TECHNICAL PROGRAMME | Energy Infrastructure – Future Pathways
Navigating the Future: Innovations & Market Dynamics in LNG, FLNG, & CNG
Forum 7 | Digital Poster Plaza 2
27
April
15:30
17:30
UTC+3
This session aims to explore the evolving landscape of natural gas, focusing on the future prospects of LNG, FLNG, and CNG technologies. As the global energy market shifts towards cleaner alternatives, natural gas is poised to play a pivotal role in the energy transition. The session will bring together discussions on the latest technological advancements, market opportunities, and challenges in the LNG, FLNG, and CNG sectors.
Closed two-phase hydrocarbon storage tank with great storage capacity and long storage time is faced with the continually evaporation of liquid, which result in the increasing of vessel pressure and liquid hydrocarbon waste. In order to improve the performance of storage tank and estimate the Boil-off Gas (BOG), accurate and efficient method is in demand. A novel dynamic numerical method has been derived to model the effects of non-ideal thermodynamic behaviors, mass and energy transfer on hydrodynamics and vice versa using CFD methods in non-isothermal multiphase flow. Mass and energy transfer during condensation and vaporization were modeled by chemical potential at the liquid–vapor interface. Mass transfers were related to the diffusion at the interface and concentration gradients at the interface. A finite volume scheme is used to solve the equations of motion. Since the thermodynamic non-ideality of the system has been taken into account, the equilibrium calculations have been performed using the fugacity coefficient definition for both the liquid and gas phases. The equilibrium calculations were done using U-P flash calculation. The obtained results and their comparison against experimental data show that the proposed model can estimate boil-off rate and rollover in closed two-phase hydrocarbon storage tank (error for BOR estimation is less than 4%). Finally, the proposed approach is valid option to simulate the behavior of industrial scale closed liquified Natural Gas (LNG) storage tank.
This paper focuses on the efficient and comprehensive development of associated helium resources in natural gas. An integrated experimental device for combined helium gas and liquid production was developed, and its performance was tested. The helium extraction system employs cryogenic purification and high-efficiency deneonization technology, achieving a product helium purity of 99.999%. The helium liquefaction system innovatively adopts a two-stage turbine expansion refrigeration cycle combining full dynamic and dynamic-static pressure processes. The measured isentropic efficiency of the turbine reached 65%, and the system’s coefficient of performance (COP) was no less than 0.002. Test results demonstrate that the unit operates stably and meets all design specifications, enabling continuous co-production of high-purity liquid helium from raw feed gas. This provides an effective engineering solution for technological advancement and high-value utilization of helium resources in the natural gas helium extraction industry.
As global energy systems transition toward lower carbon intensity, LNG remains a strategic enabler for delivering cleaner energy—particularly in archipelagic nations like Indonesia. This case study highlights Indonesia’s first Floating Storage Regasification Unit (FSRU), which plays a crucial role in ensuring secure, flexible, and sustainable energy supply for the national power grid.
Located offshore Jakarta, the FSRU terminal regasifies LNG for power plant consumption while managing increasing operational complexities, including fluctuating demand, multiple LNG suppliers, and co-mingled cargoes. Structured operational excellence programs have been implemented, including robust frameworks for process safety, reliability engineering, and performance monitoring to ensure uninterrupted gas delivery.
This abstract outlines the strategic approach and innovative practices applied to maintain operational reliability. It explores key challenges and the corresponding solutions, including the adoption of digital transformation, workforce upskilling, and adherence to evolving regulatory requirements. The use of digital tools—such as real-time analytics, predictive maintenance, and remote monitoring—has strengthened operational agility and enhanced resilience against disruptions stemming from geopolitical events, extreme weather, or market volatility.
Aligned with Indonesia’s roadmap toward Net Zero Emissions (NZE) by 2060 and the United Nations Sustainable Development Goals (SDGs), the FSRU infrastructure supports clean energy access (SDG 7), resilient infrastructure (SDG 9), and climate action (SDG 13). By maintaining high operational standards and fostering collaboration across stakeholders, this model offers a scalable approach to LNG midstream operations that supports both national development and global sustainability objectives.
