This renewed emphasis on the Italy Libya energy cooperation comes at a crucial time for Italy, which is heavily reliant on imported energy and is particularly sensitive to fluctuations in global fuel prices. The current geopolitical climate has amplified the need for securing stable and diverse energy supplies, making Libya a key strategic partner.

Libya currently stands as Rome’s primary supplier of crude oil, a significant contributor to Italy’s overall import volume. However, recent data indicates a decrease in Libya’s gas exports to Italy, falling to approximately 1 billion cubic metres in the past year from 1.4 billion cubic metres previously. This reduction is attributed to various supply-side challenges within Libya, including rising domestic consumption, recurring disruptions to critical infrastructure, and persistent political instability, which have impacted the operational capacity of the Greenstream pipeline.

To address these challenges and bolster energy exports, discussions have also involved the necessity of increased investment in Libya’s energy infrastructure. Such investments are seen as vital for significantly boosting Libyan gas production and, consequently, its export volumes to Italy. Italian energy major Eni, a long-standing operator in Libya since 1959, plays a crucial role in the country’s energy landscape. The company continues its operations, with a substantial equity production and several development projects underway, some of which are slated to commence operations in the near future, further solidifying the Italy-Libya energy cooperation.

The ongoing dialogue between Italy and Libya underscores the strategic importance of their bilateral cooperation in navigating the complexities of the global energy market and ensuring reliable energy supplies for Italy. The focus on the energy sector reflects a broader objective to foster robust economic ties and secure critical resources.

This strategic collaboration, valued at approximately $10 billion in capital investment, is poised to enable the Ruwais chemical production of 14 new industrial chemicals. Upon final investment decisions and regulatory approvals, this initiative could lead to an additional chemical capacity of about 2.2 million tonnes per year within the TA’ZIZ industrial chemicals ecosystem. The expansion aligns with the UAE’s broader industrial strategy and the ‘Make it in the Emirates’ (MIITE) initiative, aiming to enhance domestic manufacturing and achieve greater self-sufficiency in vital chemical products.

The intended new production lines are designed for close integration within the TA’ZIZ and broader ADNOC ecosystems, leveraging synergies in feedstock sourcing, utilities, infrastructure, and facility integration. These industrial chemicals serve a wide array of sectors, including construction, automotive, packaging, consumer goods, infrastructure, and advanced manufacturing. The objective is to enhance the overall competitiveness and capital efficiency of the TA’ZIZ platform by strengthening local supply chain resilience and substituting key imported products.

The new chemicals to be produced will include styrene, polystyrenes, acrylic acid and its derivatives, polyols, methylene diphenyl diisocyanate (MDI), epoxy resins, and linear alpha-olefins. These additions will build upon TA’ZIZ’s Phase 1 plans, which already project a chemical production capacity of 4.7 million tonnes per year of marketable products, with a scheduled startup by the end of 2028.

The partnership’s joint-feasibility and market study for the proposed chemical expansion are a direct support to the UAE’s vision for industrial growth. Hamad Al Ameri, Alpha Dhabi Holding’s managing director and chief executive officer, highlighted that this expansion not only strengthens domestic manufacturing but also has the potential to unlock significant export opportunities. This agreement follows closely on the heels of TA’ZIZ securing substantial commercial agreements totaling $28.5 billion across its chemicals portfolio, ensuring long-term offtake, feedstock supply, and product sales to support the ongoing development of its Ruwais industrial platform. The Ruwais chemical production expansion underscores a commitment to advancing local manufacturing capabilities.

Prime Minister Madbouly highlighted that this gas infrastructure agreement is a direct outcome of his visit to Beirut in December, emphasizing Egypt’s dedication to assisting Lebanon in overcoming its energy-related hurdles and securing dependable energy provisions. The discussions also encompassed expanding bilateral cooperation within the broader energy sector. Minister Badawi characterized the gas infrastructure revival deal as a crucial stride in fortifying collaboration in the oil and natural gas domains, contributing positively to regional energy security.

This development follows closely on the heels of another regional energy initiative. Just days prior, Jordan, Syria, and Lebanon announced a collaborative plan to revitalize the Arab Gas Pipeline. This established energy artery connects Egyptian gas supplies to the Levant. Under this trilateral arrangement, Jordan is set to leverage its infrastructure to import liquefied natural gas, process it into natural gas, and then transmit it to Syria and Lebanon via the pipeline.

