Global energy companies in attendance
GASTECH 2026 is now open in Bangkok
Gastech 2026 is now underway, bringing together the global energy community at the world’s largest exhibition and conference dedicated to natural gas, LNG, low carbon solutions, electrification and AI for energy.
Across four days, global leaders, breakthrough technologies and strategic partnerships come together to shape secure, affordable energy at scale. Gastech offers unrivalled access to the insights, innovations and connections driving industrial competitiveness, strengthening resilience and advancing sustainable economic growth.
There’s still time to join Gastech 2026. Register today and be part of the conversations, connections and opportunities shaping the future of energy.
A selection of confirmed speakers
session [
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"PublishedSessionDate": "2026-08-27 10:38:03",
"Title": "Fuel choice under pressure: Utilities, resilience and Japan\u2019s evolving power mix",
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"biography": "Akira Yabumoto is Executive Officer responsible for Global Energy Strategy at J-POWER (Electric Power Development Co., Ltd.). Since joining the company in 1989, he has worked across regulatory affairs, policy analysis, corporate planning, and strategic business development in the evolving electricity and energy markets.\n\nFrom 1995 to 1997, he was a Visiting Researcher at MIT\u2019s Center for Energy and Environmental Policy Research (CEEPR), where he conducted research on electricity industry restructuring. His work contributed to J-POWER\u2019s internal analysis during the period of privatization and market liberalization in Japan.\n\nFrom 2009 to 2011, he was seconded to the International Energy Agency (IEA) Secretariat in Paris as an Energy Analyst in the Country Studies Division, where he participated in In-Depth Reviews of the electricity sectors of four IEA member countries. After returning to Tokyo, he worked on international business development, including projects in the Indian market, as well as corporate planning and market analysis.\n\nHe currently supports J-POWER\u2019s senior management by providing informed analysis and insights on key global energy policy, market, and geopolitical trends, and by helping facilitate senior-level engagement with international energy organizations, policy experts, and industry leaders. He also leads a cross-functional team working on Blue Hydrogen and overseas CCS development initiatives. He has spoken at and participated in international energy conferences and policy discussions, offering a practitioner\u2019s perspective on energy markets, energy security, and the energy transition",
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"PublishedSessionDate": "2026-09-09 08:47:40",
"Title": "Trading the LNG market: Contracting, optionality and portfolio advantage",
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"Description": "\u003Cp\u003ELNG markets are becoming more dynamic and trade-driven, with freight, routing and timing increasingly shaping value. For traders, success lies in optimising cargoes across routes and counterparties, not just regional price spreads. This is reshaping contracts. Flexibility, diversion rights and portfolio breadth are now key advantages, while buyers weigh concentration versus diversification. Long-term deals remain vital but must evolve to keep pace with a more fluid, trader-led market.\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EAudience insight: \u003C/strong\u003EThe evolution of contracts to balance security, optionality, and tradability in a more liquid LNG market.\u003C/p\u003E",
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"Description": "\u003Cp\u003ETechnical papers can be accessed here: \u003Ca href=\u0022https://www.gastechevent.com/technical-papers/\u0022 rel=\u0022noopener noreferrer\u0022 target=\u0022_blank\u0022\u003Ehttps://www.gastechevent.com/technical-papers/\u003C/a\u003E\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EPathways of ship-based CCTS value chain targeting depleted offshore oil and gas fields\u0026nbsp;\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EXiang Liu, Principal Engineer, ABS\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe carbon capture, transportation and storage (CCTS) value chain is built on CO\u2082 capture technologies that separate carbon dioxide from industrial gas streams, including from sources such as cement plants, power stations and even marine vessels. Offshore environments offer long-term CO\u2082 sinks. This paper focuses on a ship-based CCTS value chain in which liquid CO\u2082 (LCO\u2082) carriers transport captured CO\u2082 to depleted offshore oil and gas (O\u0026amp;G) fields for permanent geological sequestration.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe implementation of such a ship-based CCTS value chain is nascent. Present LCO\u2082 carriers are typically built for regional CO\u2082 transportation from a point source to a point sink. By contrast, the offshore O\u0026amp;G industry has accumulated decades of experience in injecting CO\u2082 and other fluids into geological formations. By using depleted offshore fields, we gain access to extensive subsurface data for CO\u2082 storage assessment and an existing infrastructure that may be repurposed for CO\u2082 injection. Leveraging these advantages requires an integrated view of the ship-based CCTS chain and its interfaces. The paper recognizes four major challenges for enabling a robust ship-based CCTS value chain: (1) the lack of unified logistics and cargo specifications for multi-source CO\u2082 streams; (2) the absence of port or nearshore CO\u2082 collection infrastructure that is compatible with aggregation and temporary storage of captured CO\u2082 onboard vessels; (3) the technical complexity of transferring large, intermittent LCO\u2082 cargoes delivered by ship to offshore installations designed for continuous injection; and (4) CO\u2082 compatibility issues arising when utilizing depleted offshore fields as CO\u2082 storage sites. The paper defines the interfaces relevant to transhipment and offshore offloading scenarios, with a primary focus on unloading ship-transported LCO\u2082 at offshore facilities, while also considering the loading and unloading of LCO\u2082 at the emission source. Drawing on published engineering practice and existing standards where available, the paper consolidates applicable CO\u2082 stream specifications for ship-based CCTS chains and develops a structured guidance methodology for screening technically feasible CO\u2082 cargo transfer pathways in light of the four challenges identified. Applying this methodology, thirty (30) potentially feasible transfer pathways for transporting LCO\u2082 by ship to offshore facilities are identified and tabulated for user\u2019s reference. These pathways support the systematic identification of key systems and equipment for CO\u2082 cargo transfer.