreement, and subject to the relevant governmental approvals and final contractual arrangements, QatarEnergy will hold a 30% working interest, while Shell (the operator) will hold 50%, and Sonangol will hold 20% in the two offshore blocks.
Commenting on this occasion, Saad Sherida Al-Kaabi, the Minister of State for Energy Affairs, the President and CEO of QatarEnergy, said, “QatarEnergy is pleased to sign this agreement and to establish a presence in the energy sector of the Republic of Angola as part of our international upstream exploration strategy and growth efforts. We would like to thank the Angolan authorities, and our partners Shell and Sonangol, for their cooperation and support. We look forward to a longstanding and fruitful partnership.”
The agreement was signed in the Angolan capital Luanda on the sidelines of the Angola Oil & Gas Conference.
Previously, the government of Egypt approved for Qatar Energy a 40% stake in an offshore concession where Eni is the operator with 60% interest.
The concession is applicable for the North Rafah offshore block located in the Mediterranean Sea, off the northeastern coast of Egypt. It spans nearly 3,000 sq km in water depths of up to 450 meters.
“We are pleased with our new position in the North Rafah offshore block, which further strengthens our presence in Egypt and marks another important step in advancing our ambitious international exploration strategy,” said Al-Kaabi.
“We extend our thanks to the Ministry of Petroleum and Natural Mineral Resources in Egypt, and our partner Eni for their valued support and cooperation. We look forward to working together to achieve our exploration objectives,” he added.
Sintana has acquired 44% interest in Maravilla Oil and Gas.
One of Africa’s most active emerging energy frontiers, Namibia’s Walvis Basin is a prospective exploration site for operators both major and small
The image of West Africa conjures, for operators, major high-impact exploration opportunities. Keen on securing interests in the region, Sintana Energy has strategically expanded its offshore footprint by acquiring a significant stake in Maravilla Oil and Gas. International reach besides, the acquisition will also strengthen Sintana's on-ground presence as it pledges local community development in Namibia’s Erongo Region. It will give the company a technical edge through regional synergies with existing acreage. The company will leverage the acquisition to capitalise on upcoming multi-operator offshore drilling campaigns and region-wide exploration milestones.
Sintana Energy has announced the acquisition of a 44% interest in a privately held Namibian company called Maravilla Oil and Gas that is focused on high-impact opportunities in West Africa
This opens up for Sintana Energy several doors across Namibia's frontier acreages as Maravilla continues to expand regionally. Maravilla already owns 80% controlling shareholding in Namibian private company, Paragon, which in turn owns a 100% operated interest in Petroleum Exploration License 37 (PEL 37) located in the Walvis Basin offshore Namibia. Sintana's investment in Maravilla provides an indirect 35% interest in PEL 37.
Exploration on PEL 37
With this acquisition, Maravilla will get increased support from Sintana in resources development, as they collaborate to mature and refine opportunities including an inventory of prospects on PEL 37. Spread across an area of 17,295 sq km in relatively shallow waters (100 - 1,500m), with identified prospects at water depths between 300 and 600m, and with multiple large fans directly overlying a proven, mature oil-prone Aptian source rock.
The license comes with an extensive technical database already in place, including 2,813 sq km (2014) of 3D seismic data, ~1,000 line kms of 2D seismic data (2014), and historical drilling activity (Cormorant-1 (2018), Sasoil (1995)).
Sintana also holds a 10% indirect interest in PEL 82, which lies north of PEL 37, and is operated by an affiliate of Chevron Corporation. PEL 82 is approximately 70% covered in 3D seismic and is home to the Murumbe-1 and Wingat-1 wells that had previously revealed light oil prospects. This geographic and technical setting of the two licenses will be mutually benefitial in future drilling outcomes and read through implications.
They will also focus on identifying and evaluating capital-efficient, high-impact opportunities in West Africa more broadly.
