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The Senegalese government has opened 104 oil and gas blocks to international investors, seeking new upstream exploration and production contracts to accelerate the development of its natural resources.

Exploration

West Africa's hydrocarbon landscape is shifting rapidly towards large-scale acreage commercialisation, and Senegal is now positioning itself at the very forefront of this regional drive.

The Senegalese government has opened 104 oil and gas blocks to international investors, seeking new upstream exploration and production contracts to accelerate the development of its natural resources.

Announced by Energy and Petroleum Minister El Hadji Abdourahmane Diouf at African Energy Week (AEW) 2026 in Cape Town, the offering signals an aggressive push to draw foreign direct investment into the nation's energy sector while expanding domestic industrial capacity.

A Reorganised Acreage Landscape

The newly available assets stem from a major restructuring carried out earlier this year. In March 2026, Senegal reorganised its acreage into 113 distinct blocks, comprising 65 onshore and 48 offshore tracts. While Oil & Gas Middle East reported in September that 109 blocks were being marketed, the portfolio status has since crystallised:

  • 104 blocks are actively open and available to international investors.
  • 4 blocks are already held under existing petroleum contracts.
  • 5 offshore blocks are currently assigned to Italian energy major Eni for technical evaluations.

Eni agreed to fund these technical assessments under a memorandum signed on the sidelines of Gastech. Crucially, the agreement functions strictly as a study framework rather than an upstream petroleum contract, conferring no automatic operational rights.

Addressing delegates in Cape Town, Diouf emphasised regulatory certainty, stating that the objective is to “show investors that Senegal remains the country it has always been: open, hospitable and respectful of international procedures.”

Fast-Tracking Yakaar-Teranga and Domestic Gas

Beyond newly delineated licensing blocks, Senegal is prioritising major offshore gas assets to anchor national electrification and industrialisation. The state is actively searching for commercial partners to advance the world-scale Yakaar-Teranga gas project alongside national oil company Petrosen.

Petrosen assumed complete operational control of the asset after Kosmos Energy withdrew in April. According to reporting by Ecofin Agency, the exit involved no financial compensation, leaving Petrosen’s leadership targeting initial commercial production between late 2028 and early 2029—a timetable viewed by several market analysts as optimistic.

The government views gas monetisation as an essential catalyst for broader economic transformation rather than a simple export play. As Diouf noted: “Our strategy is to build the value chain from the well to the factory, with gas at the heart of our industrial ambition.” Under this framework, Yakaar-Teranga will deliver feedstock for domestic power generation, industrial facilities such as fertiliser plants, and international liquefied natural gas markets.

Downstream Ambitions and Regional Integration

Senegal’s upstream momentum is matched by targeted downstream development intended to retain processing margins onshore. Diouf highlighted ongoing plans to construct a second domestic refinery dedicated to processing crude from the offshore Sangomar field, requiring an estimated capital investment of $2 billion to $3 billion (approximately AED 7.35 billion to AED 11.02 billion).

On 23 September in New York, the Société Africaine de Raffinage (SAR) signed a memorandum with Turkish contractor Yamata to develop the proposed four-million-tonne-per-annum refining facility. Similar to Eni’s offshore arrangement, reports have noted that this document remains a preliminary memorandum rather than a fully binding commercial contract.

Domestic integration and capacity building remain central conditions for incoming capital. Diouf explicitly urged new entrants to incorporate domestic suppliers and local labour into their operations from project inception. “Capital must earn a return. Senegal must gain a stronger economy. The partnership we seek must serve both purposes,” he affirmed.

Concurrently, Dakar is championing deeper regional collaboration across the MSGBC basin. Senegal intends to broaden the current five-nation alliance—comprising Senegal, Mauritania, The Gambia, Guinea-Bissau, and Guinea—into a larger regional energy coalition, establishing West Africa as a unified, competitive energy frontier.