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003ETo overcome the mismatch between batchwise shipment of LCO\u2082 and the requirement for continuous CO\u2082 injection into geological formations, the paper highlights the critical role of buffer storage tanks in both nearshore and offshore operations. In alignment with a ship-based CCTS value chain targeting depleted offshore O\u0026amp;G fields, four (4) LCO\u2082 floating storage unit (FSU) concepts are outlined. The functionalities of these LCO\u2082 FSUs are to receive LCO\u2082 from periodically visiting shuttle carriers, store LCO\u2082 in onboard tanks, and offload LCO\u2082 continuously (24/7) to offshore units located within depleted fields that are repurposed for CO\u2082 injection.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe paper thereby provides practical guidance on key bottlenecks, feasible transfer pathways and critical equipment for enabling ship-based CCTS chains to support large-scale offshore CO\u2082 sequestration.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EComparative analysis of CO2 liquefaction technologies: Balancing efficiency, cost, and space constraints\u0026nbsp;\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EMitsuhiro Yamazaki, Head - Process Engineering Section 3, Chiyoda Corporation\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003ECarbon dioxide (CO\u2082) is a greenhouse gas that significantly contributes to global warming. Developing effective methods for its capture and storage is crucial for our industry. One such method involves liquefying post-combustion CO\u2082, enabling large-scale, long-distance cross-border transportation. Given the high energy demand, particularly in the liquefaction process, energy conservation is essential.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EAdditionally, post-combustion CO\u2082 capture plants are typically built near existing emission sources, along with the liquefaction facilities. Due to the limited space at these sites, it is important to balance energy conservation with spatial constraints. These restrictions vary by industry and location. Chiyoda has conducted a comprehensive comparison of three CO\u2082 liquefaction technologies, including the necessary auxiliary facilities, focusing not only on liquefaction efficiency but also on overall feasibility. In our session, we will provide guidance for selecting the optimal CO\u2082 liquefaction process.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EIn this study, we perform a comparative analysis of CO2 liquefaction technologies, comparing the energy efficiency of liquefaction processes, where external refrigerant processes using propane or ammonia, and a self-refrigeration process utilising CO\u2082 as refrigerant are examined. Our analysis further extends to explore the variations in CAPEX and OPEX resulting from the utility consumption necessary for liquefaction facilities. The study also considers the space these facilities occupy, their carbon intensity, and the indicators for selecting the optimum liquefaction technology. We will present case studies where we have assessed the unique site specifics of sample projects to give a thorough basis for this comparative assessment.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003ELCO\u2082 storage: Technical challenges and strategic importance for Southeast Asia\u2019s emerging energy market\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EAndy Jacobson, Engineering Manager, CB\u0026amp;I\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EAs global energy systems accelerate toward decarbonization, the role of carbon capture, utilisation, and storage (CCUS) is expanding beyond traditional subsurface sequestration. Large-scale liquid carbon dioxide (LCO\u2082) storage is a critical component of infrastructure that affects carbon management, transportation, buffering storage, and utilisation pathways across industrial clusters. This paper examines the technical challenges associated with LCO\u2082 storage and highlights its growing importance in the evolving energy markets of Southeast Asia.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003ELCO\u2082 storage involves maintaining carbon dioxide at refrigerated temperatures and moderate pressures to achieve the high-density liquid conditions suitable for bulk storage and transport. By significantly reducing volumetric requirements, LCO\u2082 storage enables more economical designs for centralised hubs, ship-based transport systems, and large-scale storage vessels. This is particularly relevant for regions with limited pipeline infrastructure or geographically dispersed emission sources.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EHowever, storing LCO\u2082 at scale presents a set of technical challenges that differ markedly from those encountered in conventional hydrocarbon or cryogenic fluid storage due primarily to its very high triple point and narrow liquid phase envelope. The formation of dry ice will likely result in a three-phase system that may not easily self-correct to a two\u2013phase liquid\u2013gas equilibrium state. Key technical challenges for LCO\u2082 pressure vessels include increased susceptibility to brittle fracture at low operating temperatures, the absence of well-established and standardised design and operating envelopes, and the structural design of vessel supports to accommodate the high density of liquid CO\u2082, particularly in seismically active regions such as Southeast Asia\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EDespite these challenges, LCO\u2082 storage is poised to play a pivotal role in Southeast Asia\u2019s energy transition. Many countries face constraints with onshore geological storage capacity or lack mature CO\u2082 pipeline networks. In this context, LCO\u2082 storage enables hub-and-spoke CCUS models, ship-based CO\u2082 transport between emitters and storage sites, and integration with emerging carbon utilisation markets such as synthetic fuels, chemicals, and food-grade CO\u2082. This paper discusses the technical challenges and recent developments associated with large-scale LCO2 storage. With the continued development, LCO\u2082 storage can become a cornerstone of Southeast Asia\u2019s low-carbon energy infrastructure, bridging today\u2019s emissions-intensive systems with tomorrow\u2019s sustainable energy economy.\u003C/p\u003E",
