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Eni has sold a 10% participating interest in the offshore Baleine project to the State Oil Company of the Republic of Azerbaijan (SOCAR)

The transaction reinforces international collaboration in Ivory Coast's energy sector and advances the ongoing development of Africa’s first net-zero Scope 1 and 2 upstream project.

Following the acquisition, the updated ownership structure of the Baleine field include Eni (Operator) with 37.25% shares, Vitol with 30.00% shares, Petroci with 22.75% shares and SOCAR with 10.00%.

Dual exploration model

The divestment aligns directly with Eni’s strategic initiative to streamline its upstream portfolio. Through its proprietary "dual exploration model," Eni leverages early equity dilution to monetise exploration successes rapidly while maintaining operational leadership and driving multi-phase development.

Production milestones and future growth

Baleine was discovered in 2021, ending a two-decade gap in major commercial discoveries within the basin. The giant field achieved first production in record time by 2023.

Phases 1 and 2 currently generate more than 57,000 barrels of oil and more than 78 million cubic feet of natural gas per day.

Once Phase 3 is launched, output is projected to reach 150,000 barrels of oil and 200 million cubic feet of gas daily, cementing the project’s role as the primary catalyst for Ivory Coast's energy security.

Eni’s presence in the country, established in 2015, extends beyond Baleine. The company holds a 90% operating interest in the nearby Calao and Calao South discoveries—the second-largest findings in Ivory Coast after Baleine—confirming the prolific potential of the basin.

As a globally integrated energy firm headquartered in Azerbaijan, SOCAR operates across the entire energy value chain, including upstream exploration, refining, petrochemicals, logistics, and trading. The partnership combines operational strengths to maximise the long-term potential of Ivory Coast's energy resources.

Eni is a global energy company operating across the entire supply chain, committed to achieving net-zero emissions by 2050 through innovative energy solutions and sustainable asset management.

The State Oil Company of the Republic of Azerbaijan (SOCAR) is a major international energy player engaged in exploration, production, processing, and global supply distribution.

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.

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).

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."

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.

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; this was 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

Local content set the tone for the recently held Namibia Oil and Gas Conference and Exhibition (NOGC) in Windhoek, and factors that drove the sessions and conversations included: 

• Capitalisation of petroleum opportunity

• Generation of 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.