This case provides practical insights into how operational excellence in LNG infrastructure can enable a reliable and resilient transitional pathway in the evolving global energy landscape.
Located offshore Jakarta, the FSRU terminal regasifies LNG for power plant consumption while managing increasing operational complexities, including fluctuating demand, multiple LNG suppliers, and co-mingled cargoes. Structured operational excellence programs have been implemented, including robust frameworks for process safety, reliability engineering, and performance monitoring to ensure uninterrupted gas delivery.
This abstract outlines the strategic approach and innovative practices applied to maintain operational reliability. It explores key challenges and the corresponding solutions, including the adoption of digital transformation, workforce upskilling, and adherence to evolving regulatory requirements. The use of digital tools—such as real-time analytics, predictive maintenance, and remote monitoring—has strengthened operational agility and enhanced resilience against disruptions stemming from geopolitical events, extreme weather, or market volatility.
Aligned with Indonesia’s roadmap toward Net Zero Emissions (NZE) by 2060 and the United Nations Sustainable Development Goals (SDGs), the FSRU infrastructure supports clean energy access (SDG 7), resilient infrastructure (SDG 9), and climate action (SDG 13). By maintaining high operational standards and fostering collaboration across stakeholders, this model offers a scalable approach to LNG midstream operations that supports both national development and global sustainability objectives.
This case provides practical insights into how operational excellence in LNG infrastructure can enable a reliable and resilient transitional pathway in the evolving global energy landscape.
The presented research work is devoted to the comparative analysis of adsorbents used for drying natural gas in the production of liquefied natural gas (LNG). Both commercially available adsorbents produced in Russia and leading global equivalents from BASF are considered. The main objective of the research is to determine the most suitable types of adsorbents for industrial use, identifying their strengths and weaknesses by studying their physicochemical characteristics, pore structure, and adsorption properties.
The issue of effective gas drying becomes especially significant due to the increasing demand for LNG, driven by the energy transition and environmental requirements. Deep adsorption drying is necessary to prevent equipment corrosion, hydrate formation, and to enhance the overall efficiency of production. Improving drying methods and using highly efficient adsorbents contribute to increased reliability and reduced costs in LNG production.
Using modern scientific approaches and laboratory equipment, the main characteristics of adsorbents necessary for assessing their suitability for use in real production processes were investigated.
Patterns of the influence of chemical composition, pore size, and thermal regimes on the ability of adsorbents to retain moisture and remove it from natural gas were identified.
One of the most important conclusions of the study is the confirmation of the competitiveness of adsorbents produced in Russia compared to foreign analogs, in some cases demonstrating better performance.
The results obtained are of significant interest to the scientific community, engineering technologists, and managers of enterprises involved in LNG production, as they provide a scientific basis for the modernization of existing facilities and the design of new complexes.
The issue of effective gas drying becomes especially significant due to the increasing demand for LNG, driven by the energy transition and environmental requirements. Deep adsorption drying is necessary to prevent equipment corrosion, hydrate formation, and to enhance the overall efficiency of production. Improving drying methods and using highly efficient adsorbents contribute to increased reliability and reduced costs in LNG production.
Using modern scientific approaches and laboratory equipment, the main characteristics of adsorbents necessary for assessing their suitability for use in real production processes were investigated.
Patterns of the influence of chemical composition, pore size, and thermal regimes on the ability of adsorbents to retain moisture and remove it from natural gas were identified.
One of the most important conclusions of the study is the confirmation of the competitiveness of adsorbents produced in Russia compared to foreign analogs, in some cases demonstrating better performance.
The results obtained are of significant interest to the scientific community, engineering technologists, and managers of enterprises involved in LNG production, as they provide a scientific basis for the modernization of existing facilities and the design of new complexes.