During a prominent energy conference held recently in Cape Town, a senior government official revealed that Angola intends to implement faster exploration concessions from next year.

Exploration

During a prominent energy conference held recently in Cape Town, a senior government official revealed that Angola intends to implement faster exploration concessions from next year.

This significant shift in policy forms the cornerstone of a newly developed, long-term hydrocarbon strategy. The primary objective of this comprehensive strategy is to attract substantial foreign investment and actively stimulate oil and gas production across the nation. As Sub-Saharan Africa’s second-largest oil producer—trailing only behind Nigeria—Angola is positioning itself to remain highly competitive in an evolving global energy landscape.

A 25-Year Blueprint for Energy Investment

At the heart of this strategic overhaul is an ambitious 25-year plan designed to revitalise the nation's energy sector. This extensive blueprint seeks to build upon a series of successful regulatory reforms that have already yielded positive results for the domestic market. In recent times, these legislative and structural adjustments have encouraged major international oil companies, including industry leaders such as TotalEnergies and Eni, to commit billions of dollars to various energy projects within the country. The upcoming 25-year framework aims to solidify this momentum, ensuring that the regulatory environment remains exceptionally hospitable to large-scale, long-term capital commitments.

Overhauling the Concession and Auction Framework

In a move to streamline operations, Angola intends to drop its traditional multi-year oil and gas auction rounds. Historically, these prolonged auction cycles dictated the pace of exploration, often resulting in extended periods between new drilling initiatives. Moving forward, the government will replace this system with a more dynamic and responsive approach.

Key changes to the exploration rollout include:

  • Opening New Blocks: The nation plans to open up more than 100 blocks for energy exploration.
  • Onshore Focus: The vast majority of these newly available blocks will be strategically located onshore.
  • Implementation Timeline: This expansive rollout is scheduled to commence as soon as the 25-year plan is formally passed later this year.

Speaking late on Wednesday, Alcides Andrade, a board member at the National Agency for Petroleum, Gas and Biofuels (ANPG), elaborated on these structural changes.

Expediting the Award Process

One of the most critical elements of the new hydrocarbon strategy is the deliberate acceleration of administrative procedures. Investors have frequently highlighted bureaucratic delays as a hurdle to operational efficiency across the continent. Addressing this directly, Andrade stated that the ANPG is actively looking to reduce the time taken to award exploration concessions.

The regulator is now aiming for a highly streamlined three-month award process. This represents a 50 percent reduction in administrative time compared to the current six-month timeframe. By halving the waiting period, Angola hopes to provide energy companies with the agility required to deploy capital and commence operations much faster, thereby improving the overall commercial viability of the proposed projects.

A Tailored, Risk-Profile-Based Model

Recognising that different geological assets present unique technical and financial challenges, the government is also reforming its approach to the terms and conditions attached to exploration agreements. Andrade emphasised that the new regulatory framework will explicitly not be a “one-size-fits-all” approach.

Instead, the ANPG intends to implement a sophisticated risk-profile-based model. This nuanced strategy will carefully distinguish between varying types of assets to ensure that the fiscal and operational terms reflect the specific realities of each project. Key distinctions within this new model will include differentiating between marginal fields and mature fields, as well as offering bespoke terms for onshore developments versus deep-water blocks.

Long-Term Production Objectives

Ultimately, the overarching goal of these sweeping reforms is to reverse any stagnation and drive substantial growth in domestic crude output. By facilitating a faster concession process and offering tailored investment terms, the Angolan government anticipates a significant increase in drilling activity.

Drilling more exploration wells will hopefully lead to higher crude production over the long term, according to Andrade. Through the successful implementation of this 25-year plan, the nation aims to secure its vital role in the international energy supply chain for decades to come.

Regional trade desks reported on Wednesday that sellers of sweet and heavy West African grades are finding it difficult to clear their export programmes.