The Arab Gas Pipeline, a substantial undertaking stretching over 1,200 kilometers, was originally conceived to channel Egyptian natural gas to countries across the Levant, with aspirations for further distribution to Europe. The pipeline’s operations experienced significant disruptions post-2011, influenced by the prevailing circumstances in Syria and international sanctions. The lifting of these restrictions paved the way for renewed regional energy infrastructure projects. The deal to revitalize Lebanon’s gas infrastructure is a testament to the ongoing efforts to revitalize these vital energy pathways and enhance the overall energy infrastructure in the region. This focus on energy infrastructure is paramount for the sustained growth of the energy sector.

The strategic importance of the Neptun Deep gas project extends beyond Romania’s borders, with plans to supply gas to Germany and Moldova. Several other European countries, including Slovakia, have also expressed considerable interest in securing a share of this vital resource.

This ambitious energy undertaking is a joint venture involving OMV Petrom, a company where Austria’s OMV holds a majority stake, and Romania’s state-owned entity, Romgaz. Christina Verchere, CEO of OMV Petrom, highlighted the project’s significance at a ceremony marking the official start of pipeline work. “It gives Romania a much bigger stage in the European Union, and this is what these big energy projects can do,” Verchere stated. She further emphasized, “I think it’s a reminder to us that when you have access to indigenous natural gas here in Europe, that we should develop it and make sure that we can bring it into the market.”

The operational phase of pipeline installation for the Neptun Deep gas project involves two specialized ships owned by Italy’s Saipem. These vessels are tasked with laying 160 kilometers (approximately 99 miles) of pipeline connecting offshore wells to the mainland. Concurrently, construction is in full swing for a gas metering plant on land. According to Cristian Hubati, a senior executive at OMV Petrom, the pipeline laying process is expected to take two months, with the gas metering plant slated for completion by summer. The two ships, identified as Castoro 10 and Castorone, are part of a larger fleet of 50 vessels that will operate in the Black Sea this year to support the construction of Neptun Deep.

Razvan Popescu, CEO of Romgaz, confirmed the project’s adherence to schedule. “That we have begun installing (the pipeline) shows we are on schedule to delivering this project,” Popescu commented. The company is currently focused on completing the digging of six deep water wells. Fabrication of components for the production platform is underway in both Indonesia and Italy, with these parts expected to be transported to the Black Sea later in the year.

The Black Sea region, a vital corridor for international trade, including grain and energy products, is also home to numerous offshore drilling endeavors. The maritime boundaries of the Black Sea are shared by Bulgaria, Romania, Georgia, Turkey, and Ukraine, with Russia also having a presence via Crimea.

Market Valuation and Long-Term Forecast

In terms of overall market valuation, the industry is poised for steady, reliable expansion over the coming decade. As of 2024, the market size was firmly established at an estimated USD 230.38 Billion. Stepping into the core forecast period, the market is projected to reach a valuation of USD 238.77 Billion in 2025 and is expected to continuously expand to a robust USD 341.39 Billion by the year 2035. This consistent upward trajectory represents a compound annual growth rate (CAGR) of 3.64% spanning the 2025 to 2035 timeframe. This growth curve underscores the persistent global reliance on traditional energy resources, even as the broader transition to alternative energy begins to take hold and reshape long-term strategic planning for infrastructure developers globally.

Primary Market Drivers: Energy Demand and Geopolitical Security

The continuous expansion of this market is heavily stimulated by multiple intertwined drivers, primarily the unyielding escalation in global energy demand. Driven by rapid population growth and widespread industrialization, particularly in developing economies, the fundamental need for reliable, accessible energy sources is intensifying at a rapid pace. Current macroeconomic projections suggest that total global energy consumption could rise by approximately 30% by the year 2040. To satisfy this immense appetite, drastically enhanced storage solutions are an absolute necessity. Furthermore, the inherent volatility of energy prices compels nations and facility operators to prioritize strategic storage to manage complex supply and demand imbalances effectively.

Alongside raw consumption demand, strategic geopolitical factors heavily influence future market dynamics. Tensions and instability in primary oil-producing regions consistently threaten to disrupt global supply chains, prompting nations to aggressively bolster their strategic reserves. A highly proactive approach to energy security has emerged across the globe; recent data indicates that various nations are actively enhancing their strategic petroleum reserves, with ambitious targets aiming to hold up to 90 days of net imports. This geopolitical imperative ensures a continuous flow of capital into the expansion and modernization of storage infrastructure to safeguard national economies against potential supply shocks.