The South China Sea is rich in natural gas resources, but its complex marine environment—including frequent typhoons, massive internal wave currents, and severe sea conditions—poses unprecedented challenges to the design, mooring, operation, and maintenance of Floating Liquefied Natural Gas (FLNG) facilities. This paper aims to provide a systematic review of the core challenges and cutting-edge innovations in FLNG technology under the harsh sea conditions of the South China Sea. The study begins with an in-depth analysis of the unique environmental loads in the region and their extreme demands on FLNG systems, focusing on key issues such as the selection of process schemes under sloshing conditions and the uniform distribution of heat exchangers, vessel design and mooring system solutions adapted to deep-water ultra-strong winds and currents, LNG loading and offloading challenges, and integrated real-time monitoring and AI-driven predictive maintenance systems. Finally, the paper discusses strategies for balancing economic viability and safety in South China Sea FLNG projects and explores the application prospects of digital twin technology and renewable energy integration in enhancing the sustainability of FLNG operations in the region. This research aims to provide technical references and decision-making support for the safe and economical development of FLNG projects in the South China Sea and other similarly harsh marine environments.
The four West African countries member of OMVG organization: Senegal, The Gambia, Guinea-Bissau and Guinea face severe slow-down of their economic development due to the severe limitation of the available electricity. This also represent a major challenge for daily life of the citizens and an obstacle against general development. The severe limitations were addressed by temporary solutions which proved to be expensive, less clean that necessary in our modern world and definitely not sufficient, like a powership of 35 MW.
The OMVG project is a 226KV transmission line within the West African Power Pool that connects the four member states and forms a critical project in the implementation roadmap of the power pool infrastructure.
The LNG terminal will be modular (possibly an FSRU – floating storage and regasification unit, or onshore tanks + evaporators), initially sized to provide the fuel needed for the plant and serve other industrial consumers. The liquefied gas will be imported by sea and stored/re-gasified at the terminal, then transported to the power plant via a short pipeline. Industrial LNG distribution will be achieved either by expanding a local gas network or by a "virtual pipeline" – i.e. delivering LNG with ISO cryogenic tankers to large industry consumers, who will re-gasify it at its destination. This flexible approach ensures the supply of gas to off-grid units such as factories, mining or transport, helping to replace diesel and butane with a cleaner, cheaper fuel available through long-term supply contracts.
Taking the example of one of the countries with the most serious electricity supply problem, the project will provide Guinea-Bissau with a reliable source of electricity and fuel: the 60 MW plant almost doubles the available capacity compared to the current level (~30–35 MW needed in Bissau), covering current demand and future increases. This will reduce dependence on fuel oil imports and unpredictable and seasonal hydropower, aligning with governments' strategy to reduce dependence on diesel and increase access to modern energy. Natural gas also has lower CO₂ emissions and local pollutants than the fuels currently used, contributing to climate and environmental goals. The importance of the gas transition in the regional energy mix is already recognised – for example, the first floating LNG plant recently came into operation in Senegal, marking a turning point in West Africa's energy transition.
The Bissau LNG project would position Guinea-Bissau as a pioneer in the region in the adoption of natural gas for energy production and industrial fuel, while catalyzing economic development (reliable energy for industry, possibility of boosting mining projects, cement, agri-food processing, etc.).
Selected bibliography:
Hannah Ritchie and Max Roser (2020) - "Energy". Published online at OurWorldInData.org. Retrieved from: https://ourworldindata.org/energy
IEA Statistics Report (2021) - “Natural Gas Overview: Information”. Published online from: https://www.iea.org/reports/natural-gas-information-overview
Co-author/s:
Teodor Ovidiu Tender, President, Tender Oil & Gas.
Alexandru Boscaneanu, General Director, Prospectiuni.
Dr. Jean Gorie, Guest Professor, University of Bucharest
The OMVG project is a 226KV transmission line within the West African Power Pool that connects the four member states and forms a critical project in the implementation roadmap of the power pool infrastructure.
