Norwegian energy giant Equinor has entered into a five-year natural gas supply agreement with Dutch energy company Eneco, expanding its long-term commercial arrangements in the European gas market. Under the contract, Equinor will deliver approximately 9 terawatt-hours (TWh) of natural gas annually, equivalent to around 0.9 billion cubic meters (bcm), from the Norwegian continental shelf to the Dutch gas grid. Deliveries under the agreement commenced on 1st October 2026.

The latest deal follows two earlier agreements involving the Netherlands and Eneco’s operations. In February 2026, Equinor signed a five-year contract to supply up to 0.5 bcm of natural gas annually to the Netherlands. In May 2026, the company also reached an agreement covering approximately 2.2 TWh of annual gas deliveries to Eneco’s German subsidiary, LichtBlick.

Corporate Perspectives on the Agreement

Government Support and Economic Impact

Project Specifications and Future Timeline

The free-on-board arrangement generally places responsibility for ocean transportation with the buyer once the LNG has been loaded, providing Petrobras with flexibility regarding the destination of the cargoes. The agreement adds another long-duration commitment to Cheniere’s LNG business and provides a defined supply arrangement extending into the second half of this century.

“We are pleased to enter into this multi-decade agreement with Petrobras, one of the largest energy companies in the world,” said Jack Fusco, Cheniere’s chairman, president and CEO.

Fusco said the agreement provides additional commercial support and fixed-fee cash flow visibility as Cheniere considers further brownfield liquefaction growth.

“We look forward to providing our secure and reliable LNG to Petrobras into the second half of this century under this new long-term agreement,” he added.

The LNG supply agreement therefore gives Cheniere another established commercial commitment while the company continues to assess additional liquefaction opportunities across its Gulf Coast facilities.

Cheniere Continues Gulf Coast LNG Expansion

The Petrobras agreement comes as Cheniere continues to expand one of the world’s largest LNG export platforms. The Houston-based company operates the Sabine Pass LNG terminal in Louisiana and Corpus Christi LNG facility in Texas, together representing approximately 56 million tonnes per annum of combined production capacity.

Cheniere says another roughly 5 mtpa of capacity is under construction, including estimated debottlenecking opportunities. The Petrobras agreement follows the recent completion of Cheniere’s major Stage 3 expansion at Corpus Christi. The company also marked its 5,000th LNG cargo the following day, when the LNG carrier Yari departed Sabine Pass bound for Asia. Cheniere reached that milestone just over a decade after shipping its first LNG cargo from Sabine Pass in 2016.

Petrobras Contract Adds Long-Duration Commitment

Cheniere has said it is continuing to pursue additional liquefaction expansion opportunities at its Gulf Coast facilities. Against that backdrop, the LNG supply agreement with Petrobras adds another long-duration commitment as the company weighs its next phase of growth. The agreement covers approximately 800,000 tonnes of LNG per year and further connects Cheniere’s existing export operations with Petrobras through a multi-decade supply arrangement. With the agreement in place, Cheniere continues to build on its long-term commercial commitments while considering additional growth at its Gulf Coast facilities.

Production Expansion Planned for 2029

The Absheron Full Field development is expected to substantially increase production from the field, taking overall output to 6 BCMA of gas and 47,000 barrels per day of condensate. Project is expected to start-up in 2029. Gas produced through the development will be supplied to the domestic market as well as exported to Turkey. The exports will use the existing gas infrastructure connecting Azerbaijan to the European gas market, supporting the role of the development in strengthening regional energy security.

Low-Carbon Design and Subsea Production

The project has been designed with a focus on innovation and a low carbon footprint. Gas will be produced by 4 subsea wells before being transported to shore through a subsea pipeline equipped with advanced automation solutions. It will then be processed at a new onshore plant that will be fully electrified and designed to minimize energy consumption and greenhouse gas emissions. As a result of the design, the scope 1 & 2 greenhouse gas emissions intensity of the project stands below 4 kg CO2e/boe.