Chevron is gearing up for a busy year exploration-wise, with an inaugural exploration well expected in 2027. PEL 82 besides, in April 2026, Eco (Atlantic) Oil & Gas Ltd announced the farm down of interests in three of its licences in the Walvis Basin (adjacent to PEL 82 and PEL 37) to bp PLC, and is expecting to conduct significant activities on these licences over the coming 12-24 months. This includes seismic acquisition, reprocessing and potential exploration well decisions.
In conjunction with Sintana's investment, Maravilla will make a Namibian $1mm donation to the communities in the Erongo Region to be distributed in co-ordination with the Office of the Governor, Natalia IGoagoses and the Knowledge Foundation, led by Knowledge Katti.
Cost-effective exposure to high-impact exploration
Robert Bose, CEO of Sintana, said, "Expanding our platform though an investment in Maravilla is the continuing demonstration of our ability to secure cost-effective exposure to high-impact exploration licenses in emerging basins. The expansion of our Walvis Basin footprint positions us to participate in the next chapter of Namibia's offshore success. We look forward to providing updates on progress in the coming quarters."
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."
TotalEnergies holds a 40% operated interest in the PEL83.
As key licenses in Namibia inch towards production goals, major players in the region are trying to secure their positions as significant deepwater operators in the prolific Orange Basin
Having drawn the interests of oil giants like TotalEnergies and Galp, Namibia is on the path to become a happening regional production hub. TotalEnergies and Galp besides, key international partners in the region are accelerating exploration, appraisal and commercial development.
License interests and asset swap
TotalEnergies has concluded the transaction with Galp which initiated in December 2025.
The major has acquired from Galp a 40% operated interest in the PEL83 license, holding the Mopane discovery, while Galp took a 10% participating interest from TotalEnergies in the PEL56 license, holding the Venus discovery and a 9.39% participating interest in the PEL91 license.
Further to the completion of this transaction, TotalEnergies holds a 40% operated interest in the PEL83 license alongside Galp (40%), Namcor (10%) and Custos (10%), a 35.25% operated interest in the PEL56 license, alongside QatarEnergy (35.25%), Galp (10%), Namcor (10%) and Impact (9.5%), as well as a 33.09% operated interest in PEL91 alongside QatarEnergy (33.03%), Namcor (15%), Impact (9.5%) and Galp (9.39%).
Strategic milestones and Mopane appraisal timeline
“We would like to thank the Namibian authorities for their swift approval of this strategic transaction with Galp, our new partner in Namibia. TotalEnergies' entry as operator of the giant Mopane discovery marks a key milestone in our journey to establish a major production hub in Namibia”, said Patrick Pouyanne, chairman and CEO of TotalEnergies. “This transaction positions TotalEnergies as the operator of Namibia's two largest oil discoveries and strengthens its position in the Orange Basin, supporting the long-term value creation from prolific licenses. Exploration opportunities are already lining up beyond the Mopane development, which we will start appraising as early as the second half of 2026 aiming at taking the FID of the project in 2028, after a 3 appraisal well campaign”.
The partners will launch an exploration and appraisal campaign including three wells over the next two years, with a first well planned in 2026, to further derisk resources and progress diligently toward the development of the Mopane discovery.
Concurrently, TotalEnergies, operator of PEL56, remains fully committed to the development of the Venus discovery and is working to secure all conditions enabling a potential final investment decision in 2026.
Industry collaboration and hub vision
"We are very happy to have been selected by Galp as their partner and operator for the prolific PEL83 license, including the Mopane discovery in Namibia. This is a strong recognition of the exploration and deepwater competences of TotalEnergies teams. This transaction demonstrates also the strong confidence of TotalEnergies towards Namibia as a future oil producing country. TotalEnergies will leverage its recognised operatorship track record to progress towards profitable and sustainable developments of both Venus and Mopane discoveries. By enabling the creation of a producing hub in Namibia, we aim to achieve synergies that will create long-term value for both Namibia and the stakeholders," said Pouyanne last year. "We are eager to keep building on our collaboration with the Namibian authorities in order to deliver both developments."
The last date for bids submission is 8 January 2027.
When participating in bid rounds, investors usually seek access to proven petroleum systems, key exploratory leads and significant cross-border energy assets
The Joint Oil Block and the strategic Zarat Discovery in the Gabes-Tripoli Basin that is up for bidding by Joint Oil and Moyes & Co promises these offerings with the high-potential 3,000 sq km opportunity.