The LNG terminal will be modular (possibly an FSRU – floating storage and regasification unit, or onshore tanks + evaporators), initially sized to provide the fuel needed for the plant and serve other industrial consumers. The liquefied gas will be imported by sea and stored/re-gasified at the terminal, then transported to the power plant via a short pipeline. Industrial LNG distribution will be achieved either by expanding a local gas network or by a "virtual pipeline" – i.e. delivering LNG with ISO cryogenic tankers to large industry consumers, who will re-gasify it at its destination. This flexible approach ensures the supply of gas to off-grid units such as factories, mining or transport, helping to replace diesel and butane with a cleaner, cheaper fuel available through long-term supply contracts.
Taking the example of one of the countries with the most serious electricity supply problem, the project will provide Guinea-Bissau with a reliable source of electricity and fuel: the 60 MW plant almost doubles the available capacity compared to the current level (~30–35 MW needed in Bissau), covering current demand and future increases. This will reduce dependence on fuel oil imports and unpredictable and seasonal hydropower, aligning with governments' strategy to reduce dependence on diesel and increase access to modern energy. Natural gas also has lower CO₂ emissions and local pollutants than the fuels currently used, contributing to climate and environmental goals. The importance of the gas transition in the regional energy mix is already recognised – for example, the first floating LNG plant recently came into operation in Senegal, marking a turning point in West Africa's energy transition.
The Bissau LNG project would position Guinea-Bissau as a pioneer in the region in the adoption of natural gas for energy production and industrial fuel, while catalyzing economic development (reliable energy for industry, possibility of boosting mining projects, cement, agri-food processing, etc.).
Selected bibliography:
Hannah Ritchie and Max Roser (2020) - "Energy". Published online at OurWorldInData.org. Retrieved from: https://ourworldindata.org/energy
IEA Statistics Report (2021) - “Natural Gas Overview: Information”. Published online from: https://www.iea.org/reports/natural-gas-information-overview
Co-author/s:
Teodor Ovidiu Tender, President, Tender Oil & Gas.
Alexandru Boscaneanu, General Director, Prospectiuni.
Dr. Jean Gorie, Guest Professor, University of Bucharest
Global LNG trade exceeded ~ 390 Mt in 2022 and is poised to grow as Qatar’s North Field East and additional U.S. Gulf Coast trains ramp before 2026. Accurate, transparent freight costing is therefore critical for investment screening, cargo arbitrage, and carbon-levy design. We present PEARL-LNG-RO (Predictive Econometric and Route Logistics—Routing Optimizer) —an open, voyage-level framework that couples AIS-derived tracks with vessel-specification databases and contemporaneous bunker, charter, canal, and port tariffs in a single techno-economic engine, augmented with a linear-programming assignment that minimizes the global spot-trade freight cost under terminal-level supply-demand and LNG density constraints.
For each round trip (laden and ballast), PEARL-LNG-RO solves interconnected boil-off, heel management, and propulsion equations across five engine families (Steam, DFDE, X-DF, ME-GI, and STaGE), allocates fuel between main and auxiliary, and prices consumption using monthly HFO/ MDO and LNG indices (Brent, TTF, Henry Hub, and JKM). The 2022 calibration covers 5,642 laden voyages (≈ 370 Mt delivered) linking ~1,200 export–import pairs. The volume-weighted mean port-to-port freight is $ 2.49/MMBtu (5th–95th percentile: $ 0.59–6.88/MMBtu), with cost shares: charter 64%, fuel 25%, ports 5.1%, operations 5.6%, and canals 1.3%. Route contrasts are large: US Gulf Coast to Northeast Asia via Panama averages 4.76 USD/MMBtu, whereas Intra-Mediterranean averages 1.84 USD MMBtu⁻¹ both including charter.
Applying the optimization to observed spot voyages (N = 1,647; ~104 Mt) reduces the energy-weighted average freight from $2.86 to $1.66/MMBtu (−42%) by reallocating flows among feasible terminal pairs within lean/rich density classes. This provides a quantitative upper bound on savings available from coordinated charter strategy and routing, subject to real-world constraints (contracts, berthing windows, boil-off limits). From our companion Global LNG supply chain analysis, route/engine heterogeneity yields 0.80–1.9 g CO₂e/MJ. Under an output-based levy at $100/t-CO₂, the incremental cost adds ≈$0.50/MMBtu to typical voyages.