Industry

Physical oil markets across the Atlantic basin are contending with mounting headwinds as cargoes of both Angolan and Nigerian crude struggle to find buyers, undermined by stubbornly high shipping costs and softening differentials.

Regional trade desks reported on Wednesday that sellers of sweet and heavy West African grades are finding it difficult to clear their export programmes. The paralysis highlights growing competition in international refining centres, where delivered costs dictate refiners' feedstock purchasing strategies.

Twin pressures on West African differentials

Market participants point to an accumulation of geopolitical and operational factors that have simultaneously reduced arbitrage profitability and weakened outright bids for Atlantic basin crude.

A market trader noted that the physical market was confronting a “combination of high freight costs, recovering Middle Eastern supply, and widening discounts,” which has left several Nigerian and Angolan cargoes struggling to clear within their typical trading cycles.

When maritime tanker rates surge, distant refiners in Europe and Asia demand steeper discounts on free-on-board (FOB) prices to offset the expense of transporting the barrels. Concurrently, the gradual return of regional competition from Middle Eastern producers has offered refiners closer, more economic options, compressing the natural premium historically held by Atlantic grades.

Angolan grades suffer steep discounts

The downward trajectory is particularly pronounced in heavy, sweet grades from Angola, which have experienced severe pricing declines over the course of a single trading week.

Offers for Angolan Dalia crude were heard at a discount of $20 to dated Brent on the Argus Open Market this week, according to another trader. This assessment represents a substantial deterioration compared to the discount of $9.95 to dated Brent recorded for the grade last week on the Platts platform.

Key observations shaping current West African trading include:

  • Elevated vessel charter rates pricing long-haul barrels out of key export destinations.

  • Recovering crude flows from Middle Eastern producers reducing reliance on Atlantic basin imports.

  • Persistent overhang of unsold volumes across the prompt loading programmes.

  • Angolan differentials going lower, which is directly weighing on the pricing of competing Nigerian grades.

Because Angolan and Nigerian streams often compete for similar processing units across Mediterranean and Northwest European refineries, the widening price discount on Angolan heavy barrels has exerted immediate downward pressure on lighter Nigerian export grades. Sellers of Nigerian crudes are being forced to adjust their physical differentials downward to remain viable against their regional neighbours.

Chevron’s Aseng gas milestone

Beyond the prompt crude market, the wider Gulf of Guinea upstream sector is monitoring significant long-term infrastructure progress in neighbouring waters.

US oil major Chevron has confirmed it remains on track to deliver first gas from its offshore Aseng gas project in Equatorial Guinea in 2028, a senior company executive said. The development represents a notable step forward in monetising offshore gas reserves across regional production hubs, even as short-term crude physical traders manage the volatility of global shipping bottlenecks and shifting refinery margins.

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Exploration

Nigeria’s Dangote Petroleum Refinery has just announced a staggering US$4.73bn net profit for the first nine months of 2026.

Industry

The global petroleum refining landscape is undergoing a monumental shift, driven by geopolitical volatility and the emergence of massive new downstream infrastructure in developing markets.

At the centre of this transformation is Nigeria’s Dangote Petroleum Refinery, which has just announced a staggering US$4.73bn net profit for the first nine months of 2026. This dramatic financial turnaround arrives precisely as the organisation asks investors for US$1.6bn in what is slated to be the largest initial public offering (IPO) in African history.

Global Supply Disruptions and the Refining Catalyst

Historically, West Africa has relied heavily on imported refined fuels from Europe, the United States, and the Middle East to meet its domestic energy requirements. However, recent geopolitical tensions, most notably the Iran war, have severely disrupted Middle Eastern refining operations and petroleum product exports.

These supply chain bottlenecks have sent global product margins sharply higher throughout the year, with a particularly intense spike in the profitability of diesel and jet fuel. Rather than falling victim to these shortages, newly commissioned infrastructure in West Africa has capitalised on the supply vacuum. By ramping up output, facilities in the region have begun exporting refined products directly into these global shortages, including significant jet fuel shipments successfully routed to Western Europe.