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"Description": "\u003Cp\u003ETechnical papers can be accessed here: \u003Ca href=\u0022https://www.gastechevent.com/technical-papers/\u0022 rel=\u0022noopener noreferrer\u0022 target=\u0022_blank\u0022\u003Ehttps://www.gastechevent.com/technical-papers/\u003C/a\u003E\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EModular or stick-built: Schedules trade-offs in LNG EPC project delivery\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EDr. Rafael Agra, Construction Manager, Technip Energies\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EAs LNG projects continue to increase in scale, technical complexity, and geographic diversity, project stakeholders are increasingly required to balance aggressive schedule targets against heightened execution risk. Among the most influential strategic decisions made during project development is the selection between modularised construction and conventional stick-built execution. Although modularisation is universally associated with de-risked construction and reduced onsite labour exposure, its schedule implications are not systematically beneficial. The actual schedule outcomes are obviously highly dependent on the project context and specifics.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThis presentation provides a detailed comparative analysis of modular and stick-built construction schedules for LNG EPC projects, with a specific focus on how each approach shapes schedule logic and critical path.\u0026nbsp;Key differences in schedule behaviour are highlighted by examining the full execution timeline, from engineering detailed design and procurement sequencing up to module site installation and integration. The overlap with site activities is also scrutinised in detail, especially at the interface with module installation.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EEmphasis is placed on understanding how modularisation fundamentally restructures the schedule by transferring a significant portion of Mechanical, Electrical \u0026amp; Instrumentation activities from the site to single or multiple fabrication yards, thereby shifting schedule criticality upstream into engineering completion, vendor data availability, and module fabrication productivity. The challenge is to identify the finite number of key ingredients that drive the schedule in both Modular and Stick-built strategies. Such drivers are evaluated in the present study across all project phases, including engineering maturity requirements, module yard productivity, logistics and transportation constraints, site readiness, and integration. Special attention is given to schedule interfaces introduced by modular execution. These interfaces often create discrete, logistics-driven critical paths that differ markedly from the more continuous and field-driven critical paths characteristic of stick-built projects.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe investigation presented is based on several actual as-built LNG projects, both stick-built and modular.\u0026nbsp;Replicability (for multiple identical LNG trains, for instance) and its implications on the EPC schedule are also analysed.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EBased on this comparative analysis, the paper concludes by proposing a structured framework to support construction strategy selection during early project development. This framework aligns schedule objectives with project-specific risk profiles, execution constraints, and organisational capabilities, enabling more realistic schedule development and improved predictability of LNG project delivery outcomes.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EModular liquefaction and pre-treatment: How they can make projects faster and cheaper\u0026nbsp;\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EDipanjan Bhattacharya, Technology Manager - LNG \u0026amp; Gas Processing, Kiewit\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe paper illustrates the value of pre-engineered and modular solutions for large- and medium-scale LNG trains in terms of project timeline, execution strategy and economics.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe concept originated from construction challenges encountered across recent mid- to large-capacity LNG projects. In North America, these challenges include shortages of experienced craft labour, construction on highly constrained sites, attrition of labour to competing industries such as data centres and other infrastructure projects and ongoing execution risks, some of which can be mitigated through design. Outside of North America, projects are often located in remote areas or regions with difficult working conditions, including those with extreme weather or political instability.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EEarly-stage investment also presents significant challenges for project developers, as the financial burden is greatest at project inception. To address this, we are presenting a case study of a modular solution that standardises an end-to-end pretreatment and liquefaction train design to the greatest extent possible, reducing pre-FEED and engineering costs and improving project economics. The modular solution is based on a standardised, fully integrated and optimised process technologies, offering a process licensor\u2019s single accountability for both liquefaction and pre-treatment. To accommodate varying power requirements, the design incorporates dual-mode optionality, with both gas turbines and electric drive configurations being possible.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThis modular solution is based upon a highly efficient coil-wound heat exchanger (CWHE) liquefaction unit to provide maximum LNG output. Beyond liquefaction, pretreatment and nitrogen removal have also been standardised using an integrated pretreatment process, which includes SeparSIV to provide a complete, bankable, end-to-end liquefaction train solution. An incremental gain via seamless integration of an automation system, inclusive of the process licensor\u2019s know-how, may also be leveraged as LNG projects compete for the best economics. Where feed gas conditions require deviation in pretreatment or where nitrogen removal is unnecessary, adjustments can be made within the established framework, as the design anticipates such variations.