The open-source codebase and calibrated dataset enable voyage-level benchmarking and charter-strategy optimization when paired with life-cycle emissions assessment from our companion study; they can inform cost-and carbon-aware routing decisions across trading basins.
For each round trip (laden and ballast), PEARL-LNG-RO solves interconnected boil-off, heel management, and propulsion equations across five engine families (Steam, DFDE, X-DF, ME-GI, and STaGE), allocates fuel between main and auxiliary, and prices consumption using monthly HFO/ MDO and LNG indices (Brent, TTF, Henry Hub, and JKM). The 2022 calibration covers 5,642 laden voyages (≈ 370 Mt delivered) linking ~1,200 export–import pairs. The volume-weighted mean port-to-port freight is $ 2.49/MMBtu (5th–95th percentile: $ 0.59–6.88/MMBtu), with cost shares: charter 64%, fuel 25%, ports 5.1%, operations 5.6%, and canals 1.3%. Route contrasts are large: US Gulf Coast to Northeast Asia via Panama averages 4.76 USD/MMBtu, whereas Intra-Mediterranean averages 1.84 USD MMBtu⁻¹ both including charter.
Applying the optimization to observed spot voyages (N = 1,647; ~104 Mt) reduces the energy-weighted average freight from $2.86 to $1.66/MMBtu (−42%) by reallocating flows among feasible terminal pairs within lean/rich density classes. This provides a quantitative upper bound on savings available from coordinated charter strategy and routing, subject to real-world constraints (contracts, berthing windows, boil-off limits). From our companion Global LNG supply chain analysis, route/engine heterogeneity yields 0.80–1.9 g CO₂e/MJ. Under an output-based levy at $100/t-CO₂, the incremental cost adds ≈$0.50/MMBtu to typical voyages.
The open-source codebase and calibrated dataset enable voyage-level benchmarking and charter-strategy optimization when paired with life-cycle emissions assessment from our companion study; they can inform cost-and carbon-aware routing decisions across trading basins.
Elena Fedorova
Chair
Head of Department
National University of Oil and Gas - Gubkin University - Russia
Gholamali Rahimi
Vice Chair
Faculty Member and Head of the Energy Economic Department, Institute for International Energy Studies
Ministry of Petroleum
Tongwen Shan
Vice Chair
General Manager, Science & Information Technology Department
China National Offshore Oil Corporation
Hao Cheng
Speaker
Head of Liquid Technology Institute
CNOOC Gas & Power Group Co., Ltd.
This paper focuses on the efficient and comprehensive development of associated helium resources in natural gas. An integrated experimental device for combined helium gas and liquid production was developed, and its performance was tested. The helium extraction system employs cryogenic purification and high-efficiency deneonization technology, achieving a product helium purity of 99.999%. The helium liquefaction system innovatively adopts a two-stage turbine expansion refrigeration cycle combining full dynamic and dynamic-static pressure processes. The measured isentropic efficiency of the turbine reached 65%, and the system’s coefficient of performance (COP) was no less than 0.002. Test results demonstrate that the unit operates stably and meets all design specifications, enabling continuous co-production of high-purity liquid helium from raw feed gas. This provides an effective engineering solution for technological advancement and high-value utilization of helium resources in the natural gas helium extraction industry.
Eliza Gafarova
Speaker
Associate Professor of the Department of Oil and Gas Processing Equipment
National University of Oil and Gas (Gubkin University)
The presented research work is devoted to the comparative analysis of adsorbents used for drying natural gas in the production of liquefied natural gas (LNG). Both commercially available adsorbents produced in Russia and leading global equivalents from BASF are considered. The main objective of the research is to determine the most suitable types of adsorbents for industrial use, identifying their strengths and weaknesses by studying their physicochemical characteristics, pore structure, and adsorption properties.