“We are pleased to announce the launch of Absheron Full Field development, a project that unlocks the full production potential of one of the Caspian Sea’s largest gas discoveries”, said Patrick Pouyanné, Chairman and CEO of TotalEnergies.

“In line with TotalEnergies’ strategy, Absheron Full Field Development is a low cost and low emissions project that will provide a long-term additional gas supply to the domestic and international markets, supporting regional energy security,” he added.

“We are pleased to strengthen our relationship with GIP through this infrastructure agreement which crystallizes the value of some of our midstream infrastructure assets in Africa,” said Jean-Pierre Sbraire, chief financial officer of TotalEnergies.

TotalEnergies Expands African Oil and Gas Activity

The partnership comes as TotalEnergies has recently increased its business activities across Africa’s oil and gas sector. The French supermajor has investments in Angola, Namibia, and Uganda, where it has continued to develop and expand its presence.

In early September 2026, TotalEnergies said it had made a new discovery offshore Angola and acquired operated interest in two new exploration blocks located close to operating hubs. International majors are returning to exploration in Angola’s waters to take advantage of existing infrastructure. The Acacia-5 discovery in Block 17 is expected to achieve first oil just three months after the discovery was made in June 2026, TotalEnergies said. The company has also increased its exploration portfolio offshore Namibia by taking acreage north of a block where a major oil discovery has been made, as it seeks to increase activity in the new global exploration hotspot.

In 2025, TotalEnergies signed an agreement with Galp that formalizes its operatorship over Namibia’s two largest offshore oil discoveries, Mopane and Venus, through a strategic asset swap that consolidates development control in the hands of the French major.

African Projects Strengthen Infrastructure Portfolio

TotalEnergies’ activities in Uganda also form part of its wider African oil and gas operations. In the country, TotalEnergies and China’s CNOOC have been developing the Tilenga and Kingfisher oil fields. These projects are expected to make the landlocked African country the world’s newest crude oil exporter in early 2027 through the $5 billion East African Crude Oil Pipeline (EACOP). The pipeline will transport crude from Uganda to Tanzania’s port of Tanga.

In latest development, TotalEenergies also signed a three-month bulk fuel supply deal with Namibia.

The program will combine artificial intelligence with TotalEnergies’ extensive geoscience expertise and subsurface data to improve how complex information is analyzed and interpreted. In particular, the partnership will use the latest advances in artificial intelligence, including agentic AI, to work with next to 10 petaflops of data alongside nearly a century of knowledge, know-how and expertise accumulated by TotalEnergies in geosciences and reservoir engineering. The companies aim to create frontier models capable of integrating, processing and interpreting large volumes of information and generating multiple scenarios for developing exploration opportunities. The models are also intended to help optimize and extend the life of existing projects.

Joint Laboratory to Develop Tailored AI Solutions

As part of the initiative, TotalEnergies and Mistral will establish a joint scientific laboratory. The facility will bring together the subsurface know-how and expertise of TotalEnergies’ subsurface teams with the scientific and technological capabilities of Mistral, a European AI champion. The collaboration is designed to develop solutions tailored to the specific needs of the Company’s businesses, while strengthening the use of AI across activities involving reservoir exploration and reservoir engineering. By combining its subsurface expertise and data with Mistral’s AI capabilities, TotalEnergies intends to develop tools that can support experts when dealing with complex datasets and evaluating different development scenarios.

Strengthening a European AI and Digital Ecosystem

The partnership with Mistral will also strengthen TotalEnergies’ AI solutions ecosystem through the development of proprietary models within a European digital ecosystem. The arrangement will allow TotalEnergies to leverage its strategic subsurface data while supporting Mistral’s further development as a European AI champion.

“Exploration and reservoir engineering are among the areas where artificial intelligence can create the greatest value for our activities. By combining a century of geoscience data, the expertise of our teams and Mistral’s capabilities, we aim to develop a new generation of tools capable of supporting our experts in analyzing the most complex data and in their decision-making. This partnership also illustrates our commitment to contributing to the development of a high-performing European digital ecosystem, supporting our competitiveness” said Patrick Pouyanné, Chairman and Chief Executive Officer of TotalEnergies.