Transformative Market Shifts, Trends, and Technological Integration

A major shift defining the future of the oil and gas storage market is the deep integration of technological innovation and facility digitalization. The industry is moving rapidly away from purely mechanical operations toward highly automated, intelligent frameworks. Technological advancements such as real-time monitoring, predictive analytics, and automated smart sensors are becoming standard operational requirements. These technologies allow for the exact, continuous monitoring of storage conditions, significantly reducing the environmental risks and operational costs associated with dangerous leaks and spills. Furthermore, there is a pronounced shift toward modular storage solutions, which afford operators critical flexibility and the ability to rapidly scale or deploy infrastructure as market demands fluctuate.

Simultaneously, the industry is navigating a monumental shift toward operational sustainability. Stringent regulatory frameworks and updated environmental standards are forcing a rigorous reevaluation of traditional storage methods. Governments globally are demanding minimized environmental impacts, often requiring costly structural upgrades like secondary containment systems. In response to the broader carbon-reduction movement, operators are integrating renewable energy sources directly into their storage strategies, paving the way for advanced hybrid storage models. The accelerated rise of alternative energy carriers, notably biofuels and hydrogen, requires highly innovative storage systems capable of safely handling diverse and complex fuel types, presenting both distinct engineering challenges and substantial growth opportunities over the forecast period.

Comprehensive Segmentation Analysis by Storage Type

Analyzing the market through the lens of storage methodologies reveals distinct preferences and emerging engineering tactics. Above Ground Tanks remain the dominant and largest segment in the market. Highly favored for their overall practicality, visual accessibility, ease of maintenance, and significantly faster installation times, these tanks cater effectively to diverse environmental conditions. This segment is expected to maintain the highest total valuation in the market. Below Ground Tanks represent another substantial, steady portion of the market. Floating Storage Units, which provide vital offshore flexibility for maritime transport, are expected to have some growth too.

However, the most strategically significant shift in storage methodology is the rapid emergence of Underground Caverns, which currently stand as the fastest-growing segment in the industry. As environmental regulations tighten globally and the sheer volume of required strategic storage increases, underground caverns provide unparalleled volumetric efficiency, space-saving benefits, and highly enhanced security with minimal surface-level environmental footprints.

Evolution of Material Types in Storage Construction

The choice of construction material is rapidly evolving as the industry attempts to balance traditional durability with modern efficiency and ecological needs. Steel remains the undisputed dominant material in the market, commanding the largest overall share due to its proven, multi-decade strength, longevity, and exceptional resistance to harsh environmental elements. The steel segment is fully projected to maintain its global leadership.

Conversely, Fiber Reinforced Plastic (FRP) is swiftly gaining massive traction as the fastest-growing material segment. As the market increasingly prioritizes logistical sustainability and operational efficiency, FRP offers highly appealing physical characteristics, primarily its significant weight reduction, superior resistance to aggressive chemical corrosion, and drastically lower long-term maintenance costs. The increasing capital investment in advanced material research is expected to further solidify FRP as a vital, innovative alternative for future infrastructure projects worldwide.

End Use Dynamics and the Rise of Cleaner Alternatives

The end-use segmentation highlights a global market currently in deep transition. Crude oil storage continues to represent the largest individual share of the market, rooted in deep-seated, consistent global demand and vast, pre-existing international infrastructure networks.

However, a pronounced structural shift is occurring as energy demands transition steadily toward cleaner alternatives. Natural gas has established itself as a dominant force, benefiting immensely from extensive new infrastructure projects and its critical role as a transitional bridging fuel. Within this specific spectrum, Liquefied Natural Gas (LNG) is explicitly identified as the fastest-growing end-use category, propelled by its increasing popularity as both a heavy industrial energy source and a high-efficiency maritime transportation fuel. Conversely, the refined products segment faces emerging structural challenges. While still fundamentally essential, its long-term growth is tempered by the accelerating global shifts toward vehicle electrification and zero-emission alternative fuels, forcing operators to pivot and innovate to retain market relevance.

In-Depth Regional Market Analysis 

The geographical distribution of the oil and gas storage market is highly varied, with each macro-region presenting uniquely complex economic drivers, political constraints, and investment opportunities.