The issue of effective gas drying becomes especially significant due to the increasing demand for LNG, driven by the energy transition and environmental requirements. Deep adsorption drying is necessary to prevent equipment corrosion, hydrate formation, and to enhance the overall efficiency of production. Improving drying methods and using highly efficient adsorbents contribute to increased reliability and reduced costs in LNG production.
Using modern scientific approaches and laboratory equipment, the main characteristics of adsorbents necessary for assessing their suitability for use in real production processes were investigated.
Patterns of the influence of chemical composition, pore size, and thermal regimes on the ability of adsorbents to retain moisture and remove it from natural gas were identified.
One of the most important conclusions of the study is the confirmation of the competitiveness of adsorbents produced in Russia compared to foreign analogs, in some cases demonstrating better performance.
The results obtained are of significant interest to the scientific community, engineering technologists, and managers of enterprises involved in LNG production, as they provide a scientific basis for the modernization of existing facilities and the design of new complexes.
The issue of effective gas drying becomes especially significant due to the increasing demand for LNG, driven by the energy transition and environmental requirements. Deep adsorption drying is necessary to prevent equipment corrosion, hydrate formation, and to enhance the overall efficiency of production. Improving drying methods and using highly efficient adsorbents contribute to increased reliability and reduced costs in LNG production.
Using modern scientific approaches and laboratory equipment, the main characteristics of adsorbents necessary for assessing their suitability for use in real production processes were investigated.
Patterns of the influence of chemical composition, pore size, and thermal regimes on the ability of adsorbents to retain moisture and remove it from natural gas were identified.
One of the most important conclusions of the study is the confirmation of the competitiveness of adsorbents produced in Russia compared to foreign analogs, in some cases demonstrating better performance.
The results obtained are of significant interest to the scientific community, engineering technologists, and managers of enterprises involved in LNG production, as they provide a scientific basis for the modernization of existing facilities and the design of new complexes.
Closed two-phase hydrocarbon storage tank with great storage capacity and long storage time is faced with the continually evaporation of liquid, which result in the increasing of vessel pressure and liquid hydrocarbon waste. In order to improve the performance of storage tank and estimate the Boil-off Gas (BOG), accurate and efficient method is in demand. A novel dynamic numerical method has been derived to model the effects of non-ideal thermodynamic behaviors, mass and energy transfer on hydrodynamics and vice versa using CFD methods in non-isothermal multiphase flow. Mass and energy transfer during condensation and vaporization were modeled by chemical potential at the liquid–vapor interface. Mass transfers were related to the diffusion at the interface and concentration gradients at the interface. A finite volume scheme is used to solve the equations of motion. Since the thermodynamic non-ideality of the system has been taken into account, the equilibrium calculations have been performed using the fugacity coefficient definition for both the liquid and gas phases. The equilibrium calculations were done using U-P flash calculation. The obtained results and their comparison against experimental data show that the proposed model can estimate boil-off rate and rollover in closed two-phase hydrocarbon storage tank (error for BOR estimation is less than 4%). Finally, the proposed approach is valid option to simulate the behavior of industrial scale closed liquified Natural Gas (LNG) storage tank.
Global LNG trade exceeded ~ 390 Mt in 2022 and is poised to grow as Qatar’s North Field East and additional U.S. Gulf Coast trains ramp before 2026. Accurate, transparent freight costing is therefore critical for investment screening, cargo arbitrage, and carbon-levy design. We present PEARL-LNG-RO (Predictive Econometric and Route Logistics—Routing Optimizer) —an open, voyage-level framework that couples AIS-derived tracks with vessel-specification databases and contemporaneous bunker, charter, canal, and port tariffs in a single techno-economic engine, augmented with a linear-programming assignment that minimizes the global spot-trade freight cost under terminal-level supply-demand and LNG density constraints.