Bid round launch and presentation
Joint Oil Exploration, Exploitation and Petroleum Services Company (Joint Oil) and its appointed advisor, Moyes & Co. (Moyes) have announced the Joint Oil Block and Zarat Discovery bid round from 7 September to 31 December 2026
The bid round opportunity will be presented at the World Energy Summit in London on 29-30 September 2026. The last date for bids submission is 8 January 2027. Winning bidders will be informed by 26 February 2027, with formal awards expected by 30 April 2027.
Spanning an area of 3,000 sq km at water depths of 80-120m, the offshore acreage available for the bid round is located in the prolific Gabes-Tripoli Basin of the central Mediterranean. This can potentially advance cross-border energy cooperation between Tunisia and Libya.
Commercial framework and seismic data assets
The commercial packages that make up the bid offer comes in the form of an exploration and production sharing agreement (EPSA). With 6,500 km of 2D and 1,900km of 3D seismic data available for the acreage, it unlocks access to new plays, leads, and prospects:
- Zohra-1 (1976)
- El Amal South 1 (1999)
- Besmah-1 (2002)
- El Amal North 1 (2002)
- Zarat North 1 (2010)
- El Bouri, El Jurf and Bihr El Salam in Libya
- Hasdrubal, Ashtart, Miskar & Didon in Tunisia
The development of the Zarat Discovery — which straddles the Tunisia-Libya border — is a unitised oil and gas resource. This will be governed by a development and production sharing agreement (DPSA), unitisation agreement (UA), unit operating agreement (UOA), and operating services contract (OSC).
Strategic location
The concession is blessed with a highly strategic offshore location that lies close to several major producing fields across the Sabratha-Gabes Basin, including Al Jurf, Bahr Essalam, and Bouri offshore Libya, as well as Ashtart, Didon, and Miskar offshore Tunisia. This positioning enhances the project’s long-term value proposition through access to established regional infrastructure, operational synergies, and export pathways.
Angola's largest privately owned energy company, Etu Energias has signed a sale and purchase agreement (SPA) with Cabinda Gulf Oil Company Limited (CABGOC or Chevron) for the acquisition of a 31% Working Interest (WI) in Block 14 and a 15.5% WI in Block 14K offshore Cabinda
This follows the exercise of pre-emption rights by Etu Energias, as an existing partner in both licenses. Etu Energias currently holds a 29% WI in Block 14 and a 14.5% WI in Block 14K. With completion of the acquisition, Etu Energias will become the largest interest holder of one of Angola's longest established deepwater producing assets. The company is also aiming to assume the role of Operator on Block
14, subject to regulatory approval.
The acquisition is supported by a framework agreement with BW Energy and Chariot Limited, and will be funded by a debt facility provided by Shell Western Supply and Trading Ltd..
The transaction can take up to early 2027, following customary conditions including approval by the Agencia Nacional de Petroleo Gas e Biocombustíveis (ANPG), other regulatory entities and the receipt of required third-party consents.
Edson R. dos Santos, chairman and chief executive officer, Etu Energias, said, "This transaction is a very important milestone in the development of Etu Energias as an Angolan company with a global vision. It’s about more than production and reserves; it’s about building enduring capabilities in Angola and developing deepwater operating expertise that can create value for many years to come.”
“Block 14 has been producing for more than a quarter of a century and we believe it still holds significant value. We have an in-depth knowledge of these assets, having been a partner on the licenses for many years, and believe that we can unlock further value from them for the benefit of Etu Energias, our partners and the economy of Angola going forward.”
"We are grateful to Chevron for a professional process and for the operating standards they have established over many years. We look forward to working with the ANPG and our partners to complete this transaction."
Block 14 is a producing deepwater license offshore Cabinda in water depths of 200 to 1,600 metres. The block has produced more than 900 million barrels of high-quality, Brent-linked crude since first oiil in 1999, with production peaking at approximately 200 kbopd.