North America stands as the undeniable leader in the global market, controlling approximately 40% of the total market share. This massive economic footprint is supported by incredibly robust, well-established historical infrastructure, immense domestic energy demand, and highly favorable regulatory frameworks that aggressively support both traditional hydrocarbons and renewable energy storage developments. The region’s intense strategic focus on maintaining unparalleled national energy security ensures its continued infrastructure dominance throughout the forecast period.

Europe currently holds the second-largest global share, accounting for roughly 30% of the market. The European market is distinctively characterized by its rapid, aggressive transition toward sustainable, low-carbon energy. Guided by powerful, binding regulatory initiatives such as the European Union’s Green Deal, the region is pioneering the massive integration of renewable energy sources and innovative, low-emission storage technologies.

The Asia-Pacific region represents the most economically dynamic and fastest-growing territory, currently holding about 25% of the global market share. Driven by skyrocketing basic energy consumption, highly rapid urbanization, and massive industrial expansion particularly within highly populated emerging Asian economies the region requires vast new greenfield storage capacities. Governments across the Asia-Pacific are heavily focused on reducing their historical import dependency by building massive strategic petroleum reserves and establishing secure, highly localized storage infrastructures.

Finally, the Middle East and Africa, currently holding roughly 5% of the global market, provide significant, resource-rich growth opportunities. The region is witnessing a rapid influx of capital investment aimed at diversifying local energy economies and extensively expanding domestic storage capabilities. These expansions are designed to support broad macroeconomic national initiatives, ensuring long-term economic stability and energy security across the region.

Future Outlook and Strategic Conclusion

As the oil and gas storage market progresses relentlessly toward 2035, it is characterized by a delicate, highly strategic balance between fulfilling immediate, traditional global energy requirements and adapting successfully to a rapidly decarbonizing world. With a projected valuation of USD 341.39 USD Billion by 2035 and a solid, dependable CAGR of 3.64%, the sector is anything but structurally stagnant. The long-term future will be definitively shaped by the mass expansion of highly secure underground storage facilities in strategic locations, the widespread implementation of advanced, AI-driven leak detection and environmental monitoring systems, and the crucial deployment of modular, adaptable infrastructure for rapid scaling. By comprehensively embracing technological innovation, shifting toward dynamic hybrid storage models, and complying rigorously with stringent environmental standards, the global market is fundamentally set to remain incredibly robust. Oil & Gas Advancement believes this evolution will successfully facilitate the secure, reliable transition of global energy supplies for the next decade and far beyond.

PETRONAS and ENEOS Xplora (“ENEOS”) have reaffirmed their long-standing partnership, first established in 1995, through the signing of definitive agreements formalising ENEOS’ re-entry into Malaysia LNG Tiga Sdn. Bhd. (MLNG Tiga).

Subject to the fulfilment of certain closing conditions, ENEOS will hold a 10 percent equity stake in MLNG Tiga for the next decade, following the expiry of the previous MLNG Tiga Joint Venture Agreement in 2023.

The agreements were signed by PETRONAS Executive Vice President & Chief Executive Officer of Gas & Maritime Business, Datuk Adif Zulkifli and ENEOS Xplora Representative Director and President, Yasuhiko Oshida.

Witnessing the signing ceremony were PETRONAS Senior Vice President, Corporate Strategy, Marina Md Taib and Executive Officer and Senior Vice President and Head of Business Division 1, ENEOS Xplora, Jotaro Tomoeda.

The agreement marks a significant milestone in the enduring partnership between PETRONAS and ENEOS, reflecting shared commitment to strengthening long-term energy security and supporting reliable LNG supply to international markets, particularly Japan, amid an increasingly complex and volatile global energy landscape.

“LNG continues to play an indispensable role in the global energy mix, bridging the demands of today’s economies while supporting a credible transition toward lower-carbon futures. With Asia at the centre of global LNG demand growth, stable supply and long-term partnerships remain fundamental to economic resilience across the region. The collaboration with ENEOS which now spans three decades reflects that long-term conviction, one that continues to serve the energy interests of both nations well into the decades ahead,” said PETRONAS President and Group Chief Executive Officer Tan Sri Tengku Muhammad Taufik.

ENEOS’ re-entry underscores continued confidence in MLNG Tiga’s operational resilience and long-term value proposition, as well as PETRONAS’ proven capabilities as a world-class LNG operator and trusted partner.