“We are delighted to take our collaboration with TotalEnergies to the next level. This project demonstrates the ability of our models to support complex industrial processes and adapt to the most demanding scientific and energy challenges. It also highlights the strength of Europe’s industrial ecosystem and the importance for large enterprises of adopting state-of-the-art, customizable AI solutions that protect and respect their intellectual property,” said Arthur Mensch, Co-founder and CEO of Mistral.

Core Areas of Collaboration

The partnership focuses on four distinct operational areas. These include ensuring energy supply security, facilitating market growth and development, strengthening the resilience of the supply chain, and optimizing shipping and portfolio management. By aligning the UAE-based supply capabilities of ADNOC with international sources from XRG, the agreement leverages the established market presence, trading expertise, and infrastructure access held by SEFE.

Infrastructure and Market Development

The scope of this European gas market cooperation includes the potential for joint investment and the development of energy infrastructure. Furthermore, the companies intend to implement measures aimed at optimizing gas and LNG portfolios and managing cargo movements.

Enhancing Energy Security and Market Resilience

“XRG and ADNOC are committed to Germany for the long term. We have already invested €19 billion, and this week the UAE more widely announced the long-term intention to invest a further €40 billion in the country. This agreement with SEFE combines our capabilities and opens new opportunities across the gas and LNG value chain, strengthening energy security and supporting the competitiveness and growth of German industry,” said Sultan Ahmed Al Jaber, ADNOC Managing Director and Group CEO and Executive Chairman of XRG.

“We are thrilled to deepen our collaboration with such trusted partners as ADNOC and XRG. In today’s energy landscape, closer cooperation across the value chain is critical. By bringing together ADNOC and XRG’s global supply capabilities with SEFE’s market presence, trading expertise, customer relationships and infrastructure access, we aim to enhance the resilience of Germany’s and Europe’s energy systems,” added SEFE CEO Egbert Laege.

The European gas market agreement further broadens XRG’s existing investment presence in Germany, which includes Covestro, to encompass the gas and LNG value chains.

The new block 17 discovery will be integrated into existing production infrastructure through a tieback arrangement to the Pazflor floating production, storage and offloading vessel. This connection is expected to deliver an additional 6,000 barrels per day of production capacity, leveraging already-established facilities to optimize development efficiency and reduce capital requirements.

Operational Partnership and Stakeholder Structure

France-based TotalEnergies maintains operational control of Block 17 with a 38 percent working interest. The project encompasses a diverse international consortium, reflecting the collaborative nature of modern offshore oil and gas development. Norway’s Equinor ASA holds a 22.16 percent stake, while the United States-based Exxon Mobil Corporation retains 19 percent. The Azule Energy joint venture, equally owned by Britain’s BP and Italy’s state-backed Eni, maintains a 15.84 percent position. Angola’s national petroleum company, Sociedade Nacional de Combustíveis de Angola EP (Sonangol), owns a five percent stake in Block 17.

Recent Exploration Momentum Across Angola Portfolio

“Acacia-5 is the second exploration success recorded in 2026 across TotalEnergies’ Angolan portfolio, following the recent Block 0 discovery in the prolific Lower Congo Basin, where TotalEnergies holds a 10 percent interest alongside Chevron, operator”, TotalEnergies stated in a press release, commenting on the new block 17 discovery.

The Block 0 discovery demonstrated a hydrocarbon column exceeding 600 meters within the primary Pinda reservoir, with net pay exceeding 90 meters and exceptional reservoir characteristics, according to Chevron’s announcements.

Development discussions for the Block 0 discovery are exploring a tieback arrangement to Chevron’s existing infrastructure for the 105-4X find. Production from Block 0 has already commenced through the Mafumeira developments.

Expansion of Exploration Acreage

Concurrent with the new block 17 discovery announcement, TotalEnergies finalized concession agreements with Angola’s National Agency for Petroleum, Gas and Biofuels (ANPG).