Production comes from nine fields developed through the Benguela Belize Lobito Tomboco and Tombua-Landana hub facilities (BBLT & TL), supported by active waterflooding and well intervention programmes. Abandonment obligations for Block 14 are fully funded through existing escrow provisions.
Block 14K contains the Lianzi field, a cross-border unitised development between Angola and the Republic of Congo, tied back to Block 14 infrastructure.
BluEnergies, alongwith TTE, are working to identify drillable prospects in blocks from the Harper Basin offshore Liberia as part of their work programme
Ongoing work on the blocks LB-26, LB-30 and LB-31 involves data reprocessing for which TGS and GeoPartners have been deployed. About 6,167 sq kms of 3-D seismic data has been reprocessed by TGS to enhance the seismic character/definition and the AVO content (Direct Hydrocarbon Indicator) of the original 3-D seismic survey.
High-resolution MBES survey
GeoPartners has deployed a R/V GYRE vessel to conduct within the blocks a Multi-Beam Eco Sounder survey (MBES) comprising an area of 4,045 sq km in water depths ranging from 500 meters to 3,500 meters. Completion of this acquisition is being aimed in so that the integration process can be accelerated to achieve a refined 3-D seismic data interpretation.
The MBES can map underwater terrain, aiding in identifying sea bottom anomalies, supporting the safe selection of future drilling locations. It can identify seabed geomorphologies (pockmarks, mud volcanoes, faults, etc.) and the presence of anomalous features (carbonates, outcrops, bacterial mats, etc.). This special survey can perform water column imaging for the detection of anomalies related to seepage of hydrocarbons through the sea bottom.
Seabed Geochemical Sampling is conducted through piston coring to collect evidence of migrated mature hydrocarbons (detection of fluorescent/natural oil compounds, hydrocarbon chromatography, thermogenic origin, etc.).
Geological context
Sergio Laura, BluEnergies’ Vice President of Exploration, said, “The West Africa Transform Margin, where the Harper basin is located, and its conjugate South American Margin are regions where basin floor fan plays are being actively and successfully explored, developed and produced. The recent, hectic activity by major oil companies in securing licenses for deepwater acreage along the entire Africa west margin is confirmation that the early move by BluEnergies in the Harper basin (2023) was a valid one. The Jubilee field in Ghana, the Venus field in Namibia, and the recent discoveries offshore Cote d’Ivoire have proven the significance of basin floor fan plays along the African margin.”
TotalEnergies holds a 40% operated interest in the PEL83.
As key licenses in Namibia inch towards production goals, major players in the region are trying to secure their positions as significant deepwater operators in the prolific Orange Basin
Having drawn the interests of oil giants like TotalEnergies and Galp, Namibia is on the path to become a happening regional production hub. TotalEnergies and Galp besides, key international partners in the region are accelerating exploration, appraisal and commercial development.
License interests and asset swap
TotalEnergies has concluded the transaction with Galp which initiated in December 2025.
The major has acquired from Galp a 40% operated interest in the PEL83 license, holding the Mopane discovery, while Galp took a 10% participating interest from TotalEnergies in the PEL56 license, holding the Venus discovery and a 9.39% participating interest in the PEL91 license.
Further to the completion of this transaction, TotalEnergies holds a 40% operated interest in the PEL83 license alongside Galp (40%), Namcor (10%) and Custos (10%), a 35.25% operated interest in the PEL56 license, alongside QatarEnergy (35.25%), Galp (10%), Namcor (10%) and Impact (9.5%), as well as a 33.09% operated interest in PEL91 alongside QatarEnergy (33.03%), Namcor (15%), Impact (9.5%) and Galp (9.39%).
Strategic milestones and Mopane appraisal timeline
“We would like to thank the Namibian authorities for their swift approval of this strategic transaction with Galp, our new partner in Namibia. TotalEnergies' entry as operator of the giant Mopane discovery marks a key milestone in our journey to establish a major production hub in Namibia”, said Patrick Pouyanne, chairman and CEO of TotalEnergies. “This transaction positions TotalEnergies as the operator of Namibia's two largest oil discoveries and strengthens its position in the Orange Basin, supporting the long-term value creation from prolific licenses. Exploration opportunities are already lining up beyond the Mopane development, which we will start appraising as early as the second half of 2026 aiming at taking the FID of the project in 2028, after a 3 appraisal well campaign”.