A Historic Financial Turnaround

Just a year ago, the Lagos-based mega-refinery was still absorbing heavy commissioning costs, posting a US$117.2mn loss during the same nine-month period. Today, the operational reality paints a drastically different picture. By successfully processing greater volumes of crude oil and capturing elevated refining margins on the global market, the company has transformed its balance sheet at an unprecedented pace.

The facility's fiscal transformation is underscored by several key performance metrics:

  • Revenue Growth: Total revenue more than doubled year-on-year, surging from US$9.19bn to an impressive US$22.48bn.

  • EBITDA Expansion: Earnings before interest, taxes, depreciation, and amortisation skyrocketed to US$5.52bn, up from just US$627.6mn a year earlier.

  • Cash Flow Generation: Operating cash flow reached US$3.68bn through September, compared with a mere US$364.7mn previously.

  • Debt Reduction: The organisation finished the period with US$650.8mn in net cash, completely reversing the US$1.73bn in net debt it carried the previous year.

  • Liquidity: Total cash holdings for the enterprise have now reached a robust US$6.69bn.

Africa’s Largest Initial Public Offering

These exceptional financial figures have landed right in the middle of the refinery’s highly anticipated IPO. The company is actively seeking to raise US$1.6bn in a public offering that places an overall valuation on the refinery of approximately US$47bn.

The market response has been exceptionally strong. Initially scheduled to close on the 13th of October, the subscription period has been officially extended through the 27th of October. This two-week extension was necessitated after heavy and enthusiastic investor demand effectively overwhelmed several Nigerian investment platforms when the offering first opened to the public.

Securing Regional Independence and Future Expansion

The capital generated from the IPO is already earmarked partly for the facility's next ambitious expansion phase. While the 700,000-barrel-per-day (bpd) refinery was already running near 660,000 bpd earlier this year—up from its original 650,000 bpd design—leadership has set a far higher target. By 2029, the company intends to double its total refining capacity to 1.4 million bpd. Once completed, this expansion would firmly position the Lagos complex among the very largest single-train refineries in the world.

Beyond the raw financial success, the strategic impact on the regional economy cannot be overstated. The facility has successfully and substantially cut West Africa’s historical dependence on imported fuel. Today, Nigerian product exports are increasingly displacing the millions of barrels that previously arrived via long-haul shipping routes. From navigating early commissioning hurdles to boasting billions in cash reserves and a line of eager investors, the enterprise has rapidly rewritten the narrative of African downstream energy production.

Khaled Salah, vice president - Africa, AVEVA. (Image source: AVEVA)

Geology & Geophysics

The survey will span across 34,000 kms offshore Egypt. (Image source: TGS)

Geology & Geophysics

Energy data and intelligence provider, TGS, has partnered with Egyptian Natural Gas Holding Company (EGAS), to initiate a large-scale 2D seismic reimaging campaign, the EGY-2DRE2026 project 

The survey will span across 34,000 kms offshore Egypt, which will be further integrated to the GeoStreamer 2016, 2018 and 2023 surveys. The compilation will comprise other available conventional 2D data as well, building single and consistent regional framework for interested operators to refer to across the offshore basins. The vast and insightful dataset will be fed into an advanced velocity model building and pre-stack depth migration workflow, including TGS' proprietary DM-eFWI technology, to generate credible images of pre-, intra- and post-Messinian salt intervals in high definition. 

The reimaged dataset that spans offshore Nile Delta, Herodotus Basin, and wider Eastern Mediterranean Basin will support clients to better resolve these intervals, giving a sharper, basin-wide structural framework to support prospect identification and maturation. This will play a significant role in decision making for operators to channelise exploration budgets in the right direction ahead of upcoming licensing rounds.

To support resource development, TGS has lately been taking up region-specific projects in Africa that aligns with a rising global demand for basin-wide reimaging and data integration across frontier and mature basins globally.