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe case study completed a high-fidelity 3D model to support this approach. The strategy avoids mega modules due to yard and transport constraints and instead utilises module sizes that are simpler to source and transport. The paper discusses the methodology used to determine module layouts, sizes and dimensions, taking into account module yard availability, ship availability and general site accessibility.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe study highlights the following design development, including:\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u2022Equipment layout aligned with process flow path to minimize piping in between modules\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u2022Module variations driven by feed gas composition, particularly within the pretreatment unit\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u2022Equipment weights and dimensional constraints\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThis paper demonstrates how standardisation reduces overall project development time and cost, while also creating efficiencies that extend into the early EPC phase. It further examines how outlier conditions can introduce deviations from the standard approach and how these impacts are addressed.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EAn overlooked threat: The truth about airflow deficits in ACHEs \u2013 a direct impact on LNG production\u0026nbsp;\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EYuta Kawashima, Senior Engineer, JGC Corporation\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EHundreds of air-cooled heat exchangers (ACHEs) are utilised throughout the air-cooled LNG plant. The performance of ACHEs is critical and directly affects LNG production. The performance of ACHEs can be significantly reduced if hot air recirculation (HAR) occurs. Nowadays, Computational Fluid Dynamics (CFD) is routinely used for HAR studies to predict and mitigate impacts in advance. However, another issue of air flow deficit in ACHEs, which significantly affects LNG production, has not yet been widely recognised in the energy industry. Insufficient air flow directly reduces the cooling performance of ACHEs, especially propane condensers, and hence, leads to less refrigerant condensation and lower LNG output directly. For the current LNG facility, the design margins, which are set to ACHE heat transfer area, gas turbine capacity and licensed process package, help mitigate the effects of air flow deficits. As a result, the air flow deficit issue has been made ambiguous.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EAs a global engineering leader, JGC investigated the air flow deficit issue in the LNG plant through air flow measurement at site, CFD-based root cause analysis, small-scale ACHE experiments, and process evaluation. Although the vendor shop test can achieve 100% of the design airflow, the air flow measurement of the ACHEs in several LNG plants shows that the actual air flow rate in the ACHEs is 20-30% lower than the design air flow due to the effects of the installed obstacles and weather conditions. The root cause of the air flow rate deficit was investigated using CFD simulation. It was found that the airflow deficit is mainly induced by plant layout, including ACHE height and nearby obstacles, weather conditions, and ACHE configuration. To address the air flow deficit concern, JGC is collaborating with Kyoto University to construct a small-scale ACHE test facility with an open wind tunnel as shown in Figure 1. Results from the controlled indoor environment demonstrate that air flow rates could decrease by up to approximately 25% depending on the ACHE configuration and wind conditions. Additionally, operational data from LNG plant facilities indicate an air flow deficit ranging from 10% to 30%. A certain process simulation results for a typical LNG plant revealed that a 10% deficit in air flow rate could correspondingly cause a 2% reduction in LNG production, which underlines the importance of addressing this issue for both the plant owner and the EPC contractor.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe actions from the whole LNG industry are required to address this ACHE air-flow deficit issue. First, it is important for the LNG industry to recognise that ACHE air flow deficit is a widespread and systemic issue directly affecting LNG production, with a comparable or larger impact than HAR but far less acknowledged. Second, there is a strong need to establish LNG industry-wide design guidelines that define standardised methods for the assessment of airflow impact, layout optimisation, and deciding appropriate design margins from early stages. Finally, for existing plants, applying diagnostic air flow measurements, CFD-based evaluations, and targeted engineering modifications provides a practical pathway to recover lost performance and increase LNG output.\u003C/p\u003E",
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"Description": "\u003Cp\u003ETechnical papers can be accessed here: \u003Ca href=\u0022https://www.gastechevent.com/technical-papers/\u0022 rel=\u0022noopener noreferrer\u0022 target=\u0022_blank\u0022\u003Ehttps://www.gastechevent.com/technical-papers/\u003C/a\u003E\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EToward the future of commercial liquefied hydrogen utilisation: Development of the 40,000 m\u00B3 liquefied hydrogen carrier\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EHaruhiko Tominaga, Manager, Kawasaki Heavy Industries\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EIn 2022, Kawasaki Heavy Industries, Ltd. delivered the world\u0027s first liquefied hydrogen carrier, Suiso Frontier, demonstrating its capability to develop, design and build ships to carry liquefied hydrogen. Through its gas trial, as well as full-load sea trials and cargo handling tests repeatedly conducted between Japan and Australia, Kawasaki verified highly reliable cargo containment and cargo handling systems and established technologies necessary for safe, large-scale maritime transportation of liquefied hydrogen.