The partners will launch an exploration and appraisal campaign including three wells over the next two years, with a first well planned in 2026, to further derisk resources and progress diligently toward the development of the Mopane discovery.
Concurrently, TotalEnergies, operator of PEL56, remains fully committed to the development of the Venus discovery and is working to secure all conditions enabling a potential final investment decision in 2026.
Industry collaboration and hub vision
"We are very happy to have been selected by Galp as their partner and operator for the prolific PEL83 license, including the Mopane discovery in Namibia. This is a strong recognition of the exploration and deepwater competences of TotalEnergies teams. This transaction demonstrates also the strong confidence of TotalEnergies towards Namibia as a future oil producing country. TotalEnergies will leverage its recognised operatorship track record to progress towards profitable and sustainable developments of both Venus and Mopane discoveries. By enabling the creation of a producing hub in Namibia, we aim to achieve synergies that will create long-term value for both Namibia and the stakeholders," said Pouyanne last year. "We are eager to keep building on our collaboration with the Namibian authorities in order to deliver both developments."
The agreement was signed in the Angolan capital Luanda. (Image source: QatarEnergy)
Sintana has acquired 44% interest in Maravilla Oil and Gas.
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)
MODEC's mooring system to support Coral Norte.
MODEC, Inc has announced that it will supply a SOFEC Internal Turret Mooring System for the Coral Norte FLNG project offshore Mozambique, developed by Eni and its partners CNPC, ENH, XRG and KOGAS
The company is collaborating with the Technip Energies JGC joint venture (JV) to support seamless integration, efficient execution and reliable long term performance.
With Final Investment Decision achieved in October 2025, the hull launch completed in January 2026 at Samsung Heavy Industries’ Geoje shipyard in South Korea, and first LNG targeted for 2028, the project is advancing on schedule. MODEC has supported the project since the early stages and is progressing engineering and supply activities in line with the overall timeline, underscoring the company’s contribution to mission‑critical station‑keeping for large‑scale gas developments.
Building on proven performance on the companion Coral Sul FLNG, this engagement reinforces MODEC’s track record in complex offshore station‑keeping. Designed as an enhanced replica of Coral Sul — incorporating lessons learned and optimized for improved efficiency and performance — Coral Norte will add 3.6 MTPA of liquefaction capacity.
The turret mooring system is a mission‑critical element of FLNG performance, enabling safe weathervaning, high uptime, and resilient operations in the metocean conditions of the Rovuma Basin. Drawing on decades of experience across FLNG and FPSO projects worldwide, MODEC is applying advanced engineering, robust risk management, and disciplined execution to deliver the SOFEC® Internal Turret Mooring System for Coral Norte from design through delivery.
“Coral Norte is an important milestone for the industry and for Mozambique, and we are honored to contribute to this landmark FLNG project,” said Arun Duggal, Head of MODEC’s Mooring Solutions Business Unit. “Our team’s performance on Coral Sul set a high bar for safety, reliability, and schedule discipline. This engagement reflects the trust we have built together, and we look forward to delivering a SOFEC® turret mooring system that enables best‑in‑class operability — while continuing to invest in local capability and laying the foundation for future projects in the region.”
A Technip Energies–JGC JV spokesperson commented: “The work delivered by MODEC on Coral Sul established a strong operational baseline and demonstrated clear excellence in engineering and execution. Our partnership on Coral Norte builds on that success and supports our broader commitment to sustainable development in Mozambique.”
PipeSense deployed PipeScan, a pressure-pulse technology, to locate obstructions in two offshore pipeline networks. (Image Source: PipeSense)
The submissions reveal an industrial shift towards smart, resilient and efficient energy systems.
TechnipFMC to support Eni's Baleine project offshore Ivory Coast.