Final products for a priority subset of 2D lines are scheduled for delivery in Q2 2027, with the remaining full project scheduled for completion in Q1 2028.

"EGY-2DRE2026 will give our customers a modern, regionally consistent view of a basin that has historically been difficult to image beneath its complex Messinian section," said David Hajovsky, Executive Vice President, Multi-Client at TGS. "By combining our latest imaging technology with the depth and breadth of our existing coverage, we're able to de-risk exploration decisions and support our customers as they evaluate future opportunities in this highly prospective part of the Egyptian offshore."

The project is supported by industry funding.

Offshore Sao Tome and Príncipe is a challenging subsurface environment. (Image source: TGS)

Technology

The new standard represents an important step towards optical modem interoperability for subsea systems. (Image source: SWiG)

Technology

Oil and gas industry network Subsea Wireless Group (SWiG) has released a new industry specification for free-space optical communications, providing a common protocol for modems from different manufacturers

SWiGoptical Level 1 defines a simple protocol to satisfy interoperability and interchangeability requirements for subsea free-space optical communication devices. It supports applications including, but not limited to, process control, equipment and process monitoring, diagnostics and maintenance, and data exchange and harvesting across autonomous underwater vehicles (AUVs) and other connected subsea systems.

Systems working together

SWiG, a joint industry project (JIP) managed by OTM Networks (part of R&D consultancy Sagentia Innovation), was established to enable vehicles, infrastructure and equipment from different suppliers to work together seamlessly. It has 27 members representing all parts of the supply chain, from major energy operators to subsea service providers and integrators to specialist instrumentation companies. Its objectives include:

• Promote interoperability between users of subsea wireless communications.
• Raise industry awareness and acceptance of subsea wireless communications.
• Identify areas (within subsea wireless communications) where open standards are needed, and develop them.
• Encourage the integration of subsea wireless communication technologies.
• Share best practices across the industry.
• Promote knowledge transfer across the industry.

Shreekant Mehta, senior vice president, Energy Sector at Sagentia Innovation, said SWiGoptical Level 1 represents an important step towards optical modem interoperability for subsea systems.

“SWiG’s goal is to create a common subsea ecosystem where devices from different manufacturers interact seamlessly,” Mehta explained. “As subsea communication technologies continue to mature, a collaborative approach to developing open standards supports cost management and provides a common framework, reducing deployment risk, simplifying integration and supporting scalability. Achieving interoperability across subsea operations is essential if the industry is to realise the full benefits of autonomy.”

The new specification builds on the earlier SWiGacoustic standard and is the latest in a family of complementary SWiG standards that also cover radio frequency (RF), inductive data and power and hybrid communications. SWiGoptical Level 1 is now available to the wider industry, with Level 2 and Level 3 specifications for higher-performance protocols already under development.

SLB to deploy subsea production system for Rovuma development.

Gas

First gas from NT-1 and NT-2 is targeted for December.

Gas

The giant Ntorya gas field development in Tanzania is anticipated to deliver vital domestic energy supplies, alleviate local energy poverty, and drive long-term industrial and economic growth for the country

Tanzanian government authorities have recognised the urgency of the project's advancement and to make sure there is no delay, an optimised timetable has been established in consultation with the joint venture partners involved in the field's development. Designed with an aim to achieve first gas production by December, the packed schedule includes critical well workovers, testing, and accelerated drilling. Fully funded field operations and pipeline infrastructure integration will prepare the site for production generation.

Aminex has reached an agreement on the sequencing and implementation of the Ntorya gas development following a meeting convened by the Tanzanian Ministry of Energy

Key stakeholders convene

Representatives of the Ministry of Energy, the Petroleum Upstream Regulatory Authority (PURA), the Tanzania Petroleum Development Corporation (TPDC), ARA Petroleum Tanzania Limited (APT), the operator of the Ruvuma PSA, and Aminex's wholly owned subsidiary, Ndovu Resources Limited (Ndovu) were present at the meeting.