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EIn 2025, Kawasaki embarked on the next stage by signing a shipbuilding contact for a 40,000 m\u00B3-class liquefied hydrogen carrier with a Japanese customer. Based on the technologies developed through Suiso Frontier, Kawasaki has further advanced its expertise and completed the development and initial design of this vessel that will realise commercial-scale maritime transportation of liquefied hydrogen.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe vessel will enable commercial-scale transportation with a large-capacity, high-performance cargo containment system that has been further developed from the cargo tank structure and insulation systems on Suiso Frontier. It will also reduce GHG emissions and facilitate appropriate BOG (boil-off gas) management during operation with a newly introduced hydrogen-fuelled propulsion system that combines a hydrogen-fuelled diesel engine and fuel supply system.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EFurthermore, with cargo handling systems incorporating large capacity cargo pumps and cargo compressors, the vessel is capable of handling large quantities of liquefied hydrogen in a short period while significantly minimising cargo loss. The vessel is scheduled to enter service in 2030, marking the start of commercial maritime transportation of liquefied hydrogen.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EKawasaki is also working on the development of a new type of cargo containment system that will be a key component for expanding commercial-scale maritime transportation of liquefied hydrogen. This development is being supported by NEDO and is planned to be completed in 2027. The next-generation cargo containment system will further increase transportation capacity. Kawasaki expects to make a significant contribution to realising a carbon-neutral society through the implementation of this new technology.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThis presentation introduces the development of the 40,000 m3 liquefied hydrogen carrier and next-generation cargo tanks that will enable even larger-scale commercial transportation, helping achieve a carbon neutral society in the future.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003ERealising commercial LH\u2082 shipping: Verification of large-scale LH\u2082 storage technology and a pioneering 2,000 m\u00B3 LH\u2082 carrier\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EDr. Woorim Lee, Senior Research Engineer, HD Korea Shipbuilding \u0026amp; Offshore Engineering (HD KSOE)\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EHD Korea Shipbuilding \u0026amp; Offshore Engineering (HD KSOE) has successfully verified the scale-up feasibility of large liquid hydrogen (LH2) storage tanks through extensive mock-up testing. Central to this achievement is a newly developed vacuum insulation system that potentially enables the construction of large LH2 tanks in a time- and cost-effective manner, which is critical for large hydrogen carriers, hydrogen-fueled vessels, and onshore storage applications.\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EA key technical challenge in large-scale LH2 storage is establishing and maintaining high-quality vacuum insulation in very large tanks. HD KSOE addressed this challenge by developing an innovative vacuum creation method that significantly reduces evacuation time while ensuring long-term vacuum stability. The solution was validated through tests using a large vacuum chamber and a full-scale LH2 mock-up tank, making HD KSOE the first shipbuilder to demonstrate the practical viability of this approach. Traditionally, achieving the required vacuum level for a 5,000 m3 tank could take several months; test results indicate that the new vacuum installation system could potentially complete the vacuum process within only a few days for a 20,000 m3 tank. Mock-up testing also confirmed that the tank meets the design boil-off rate (BOR) and maintains structural integrity and stable operation under long-term LH2 storage conditions. The results demonstrate robust vacuum retention performance as well. The testing program was closely reviewed by major classification societies\u2014including DNV, LR, ABS, and KR\u2014and experts from the hydrogen shipping industry, providing independent validation and valuable technical insights to be presented at Gastech 2026.\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe newly developed tank technology will be implemented on a 2,000 m3 LH2 demonstration carrier supported by the Korean government. The vessel is designed to validate core technologies for future large commercial LH2 carriers. It will be equipped with three spherical tanks, identical in concept to those intended for large-scale carriers, along with a cargo handling system capable of managing boil-off gas and multi-tank operation. The ship will also feature a hybrid electric propulsion system combining a dual-fuel hydrogen-diesel HiMSEN engine and a Proton Exchange Membrane Fuel Cell (PEMFC), enabling verification of lower-emission shipping technologies.\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EHD KSOE is developing large LH2 carrier solutions in collaboration with leading global energy and shipping companies, including Woodside Energy, MOL, and Hyundai Glovis. This collaborative effort aims to establish a robust global hydrogen shipping value chain. Technical insights obtained from the 2,000 m3 demonstration vessel are expected to play a pivotal role in advancing commercial LH2 transport technologies. The Gastech presentation will highlight both the technical achievements and the commercial progress of these collaborations, marking a significant step toward enabling large-scale international hydrogen trade.\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EHydrogen bunkering technology and standards: Status, challenges, and future perspectives\u0026nbsp;\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EHuan Tu, Senior Engineer, China Classification Society\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EHydrogen is a potential candidate carbon\u2011neutral fuel for the shipping industry. The utilisation of hydrogen fuel necessitates the implementation of safe and reliable bunkering operations. This paper systematically surveys recent research, applications and challenges in hydrogen bunkering focusing on key technologies, core equipment and technical standards, covering major storage methods such as high\u2011pressure gaseous hydrogen, cryogenic liquid hydrogen, liquid organic hydrogen carriers (LOHC) and metal hydrides. It also reviews the current status of qualitative and quantitative risk assessment studies for hydrogen bunkering, summarises the methods and risk control measures used. On the basis of the review and analysis, the development needs and future directions for hydrogen bunkering technologies, standards and risk assessment will be proposed.