As Eni SpA works to expand production from the Baleine Phase 3 fast track development offshore Ivory Coast, it has signed a significant contract with TechnipFMC to secure its support services
Known as one the largest hydrocarbon discoveries in the region, the fast track development will be supported with a network of flexible flowlines and risers that will be designed and build by TechnipFMC to connect wells in water depths of approximately 1,200 meters 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.”
Previously, TechnipFMC bagged a engineering, procurement, construction, and installation contract offshore Mozambique for the Coral North development in water depths of approximately 2,000 m.
“We are excited to once again work with Eni and their consortium partners in Mozambique. We will leverage our experience gained from the successful delivery of Coral South—the world’s first FLNG project in ultradeep water—by replicating our proven playbook with an enhanced approach,” said Landes.
The contract will require TechnipFMC to manufacture and install flexible flowlines and risers, alongside subsea manifolds and umbilicals.
TechnipFMC has secured the contract from the project's operator, Eni, who reached the final investment decision of the Coral North project in October this year, and aims delivery by 2028.
While Eni is leading the venture with a 50% share, other partners include CNPC (20%), Kogas (10%), ENH (10%) and ADNOC-subsidiary XRG (10%). Eni will be investing on the development of a state-of-the-art floating LNG facility in the Rovuma Basin, where it will be generating gas volumes from the northern part of Area’s 4 Coral gas reservoir.
The Coral North development follows the success of the Coral South project, which effectively continues to be in production.
First gas from NT-1 and NT-2 is targeted for December.
Reservoir properties were above pre-drill estimates.
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.
Early confirmed speakers at ADIPEC 2026 demonstrate global relevance. (Image source: DMG World Media)
As the energy sector navigates rising demand, geopolitical uncertainty, infrastructure pressures and rapid technological change, ADIPEC 2026 is set to bring together some of the world's most influential leaders from Africa, Asia, Europe and the Americas, to help shape the future of global energy systems
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 2–5 November 2026, convening policymakers, industry executives, technology innovators and investors from around the world.
Among the early confirmed speakers are a number of the energy sector’s most prominent voices, reflecting the diverse breadth of expertise and perspectives that will be represented across this year's programme.
Confirmed leaders include: Proscovia Nabbanja, CEO, Uganda National Oil Company; Wael Sawan, CEO, Shell; Claudio Descalzi, CEO of ENI; Osama Mobarez, Secretary General, EMGF; Olivier Le Peuch, CEO of SLB; Lorenzo Simonelli, Chairman and CEO of Baker Hughes; Horacio Marín, Chairman of the Board and CEO of YPF; Yoshinori Kanehana, Chairman of the Board of Kawasaki Heavy Industries; Dr Angela Wilkinson, Secretary General and CEO of the World Energy Council; Aliko Dangote, President and CEO of Dangote Group; Hunter Hunt, Chairman and CEO of Hunt Energy Holdings; Stuart Bradie, Chair of the Board, President and CEO of KBR; and Professor Haruhiko Ando, CEO of the Japan Cooperation Center for Petroleum and Sustainable Energy.
These leaders will contribute to an expanded Strategic Conference designed around the key challenges and opportunities shaping energy markets today. Featuring more than 380 sessions across 11 specialised programmes, the conference will explore topics including energy security and resilience, market stability, infrastructure delivery, investment, workforce development, industrial competitiveness and the growing role of AI in transforming energy systems.
New programmes for 2026 include Energy Security & Resilience, Policy, Regulation & Governance, Upstream, Clean Power, Molecules & Carbon Management, Grids, Infrastructure & Industrial Execution, and Workforce & Skills. Existing programmes have also been refreshed to better reflect evolving industry priorities, including AI, Digital & Technology and Downstream, Chemicals & Industrial Value Chains.
In parallel, ADIPEC's exhibition will bring together more than 2,250 companies across 17 halls, including 54 national, international, integrated and independent energy companies, alongside 30 country pavilions. New features such as an expanded AI Zone and an enhanced Low Carbon and Chemicals Zone will showcase technologies and solutions supporting the next phase of energy development.