While the government did not approve the operator's proposal to extend and delay the project timetable, it did confirm a revised implementation schedule with all the parties involved. This schedule comprises workover of the Ntorya-1 well (NT-1) in October, the testing of the Ntorya-2 well (NT-2) in November and the drilling of a newly planned NT-Central well (NT-C) in December.

First gas from NT-1 and NT-2 is targeted for December. Drilling of the Chikumbi-1 well (CH-1) is to proceed after NT-C is drilled. Following the change of management at ARA Petroleum LLC and a technical reappraisal of the Ntorya project, APT had proposed bringing forward NT-C, previously planned as a development well for a later phase of field development, in place of CH-1, with the drilling of CH-1 deferred. The revised implementation schedule plans to drill the NT-C first, followed by the drilling of CH-1.

It was also confirmed at the meeting that the Ntorya to Madimba pipeline will be completed in time to receive first gas from the Ntorya field in December 2026.

APT confirmed to the parties that it had all necessary funds to carry out the revised programme for the development of the Ntorya field.

The parties agreed that APT should execute the planned activities in accordance with the revised implementation schedule and without unnecessary delay. The revised programme will now be progressed through the formal Joint Venture approval process in accordance with the Joint Operating Agreement.

Economic impact of the project

Charles Santos, executive chairman of Aminex, said, "I would like to thank Dr James Mataragio, Permanent Secretary for Petroleum at the Ministry of Energy, for convening the meeting last week and for the constructive approach taken by all parties. Our focus now is on working together to implement the agreed programme and deliver first gas without further delay.

"The revised implementation programme establishes clear near-term operational milestones, targets first gas for December 2026 and provides for the drilling of a newly planned well, NT-Central, while ensuring that the CH-1 well is also drilled.

"Together, these activities form just the beginning of the development of the giant Ntorya field which is expected to deliver large volumes of gas supplies to Tanzanians, helping alleviate energy poverty, boost industrial development and fuel Tanzania's economic growth."

Puma Energy Ghana boosts LPG distribution through local partnerships.

The coming months will see a significant increase in operational activity at Ntorya.

Downstream

The consistent market launches come from optimised production.

Downstream

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.

Event News

The event will convene the global energy industry in Abu Dhabi. (Image source: dmg events)

Event News

Held under the patronage of His Highness Sheikh Mohamed bin Zayed Al Nahyan, President of the UAE, in his capacity as Ruler of Abu Dhabi, ADIPEC 2026 will take place in Abu Dhabi from 2 to 5 November 2026 at ADNEC Centre Abu Dhabi

The event will mobilise investment in resilient and intelligent energy systems, with confirmed participation from ministers, CEOs and senior leaders across energy, technology, finance and industry.

The event will convene the global energy industry in Abu Dhabi as the world enters a new era of rising energy demand, geopolitical volatility, infrastructure constraints and the rapid expansion of artificial intelligence (AI), underscoring the critical importance of energy security to economic stability and growth.

As the world's largest energy conference and exhibition, and drawing on the UAE's position as a reliable energy supplier, long-term investment partner and global hub for technology and industry, ADIPEC 2026 will bring together policymakers, producers, investors, technology leaders and customers to turn shared priorities into practical action.

Across its conferences and exhibition, participants will align priorities, advance commercial partnerships and accelerate the projects and solutions needed to support secure, reliable and affordable energy supplies and long-term growth.