For each round trip (laden and ballast), PEARL-LNG-RO solves interconnected boil-off, heel management, and propulsion equations across five engine families (Steam, DFDE, X-DF, ME-GI, and STaGE), allocates fuel between main and auxiliary, and prices consumption using monthly HFO/ MDO and LNG indices (Brent, TTF, Henry Hub, and JKM). The 2022 calibration covers 5,642 laden voyages (≈ 370 Mt delivered) linking ~1,200 export–import pairs. The volume-weighted mean port-to-port freight is $ 2.49/MMBtu (5th–95th percentile: $ 0.59–6.88/MMBtu), with cost shares: charter 64%, fuel 25%, ports 5.1%, operations 5.6%, and canals 1.3%. Route contrasts are large: US Gulf Coast to Northeast Asia via Panama averages 4.76 USD/MMBtu, whereas Intra-Mediterranean averages 1.84 USD MMBtu⁻¹ both including charter.
Applying the optimization to observed spot voyages (N = 1,647; ~104 Mt) reduces the energy-weighted average freight from $2.86 to $1.66/MMBtu (−42%) by reallocating flows among feasible terminal pairs within lean/rich density classes. This provides a quantitative upper bound on savings available from coordinated charter strategy and routing, subject to real-world constraints (contracts, berthing windows, boil-off limits). From our companion Global LNG supply chain analysis, route/engine heterogeneity yields 0.80–1.9 g CO₂e/MJ. Under an output-based levy at $100/t-CO₂, the incremental cost adds ≈$0.50/MMBtu to typical voyages.
The open-source codebase and calibrated dataset enable voyage-level benchmarking and charter-strategy optimization when paired with life-cycle emissions assessment from our companion study; they can inform cost-and carbon-aware routing decisions across trading basins.
For each round trip (laden and ballast), PEARL-LNG-RO solves interconnected boil-off, heel management, and propulsion equations across five engine families (Steam, DFDE, X-DF, ME-GI, and STaGE), allocates fuel between main and auxiliary, and prices consumption using monthly HFO/ MDO and LNG indices (Brent, TTF, Henry Hub, and JKM). The 2022 calibration covers 5,642 laden voyages (≈ 370 Mt delivered) linking ~1,200 export–import pairs. The volume-weighted mean port-to-port freight is $ 2.49/MMBtu (5th–95th percentile: $ 0.59–6.88/MMBtu), with cost shares: charter 64%, fuel 25%, ports 5.1%, operations 5.6%, and canals 1.3%. Route contrasts are large: US Gulf Coast to Northeast Asia via Panama averages 4.76 USD/MMBtu, whereas Intra-Mediterranean averages 1.84 USD MMBtu⁻¹ both including charter.
Applying the optimization to observed spot voyages (N = 1,647; ~104 Mt) reduces the energy-weighted average freight from $2.86 to $1.66/MMBtu (−42%) by reallocating flows among feasible terminal pairs within lean/rich density classes. This provides a quantitative upper bound on savings available from coordinated charter strategy and routing, subject to real-world constraints (contracts, berthing windows, boil-off limits). From our companion Global LNG supply chain analysis, route/engine heterogeneity yields 0.80–1.9 g CO₂e/MJ. Under an output-based levy at $100/t-CO₂, the incremental cost adds ≈$0.50/MMBtu to typical voyages.
The open-source codebase and calibrated dataset enable voyage-level benchmarking and charter-strategy optimization when paired with life-cycle emissions assessment from our companion study; they can inform cost-and carbon-aware routing decisions across trading basins.
The South China Sea is rich in natural gas resources, but its complex marine environment—including frequent typhoons, massive internal wave currents, and severe sea conditions—poses unprecedented challenges to the design, mooring, operation, and maintenance of Floating Liquefied Natural Gas (FLNG) facilities. This paper aims to provide a systematic review of the core challenges and cutting-edge innovations in FLNG technology under the harsh sea conditions of the South China Sea. The study begins with an in-depth analysis of the unique environmental loads in the region and their extreme demands on FLNG systems, focusing on key issues such as the selection of process schemes under sloshing conditions and the uniform distribution of heat exchangers, vessel design and mooring system solutions adapted to deep-water ultra-strong winds and currents, LNG loading and offloading challenges, and integrated real-time monitoring and AI-driven predictive maintenance systems. Finally, the paper discusses strategies for balancing economic viability and safety in South China Sea FLNG projects and explores the application prospects of digital twin technology and renewable energy integration in enhancing the sustainability of FLNG operations in the region. This research aims to provide technical references and decision-making support for the safe and economical development of FLNG projects in the South China Sea and other similarly harsh marine environments.