“These promising blocks benefit from extensive existing 3D seismic coverage and offer access to several prospective geological plays”, TotalEnergies said.

“They are located close to existing facilities in TotalEnergies-operated Blocks 17 and 32, where six FPSOs are currently producing, therefore allowing for future tie-backs and cost-efficient development of additional resources through existing facilities,” it added.

Additionally, TotalEnergies entered a preliminary agreement with ANPG and ExxonMobil targeting exploration blocks 40, 41, 42, and 58 in the Benguela Basin. Under the arrangement, TotalEnergies would assume a 35 percent working interest in these prospective acreage positions.

Strategic Vision and Market Positioning

“Exploration is a key pillar of our ambition in Angola, supported by the incentives introduced to encourage investment”, said TotalEnergies chair and chief executive Patrick Pouyanné.

“Together with our partners, we aim to explore further and unlock new resources, sustaining a strong exploration effort to identify new opportunities across Angola’s offshore basins,” he added.

Key Assets in the Asset Acquisition Transaction

The transaction regarding the Tallgrass Energy assets encompasses several major infrastructure components that enhance Enbridge’s acquisition capabilities. The company will acquire a 75% interest in the Pony Express Pipeline, spanning 1,050 miles with transportation capacity of approximately 460,000 barrels per day. This critical corridor connects Rockies crude production directly with Cushing, Oklahoma, and provides access to roughly 500,000 barrels per day of nearby refining capacity.

Strategic Connectivity and Production Basin Access

Financial Structure and Valuation

Enbridge values the $2.55 billion purchase price at an estimated forward enterprise value-to-EBITDA multiple ranging from 10 to 11 times. The acquisition also includes the PXP2 expansion project, representing approximately $300 million in planned investment designed to increase Pony Express capacity to roughly 515,000 barrels per day.

The PXP2 project benefits from take-or-pay contracts and is scheduled to commence operations in late 2027. Upon transaction closure, Enbridge intends to incorporate PXP2 into its secured growth backlog, which currently stands at $41 billion.

Broader Strategic Implications

Geological Findings and Technical Details

The Vicango East-01 well encountered approximately 25 metres of high-quality, hydrocarbon-bearing sandstone with a porosity measurement of 22%. This Angola offshore discovery was drilled in 940 metres of water depth using the Valaris DS-9 drillship, positioned roughly 370 kilometres northwest of Luanda. The geological characteristics indicate substantial commercial potential for the region’s continued energy development.

This latest Angola offshore discovery marks the 20th confirmed find within Block 15 across a 30-year exploration and production timeline. Over this extended period, the block has yielded more than 2.7 billion barrels of hydrocarbons, establishing its significance within Angola’s energy infrastructure.

Long-Term Production and Development Impact

“After more than 23 years of successful production from Block 15, this discovery demonstrates the continued potential of Angola’s offshore resources and reflects our ongoing commitment to exploration and development in the country. Block 15 has been one of Angola’s most significant deepwater developments, and discoveries like this help increase the value of existing infrastructure while supporting future production opportunities,” said Brian Unietis, President and General Manager of ExxonMobil Angola.

Regulatory Framework and Investor Incentives

ANPG Chairman Paulino Jerónimo attributed the continued success of exploration efforts to recent adjustments in Angola’s legal and fiscal environment. The Angola offshore discovery was facilitated partly through policy reforms designed to encourage ongoing investment and resource development.

“This discovery is partly the result of adjustments to the legal framework and the incentives that the Angolan State has provided to investors. The extension of the Block 15 licence until 2032, Decree 8/24 on Incremental Production, as well as Decree 5/18 on the legal regime allowing exploration within and in proximity to development areas, are examples of this,” added Jerónimo.

Operational Partnership Structure

ExxonMobil affiliate Esso Exploration Angola (Block 15) Limited serves as the operator with a 36% interest. Azule Angola Limited maintains 24% ownership, Azule Angola BV holds 18%, Equinor Angola Block 15 A.S. carries 12%, and Sonangol E&P manages 10%. ANPG functions as the concessionaire.