Among the early confirmed speakers for ADIPEC 2026 are: His Excellency Suhail Mohamed Al Mazrouei, Minister of Energy and Infrastructure, UAE; His Excellency Eng. Karim Badawi, Minister of Petroleum and Mineral Resources, Arab Republic of Egypt; His Excellency Saleh Kharabsheh, Minister of Energy and Mineral Resources, Hashemite Kingdom of Jordan; Rt. Hon Ekperikpe Ekpo, Minister for State for Petroleum Resources (Gas), Nigeria; Wael Sawan, CEO, Shell; Patrick Pouyanne, Chairman & CEO, TotalEnergies; Meg O'Neill, CEO, bp; Richard Jackson, President and CEO, Oxy; Claudio Descalzi, CEO, ENI; Christian Bruch, President and CEO, Siemens Energy; Wang Yuetao, Chairman, Zhenhua Oil; Olivier Le Peuch, CEO, SLB; Lorenzo Simonelli, Chairman and CEO, Baker Hughes; Horacio Marín, Chairman of the Board and CEO, YPF; Dr Angela Wilkinson, Secretary General and CEO, World Energy Council; Aliko Dangote, President & CEO, Dangote Group; Hunter Hunt, Chairman and CEO, Hunt Energy Holdings; Stuart Bradie, Chair of the Board, President and CEO, KBR; Dr Olivier Oullier, CEO and Co-founder, Inclusive Brains; and Prof. Haruhiko Ando, CEO, Japan Cooperation Center for Petroleum and Sustainable Energy.

Abdulmunim Al Kindy, Chairman of ADIPEC 2026, said, “Recent volatility has reaffirmed a simple truth: energy security is economic stability. As demand rises and AI transforms both the energy sector and the economies it powers, the world must invest ahead of demand, diversify supply and strengthen the infrastructure, technology and capabilities that keep energy moving.

“ADIPEC 2026 will focus on what the next energy system needs most: growth, reliability, intelligence and delivery. By bringing together policy, capital, technology and industry in Abu Dhabi, we will help advance the investments, projects and partnerships required to provide more energy, more securely and affordably, while supporting global economic growth.”

New for 2026, ADIPEC's Strategic Conference has been redesigned around the forces reshaping global energy, from rising demand and energy security to infrastructure, investment, AI, industrial execution and workforce capability.

Across 11 programmes and more than 380 sessions, ministers, CEOs, investors, policymakers and technology leaders will examine the decisions, partnerships and capital needed to expand energy supply, accelerate infrastructure delivery and strengthen long-term system performance.

New Strategic Conference programmes 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 updated to reflect the priorities shaping energy's next phase, including AI, Digital & Technology Innovation and Downstream, Chemicals & Industrial Value Chains.

The 11 Strategic Conference programmes are complemented by the Technical Conference, with its SPE Technical and Downstream Technical programmes, which together represent the world's largest gathering of technical energy engineers and experts to transform strategy into operational delivery.

Christopher Hudson, President, dmg events (organisers of ADIPEC), said, “As the global energy landscape continues to evolve, ADIPEC's role as a platform for dialogue, collaboration and commercial engagement has never been more important. Rising energy demand, supply constraints and rapid technological advancement underscore the need to bring industry leaders together to align priorities, mobilise investment and accelerate the projects and technologies required to support long-term energy security and economic growth.

“The strong early momentum behind ADIPEC 2026 reflects the industry's recognition of both the scale of the opportunity and the urgency for action. By convening policymakers, investors, technology leaders and energy producers in Abu Dhabi, ADIPEC will help strengthen partnerships, advance innovation and support the delivery of the secure, reliable and affordable energy systems the world needs.”

The ADIPEC Exhibition will serve as a global marketplace where connections translate into commercial outcomes. In 2025, the event generated US$53 billion in value through more than 49,000 deals, demonstrating its role in advancing investment, partnerships and project delivery.

With more than 2,250 companies already confirmed to participate – including 54 NOCs, IOCs, NECs and IECs – across 16 halls and 30 country pavilions, ADIPEC 2026 is set to be one of the most influential gatherings in the global energy industry, bringing together the technologies, collaboration and investment opportunities shaping the future of energy. Four specialised zones will connect market-ready technologies and solutions with customers, investors and partners, helping move projects from opportunity to execution.

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