Expected to attract more than 239,000 attendees, 1,800 speakers and 16,500 delegates, ADIPEC 2026 will serve as a global platform for the partnerships, investment decisions and innovations needed to strengthen energy systems and support long-term economic growth.
Energy leaders from across Africa will participate in the Strategic Conference. (Image source: dmg events)
Lucia Witbooi, Vice President of the Republic of Namibia at NOGC 2026. (Image source: NOGC)
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The Agogo project involves the development of Agogo and Ndungu fields.
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The two subsea tie-back projects will deliver additional production. (Image source: TotalEnergies)
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A single well location can now be pinpointed at Oryx prospect. (Image source: Pancontinental Energy)
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Both partners have entered into detailed commercial discussions.
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The sale of its Gabon assets marks Tullow’s exit from its licences in Gabon after 21 years.
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Initial results from drilling and logging the Begonia-2 appraisal well are successful.
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The Kavango West 1X well was spud on July.
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BW Energy delivered a strong first half of 2025.
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Capricorn forecasts the drilling of 10 development wells for H2 2025.
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The MoU will advance regional energy development in sub-Saharan Africa.
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The rig will be used for drilling the Kharas appraisal well.
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63 wells in Tilenga and 9 in Kingfisher have been drilled. (Image source: Adobe Stock)
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Bourbon will utilise its data management system for end-to-end execution. (Image source: Adobe Stock)
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Major operators are increasingly adopt AI. (Image source: African Energy Chamber)
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PetroVision will facilitate operations within Nigeria using DUG Insight software. (Image source: Adobe Stock)
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The locations will employ locals and are expected to grow Namibia’s energy sector. (Image source: Halliburton)
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The Cabinda Refinery aims to double capacity to 60,000 bpd. (Image source: Adobe Stock)
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Sanha Lean Gas Connection is a project by Cabinda Gulf Oil Company Limited. (Image source: Chevron)
Latest News
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Sintana has acquired 44% interest in Maravilla Oil and Gas.
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First gas from NT-1 and NT-2 is targeted for December.
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TotalEnergies holds a 40% operated interest in the PEL83.
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The last date for bids submission is 8 January 2027.
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Offshore Sao Tome and Príncipe is a challenging subsurface environment. (Image source: TGS)
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The agreement was signed in the Angolan capital Luanda. (Image source: QatarEnergy)
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Weatherford secures new work in the Middle East (Image source: Adobe Stock)
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Energy leaders from across Africa will participate in the Strategic Conference. (Image source: dmg events)
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PipeSense deployed PipeScan, a pressure-pulse technology, to locate obstructions in two offshore pipeline networks. (Image Source: PipeSense)
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Petrobras gets direct entry into the negotiation phase.
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Lucia Witbooi, Vice President of the Republic of Namibia at NOGC 2026. (Image source: NOGC)
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Block CI-27 powers Abidjan in Ivory Coast.
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Chevron will be assessing the tie-back potential of the discovery.
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The agreement gives Equinor access to a drill-ready prospect. (Image source: Equinor)
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Jarvie-1 rig will drill horizontal sidetrack laterals. (Image source: ReconAfrica)
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The new agreement widens the scope of collaboration.
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The drillship Santorini offshore Ivory Coast.
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Nigeria is joining the IEA. (Image source: IEA)
More Articles
PipeSense deployed PipeScan, a pressure-pulse technology, to locate obstructions in two offshore pipeline networks. (Image Source: PipeSense)
The submissions reveal an industrial shift towards smart, resilient and efficient energy systems.
MODEC's mooring system to support Coral Norte.
Construction vessels FDS and Shen Da will be deployed.
SLB launches digital marketplace for energy companies. (Image source: SLB)
The Technical Conference is organised by SPE. (Image source: dmg media)
Baker Hughes and NLNG collaboration continue to run strong. (Image source: Baker Hughes)
Baker Hughes offering lifecycle solutions for ANOH Gas project.
The project is operated by Burullus Gas Company. (Image source: Strohm)
Digitalisation and AI will create close to US$500bn in cumulative value for E&P companies between 2026 and 2030.