“ENEOS’ re-entry into MLNG Tiga reflects shared confidence in the asset’s resilience and long-term role within Asia’s LNG landscape. It also reinforces PETRONAS’ focus on building a reliable LNG system that continues to deliver value to customers and partners, particularly in important markets such as Japan,” said Adif Zulkifli.

“MLNG Tiga has been a project that has steadily supplied LNG to Japanese buyers since commencing operations in 2003, under the cooperation between our group and PETRONAS, and we are very pleased to be participating once again. While further strengthening our partnership with PETRONAS, we will also work closely with our fellow shareholders – the Sarawak State Government and Mitsubishi Corporation, to pursue new value creation during the energy transition.” said Yasuhiko Oshida.

The agreement reinforces continued foreign investor confidence in Malaysia’s investment climate and long-term growth prospects. This reflects the country’s strong fundamentals, supported by a stable regulatory framework and a conducive business environment that continues to attract long-term investments in the energy sector.

The deal comes as Venezuela accelerates efforts to attract foreign investment into its energy sector, having recently concluded exploration and cooperation agreements with global producers such as Italy’s Eni and Spain’s Repsol. This shift follows the ouster of President Nicolas Maduro by U.S. forces in January, a development that has opened the door for broader international participation in the country’s oil and gas industry. Within this evolving landscape, BP is positioning itself as a key participant in cross-border gas initiatives tied to regional supply and export infrastructure.

Speaking at the signing ceremony, Venezuela’s interim President Delcy Rodriguez, said, “The return of BP is a ⁠clear sign of the future we want to chart for Venezuela and for ​international energy relations — relationships based on respect, cooperation grounded in a win-win approach, and ​shared benefits that contribute to the development of the Venezuelan people.”

William Lin, BP’s executive vice president for gas and low carbon energy, said the company was pleased to be partners with Venezuela on the exploration of the Loran area, as well as on other projects, ‌including ⁠the commercialization of gas.

The MOU also “formalized the launch of gas development at the Cocuina-Manakin field,” a gas field that crosses the border between Trinidad and Tobago and Venezuela, Rodriguez’s office said in ​a statement.

The field straddles the border between Venezuela and Trinidad and Tobago, with Cocuina forming part of the inactive Deltana Platform project on the Venezuelan side and extending into Trinidad, where a BP subsidiary operates it as Block 5b.

BP had earlier indicated it was seeking a U.S. government license to move ahead with development of the Cocuina-Manakin field. The company aims to unlock more than 1 trillion cubic feet of gas from the project, which would be transported to Trinidad for conversion into liquefied natural gas destined for export markets.

“ARC is a high-quality, low-cost and top quartile low carbon intensity producer operating in the Montney shale basin that complements our existing footprint in Canada and strengthens our resource base for decades to come. We are accessing uniquely positioned assets and welcoming colleagues that bring deep expertise which, combined with Shell’s strong basin level performance, provides a compelling proposition for shareholders.” said Shell’s chief executive officer, Wael Sawan. “This establishes Canada as a heartland for Shell while furthering our strategy to deliver more value with less emissions.”

“This combination is a great opportunity for ARC to realise value for our shareholders and continue to benefit from Shell’s success in the future. ARC is combining with a company that has a global portfolio of best-in-class assets,” said ARC president and CEO, Terry Anderson. “I’m excited that ARC’s assets and world class people will play an important role in helping Shell to further strengthen Canada’s resource landscape whilst also providing the secure energy that the world needs.”

This ARC Resources acquisition increases Shell’s production CAGR from 1% as outlined at our 2025 Capital Market’s Day to 4%3, compared to 2025, and supports Shell’s aim to sustain material liquids production of ~1.4 million barrels per day towards 2030 and beyond. The transaction combines ARC’s more than 1.5 million net acres with Shell’s ~440 thousand net acres in the Montney formation and adds ~2 billion barrels of oil equivalent proved plus probable reserves at the end of 20254. Last year, ~40 per cent of ARC’s production was liquids, which accounted for ~70 per cent of its revenues. In addition, ARC’s proved plus probable gas reserves have the potential to support Shell’s growth in LNG in Canada.