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E1. Current status of shipboard hydrogen storage\u0026nbsp;\u003C/p\u003E\u003Cp\u003EBunkering methods is primarily determined by the vessel\u2019s hydrogen storage technology and the supporting bunkering infrastructure. This section introduces the main storage options, including high\u2011pressure gaseous hydrogen, cryogenic liquid hydrogen, LOHC, and metal hydrides, and analyses and compare their advantages and limitations. Representative shipboard application cases are summarised, with analysis of vessel arrangement, storage capacity, operating pressure and other application features.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E2. Analysis of key bunkering technologies\u0026nbsp;\u003C/p\u003E\u003Cp\u003E1) Bunkering modes: Summarise principal modes including shore\u2011based bunkering station, mobile bunkering trailer, bunkering vessel, and fuel skid replacement, and compare them in terms of technology readiness, delivered volume, safety risk and technical challenges. In addition, strengths and weaknesses of each mode will be discussed.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E2) Bunkering equipment: for different hydrogen storage methods the core bunkering equipment required primarily includes hydrogen compressors, high\u2011pressure liquid hydrogen pumps, and refuelling dispensers. The key technical points for these devices will be summarized and analysed.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E3) Bunkering strategies: To control temperature rise and pressure in the hydrogen storage vessel during bunkering, appropriate control strategies for pressure, flow and temperature are required, as well as the bunkering efficiency should be considered. Because thermodynamic and kinetic characteristics differ among storage methods, analyse tailored strategies: for high\u2011pressure gas\u2014multi\u2011stage filling, controlled pressure rise rates, source pre\u2011cooling and real\u2011time communication during filling; for liquid hydrogen\u2014constant\u2011pressure filling; for metal hydrides\u2014fixed\u2011flow or pressure\u2011maintaining filling regimes.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E3. Status of risk assessment development\u0026nbsp;\u003C/p\u003E\u003Cp\u003EBy systematically reviewing the risk assessment studies for hydrogen bunkering operations, the safety hazards during bunkering and the consequences of leakage, dispersion, combustion and explosion will be analysed, and the qualitative and quantitative risk assessment methods and implemented risk control measures will be synthesised.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E4. Gap analysis of technical standards\u0026nbsp;\u003C/p\u003E\u003Cp\u003ETechnical standards across multiple levels will be investigated, including the IMO regulations, flag\u2011state regulations, classification society rules, industry standards and guidelines from professional organisations. Furthermore, relevant standards from industrial and automotive hydrogen refuelling that could inform maritime practice will be referenced. Based on the current standards landscape and specific shipboard requirements, current gaps and future development directions for developing bunkering standards applicable to maritime scenarios will be proposed.\u003C/p\u003E",
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"Description": "\u003Cp\u003ETechnical papers can be accessed here: \u003Ca href=\u0022https://www.gastechevent.com/technical-papers/\u0022 rel=\u0022noopener noreferrer\u0022 target=\u0022_blank\u0022\u003Ehttps://www.gastechevent.com/technical-papers/\u003C/a\u003E\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EEvolving LNG procurement strategies in East Asia and their interaction with spot market dynamics\u0026nbsp;\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EFei Xu, Senior Gas Analyst, ICIS\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThis study examines how the procurement strategies of Asian LNG buyers are redistributing influence over Asian spot LNG price formation.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EIt begins with an assessment of historical LNG import patterns and the underlying demand fundamentals that determine the structural and seasonal profile of LNG requirements across Japan, Korea, China, Taiwan and emerging Southeast Asian markets.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe analysis then evaluates how medium-term LNG import trends are being shaped by structural changes in the macroeconomic environment, country-level energy strategies and policy implementation, including shifts in power-sector fuel mixes, industrial activity, availability of alternative generation and fuel-switching economics.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EBuilding from these fundamentals, the study assesses how procurement strategies are beginning to evolve and how the relative influence of key Asian buyers on spot LNG price formation is shifting. These developments are assessed in the context of a global LNG market expected to remain structurally oversupplied over the next five years.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe analytical framework links three layers of assessment:\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E1.Demand fundamentals:\u0026nbsp;\u003C/p\u003E\u003Cp\u003EDemand fundamentals are characterised through seasonal consumption patterns, power-sector fuel-mix dynamics and the availability of alternative generation (including nuclear and hydropower), together with industrial and city-gas demand trends. These indicators define the structural and seasonal LNG requirements in each market.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E2.Procurement strategy behaviour:\u0026nbsp;\u003C/p\u003E\u003Cp\u003EICIS datasets covering long-term LNG contracts, cargo-level procurement activity and satellite-monitored daily import flows form the empirical foundation of the analysis.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EContract attributes - including buyer and seller details, contracted annual volumes, indexation structures, price slopes and delivery terms - are consolidated into buyer-level procurement matrices. Spot-market behaviour is assessed through procurement timing, supply-security and stock-management strategies, and buyer responsiveness to historical EAX price movements, TTF-EAX spreads, Brent-Asian spot parity and Atlantic-Pacific arbitrage conditions.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E3.Spot-price dynamics:\u0026nbsp;\u003C/p\u003E\u003Cp\u003ESpot-price dynamics are evaluated using historical EAX price movements (ICIS East Asia spot price benchmark) together with realised seasonal differentials, volatility patterns and inter-basin price connectivity as inferred from TTF, the key European gas benchmark assessed by ICIS. This approach enables assessment of how procurement behaviour, when combined with underlying demand fundamentals and evolving global supply conditions, translates into observable price outcomes.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe presentation highlights how shifts in Asian demand fundamentals, country-level energy strategies and evolving procurement approaches are changing the seasonal and structural shape of LNG procurement. It also explores how these elements may interact with expanding flexible supply from the Atlantic Basin and with inter-basin price relationships. These interactions are presented to demonstrate how varying procurement behaviours across Asia can shape regional engagement with the spot market under different supply and demand conditions. Finally, the presentation discusses a range of uncertainties - including hydrological variability, nuclear-reactivation, industrial demand recovery, policy adjustments and liquefaction project scheduling - that market participants may wish to consider when evaluating how procurement practices and spot-price dynamics could evolve in a supply-abundant LNG environment.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe presentation concludes by summarising how the combined analysis of demand fundamentals, evolving procurement practices and global supply conditions can provide a structured lens for interpreting Asian participation in the spot LNG market.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EGlobal LNG market re\u2011pricing: How shifts in Brent, JKM, HH and TTF benchmarks are reshaping contracting and trading dynamics in 2026\u0026nbsp;\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EKenneth Foo, Global Director - LNG Pricing, S\u0026amp;P Global Energy\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EGlobal LNG markets are entering a decisive re-pricing phase in 2026 as Brent, JKM, Henry Hub and TTF shift in ways that are rapidly reshaping contracting behaviour, trading strategies and portfolio economics. After 18 months of stabilising spot prices and renewed liquidity, benchmark movements are now driving the fastest restructuring of price relationships and indexation preferences seen in over a decade.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EBrent\u2019s sharp decline remains the most influential driver. With Brent expected to average around $59/b, long-term oil-indexed LNG under typical 12\u201313% slopes lands near $7.2\u20138/MMBtu\u2014comfortably below the expected JKM average of roughly $9/MMBtu. This discount is pushing buyers to maximise contractual offtake, often stretching upward quantity tolerances, while sellers compete harder on non-price terms. Destination flexibility, diversion rights and cancellation provisions are no longer negotiation add-ons but central levers in retaining demand.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EJKM continues to shape short-term pricing in Asia despite easing on new supply additions. Its premium over Brent-linked LNG has tightened cash differentials, making transparency between physical cargo values and monthly index averages increasingly important. Traders are responding by scaling up the use of BalMo structures, EFPs, TAS and LNG options to hedge spreads between gas and oil-linked benchmarks.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EHenry Hub has delivered the year\u0027s most disruptive price signals. A winter surge sent HH futures above $7/MMBtu, flipping US LNG netbacks into negative territory and triggering a wave of cargo cancellations. Feedgas flows to key Gulf Coast plants collapsed from near 20 Bcf/d to around 11 Bcf/d, revealing structural weaknesses in HH-indexed FOB deals\u2014particularly those with high fixed constants, rigid notice periods and limited operational flexibility. The episode has accelerated interest in adding caps, collars and dual trigger review mechanisms to future HH-linked contracts.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003ETTF remains the anchoring benchmark for Atlantic Basin LNG even as European fundamentals improve. TTF\u2019s persistent premium to both JKM and NWE LNG keeps more supply in Europe and supports a deeper Atlantic-based swap market.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EVolatility patterns across benchmarks are reshaping risk management. Brent retains the lowest volatility and remains the cross-commodity stabiliser. JKM and TTF, after extreme swings in 2022, have moderated but still require active hedge management. HH, historically less volatile, now exhibits sharp, event-driven spikes tied to weather, pipeline constraints and feedgas disruptions\u2014exactly the environments that force rapid reassessment of optionality and contract economics.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThese benchmark dynamics are driving a shift toward hybrid index portfolios. Brent\u2019s affordability supports a revival of oil-linked structures, while JKM and TTF remain essential for exposure calibration and downstream alignment. HH continues to offer value but requires redesigned contracts and stronger risk sharing.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EAs 2026 unfolds, LNG markets are defined by the tightest convergence between spot, oil-indexed and gas hub-linked pricing in more than a decade. The winners will be those who leverage flexible SPAs, hybrid indexation and fast cycle derivatives to capture value in a rapidly re-pricing global LNG landscape.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E//\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003E\u003Cstrong\u003EForecasting international ethane trade: Will US exports growth continue?\u003C/strong\u003E\u003C/p\u003E\u003Cp\u003EEmmanuel Grand, Senior MD, FTI Consulting\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EEthane is primarily used in the petrochemicals industry, to produce ethylene-derived plastics. The sustained cost advantage of ethane compared to naphtha as a feedstock for ethylene has led to an increase of global ethane cracker production capacity from 48 mtpa in 2016 to about 89 mtpa by 2025 (6% p.a.), including the seaborne trade of ethane.