Under the terms of the agreement, ARC’s shareholders will receive CAD 8.20 in cash and 0.40247 ordinary shares of Shell for each ARC share, representing approximately 25% cash and 75% shares as of the 24th April 2026 market closing. Based on Shell’s closing share price on this date of GBP 33.08 and GBP:CAD exchange ratio of 1.8480, this translates to a consideration of CAD 32.80 per share, which represents a 20 per cent premium to ARC’s 30-day5 VWAP. This equates to an equity value of approximately US$13.6 billion. Shell will take on approximately US$2.8 billion in net debt and leases resulting in an enterprise value of approximately US$16.4 billion. The equity value of US$13.6 billion will be funded via US$3.4 billion in cash and US$10.2 billion in Shell shares, the latter valued based on Shell’s closing price on the 24th April and the issuance of approximately 228 million ordinary shares.

The boards of both companies have unanimously supported the transaction, which is expected to close in the second half of 2026, subject to ARC shareholder, court and regulatory approvals.

According to the Ministry of Energy, the agreement is expected to support diversification of non-oil revenues, reinforce national industrial strategies, and contribute to job creation for Saudi citizens, alongside boosting local content. The commercial start-up of the Amiral complex, which serves as a central element of Saudi Aramco’s liquids to chemicals strategy, is scheduled for 2027. Previous disclosures by TotalEnergies indicate that the project could unlock approximately $4 billion in additional investments tied to Amiral downstream industries, particularly in petrochemical and specialty chemical facilities across the Jubail industrial area. These plants are expected to utilize feedstock from Amiral to support the production of carbon fibres, lubricants, drilling fluids, detergents, food additives, automotive components, and tyres, further reinforcing the role of Amiral downstream industries in industrial expansion.

The project is anticipated to generate at least 7,000 direct and indirect local jobs through the Amiral complex and its associated facilities. The complex itself incorporates a mixed-feed cracker with an ethylene production capacity of 1.65 million tonnes per year, alongside two polyethylene production lines, each with a capacity of 500,000 tonnes per year. Additional infrastructure includes a butadiene extraction unit and several derivative units. Feedstock for these operations will be sourced from refinery off-gases and naphtha produced by SATORP, in addition to ethane and light naphtha supplied by Saudi Aramco.

As part of its decarbonisation approach, hydrogen generated as a by-product of the steam cracker will replace methane currently used as fuel in furnaces at the SATORP refinery. The project reached Final Investment Decision (FID) in December 2022, followed by a series of engineering, procurement and construction (EPC) contract awards in June 2023. Key contractors include Hyundai Engineering & Construction, Maire Tecnimont, Sinopec Engineering Group Saudi Co., and Gulf Consolidated Contractors Co, alongside additional agreements with Mohammed Ali Al-Suwailem Trading & Contracting Co., Mofarreh Marzouq Al Harbi & Partners Co., and Mobarak M. Al Salomi & Partners for Contracting Co.

Highlighting the importance of the occasion, Saad Sherida Al-Kaabi stated: “This is a significant industry milestone that marks a new chapter in QatarEnergy’s global efforts to meet rising LNG demand and ensure reliable supplies to international markets.”

The first LNG export underscores the strategic importance of the Golden Pass LNG project within QatarEnergy’s broader expansion plans. Al-Kaabi further emphasized the scale of the initiative, noting: “The Golden Pass LNG project is one of the single largest investment decisions in the history of the U.S. LNG sector, affirming QatarEnergy’s position and reputation as a reliable provider and a trusted partner of choice that drives growth and development around the world.” These remarks reflect the broader industry implications of the first LNG export and its contribution to strengthening supply reliability.

The Golden Pass LNG project is structured as a partnership, with QatarEnergy holding a 70% stake and ExxonMobil owning the remaining 30%. The partners had taken a final investment decision exceeding USD 10 billion in February 2019 to advance the development. From the project’s total production capacity of 18 million tons per annum, 70% will be allocated to QatarEnergy Trading, the company’s wholly owned LNG trading arm. The first LNG export and the subsequent offtake volumes are expected to enhance QatarEnergy Trading’s global LNG portfolio while supporting its ongoing business expansion. This first LNG export also aligns with the company’s strategy to secure long-term market presence through integrated supply chains.

Operationally, the project has already reached key technical milestones, including sustained liquefaction operations and the commencement of LNG production from the first of its three LNG trains on 30 March 2026. The achievement of the first LNG export follows closely on the heels of this production start, demonstrating the project’s rapid transition from commissioning to export readiness. As additional trains come online, the Golden Pass LNG project is expected to further scale its output, with the first LNG export representing a foundational step in its long-term operational trajectory.