\u0026nbsp;Investment activity has increased, with US exporters aiming to add about 11.8 mtpa of additional capacity over 2025-2026, set to reach about 21 mtpa of total export capacity.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThis ongoing growth in US seaborne ethane exports has attracted interest from market players. Recent actions by the US of applying export restrictions to China only to rescind it afterwards, has led to China pausing plans for new ethane crackers, and creating global uncertainties for future US exports. In this context of structural ethane competitiveness and short-term policy uncertainty, we developed long-term scenarios for ethane seaborne exports, to guide market players in their concrete investment decisions.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EWe developed a partial equilibrium model of the seaborne ethane market. The ethane supply curve is organised into a merit-order based on ethane recovery cost, while the demand curve is organised based on the willingness-to-pay netted back to the point of supply (i.e. netback).\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EAs seaborne ethane predominantly is supplied by the US, the ethane supply is developed from EIA scenarios. We estimate the quantity of ethane based on the technical ethane potential related to the natural gas liquids portion of the supply. We estimate the cost of ethane supply based on historic correlation of costs to the share of ethane in gas (cost of recovery).\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EEthane demand is derived from ethylene demand which in turn is derived from plastics demand growth based on the OECD Plastics Outlook. The future share of ethane in overall ethylene growth is derived from its long-term cost advantage compared to naphtha. Actual ethane demand is capped by the availability of ethane crackers.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EWe calculate regional ethylene prices based on correlation with oil prices, and EIA long-term forecasted regional oil prices. Based on the regional ethylene prices and historic cracking margins, we obtain the regional willingness-to-pay for ethane as a feedstock. These ethane prices are netted-back to the US to develop a demand curve priced on a US FOB basis.\u0026nbsp;\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EWe calculate the yearly equilibrium prices and volumes when the netback ethane price justifies the additional cost of recovery.\u0026nbsp;We run the equilibrium calculation from 2023 to 2050 for different EIA scenarios to set the different perspectives.\u0026nbsp;\u003C/p\u003E\u003Cp\u003E\u003Cbr\u003E\u003C/p\u003E\u003Cp\u003EThe model shows that in the medium term, seaborne trade is expected to grow 18% per annum from 2025 to 2030, but expected to slow down to 1% p.a. in the next decade, despite strong ethane demand potential. This is limited mainly by the supply side, with ethane recovery constraints from the US. This suggests a window of opportunity for investment in terminals and shipping before 2030, with a significant first mover advantage.\u0026nbsp;\u0026nbsp;\u003C/p\u003E",
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Upcoming sessions Tuesday, 15 September 2026
Tuesday, 15 September | 14:40 - 15:20
Japan Energy Theatre
Fuel choice under pressure: Utilities, resilience and Japan’s evolving power mix
Tuesday, 15 September | 14:45 - 15:30
Energy Impact Theatre
Trading the LNG market: Contracting, optionality and portfolio advantage
Tuesday, 15 September | 14:45 - 15:30
Electrification Theatre
Building the system backbone: Resilience, flexibility, and dispatchable power
Tuesday, 15 September | 14:45 - 15:30
Global Energy Regulators Forum
Regulating the dual system: Managing hydrocarbons while building the energy transition
Tuesday, 15 September | 15:00 - 15:45
Hydrogen Theatre
Aligning policy, investment, and technological innovation to unlock renewable gas market growth
Tuesday, 15 September | 15:00 - 16:30
Low Carbon Solutions Theatre
CO₂ liquefaction
Tuesday, 15 September | 15:00 - 16:30
EPC & Gas Processing Theatre
Layout & construction optimisation
Tuesday, 15 September | 15:00 - 16:30
Shipping & Marine Theatre
Hydrogen shipping & bunkering
Gastech at a glance
Conferences
Driving the global energy agenda at a defining moment
Gastech’s conferences are central to the global energy dialogue, convening policymakers, CEOs, and industry experts to move from ambition to execution.
Across 200 sessions and 15 programmes, gain insights into forces shaping the industry, from energy security to decarbonisation.
Gastech Exhibition
Connect with leading energy suppliers and technology providers
Explore solutions from global energy companies representing the entire energy value chain.
Meet leading suppliers and technology providers, discover innovations that improve efficiency and sustainability, and build connections that support your business priorities.
Industry areas
Natural Gas & LNG
Powering progress with natural gas and LNG.
Low Carbon Solutions
Accelerating decarbonisation technologies for a lower carbon future
Hydrogen
Amplifying hydrogen's role in a balanced energy future
Shipping & Marine
Charting a course for cleaner, smarter maritime trade
Electrification
Powering the age of electrification and driving economic growth.
AixEnergy
Where AI, energy, and infrastructure meet
More Ways to Get Involved
Gastech Energy Club
An invitation-only network where global energy leaders align on critical decisions, accelerate partnerships, and drive energy security at scale.
Future Leaders programme
Future Leaders Programme is a four-day experience for early-career energy professionals, building key knowledge, insights, and connections.
Japan Energy
Japan Energy at Gastech is an opportunity to engage onsite with leading stakeholders from across the world’s fifth largest energy market, and its key regional and international partners.
Join the global energy industry in Bangkok
Join global energy professionals and leading companies at Gastech. Discover new technologies, identify commercial opportunities and build valuable connections across the exhibition, or access strategic insights, expert-led discussions and high-level networking as a conference delegate.
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