The four West African countries member of OMVG organization: Senegal, The Gambia, Guinea-Bissau and Guinea face severe slow-down of their economic development due to the severe limitation of the available electricity. This also represent a major challenge for daily life of the citizens and an obstacle against general development. The severe limitations were addressed by temporary solutions which proved to be expensive, less clean that necessary in our modern world and definitely not sufficient, like a powership of 35 MW.
The OMVG project is a 226KV transmission line within the West African Power Pool that connects the four member states and forms a critical project in the implementation roadmap of the power pool infrastructure.
The LNG terminal will be modular (possibly an FSRU – floating storage and regasification unit, or onshore tanks + evaporators), initially sized to provide the fuel needed for the plant and serve other industrial consumers. The liquefied gas will be imported by sea and stored/re-gasified at the terminal, then transported to the power plant via a short pipeline. Industrial LNG distribution will be achieved either by expanding a local gas network or by a "virtual pipeline" – i.e. delivering LNG with ISO cryogenic tankers to large industry consumers, who will re-gasify it at its destination. This flexible approach ensures the supply of gas to off-grid units such as factories, mining or transport, helping to replace diesel and butane with a cleaner, cheaper fuel available through long-term supply contracts.
Taking the example of one of the countries with the most serious electricity supply problem, the project will provide Guinea-Bissau with a reliable source of electricity and fuel: the 60 MW plant almost doubles the available capacity compared to the current level (~30–35 MW needed in Bissau), covering current demand and future increases. This will reduce dependence on fuel oil imports and unpredictable and seasonal hydropower, aligning with governments' strategy to reduce dependence on diesel and increase access to modern energy. Natural gas also has lower CO₂ emissions and local pollutants than the fuels currently used, contributing to climate and environmental goals. The importance of the gas transition in the regional energy mix is already recognised – for example, the first floating LNG plant recently came into operation in Senegal, marking a turning point in West Africa's energy transition.
The Bissau LNG project would position Guinea-Bissau as a pioneer in the region in the adoption of natural gas for energy production and industrial fuel, while catalyzing economic development (reliable energy for industry, possibility of boosting mining projects, cement, agri-food processing, etc.).
Selected bibliography:
Hannah Ritchie and Max Roser (2020) - "Energy". Published online at OurWorldInData.org. Retrieved from: https://ourworldindata.org/energy
IEA Statistics Report (2021) - “Natural Gas Overview: Information”. Published online from: https://www.iea.org/reports/natural-gas-information-overview
Co-author/s:
Teodor Ovidiu Tender, President, Tender Oil & Gas.
Alexandru Boscaneanu, General Director, Prospectiuni.
Dr. Jean Gorie, Guest Professor, University of Bucharest
The OMVG project is a 226KV transmission line within the West African Power Pool that connects the four member states and forms a critical project in the implementation roadmap of the power pool infrastructure.
The LNG terminal will be modular (possibly an FSRU – floating storage and regasification unit, or onshore tanks + evaporators), initially sized to provide the fuel needed for the plant and serve other industrial consumers. The liquefied gas will be imported by sea and stored/re-gasified at the terminal, then transported to the power plant via a short pipeline. Industrial LNG distribution will be achieved either by expanding a local gas network or by a "virtual pipeline" – i.e. delivering LNG with ISO cryogenic tankers to large industry consumers, who will re-gasify it at its destination. This flexible approach ensures the supply of gas to off-grid units such as factories, mining or transport, helping to replace diesel and butane with a cleaner, cheaper fuel available through long-term supply contracts.
Taking the example of one of the countries with the most serious electricity supply problem, the project will provide Guinea-Bissau with a reliable source of electricity and fuel: the 60 MW plant almost doubles the available capacity compared to the current level (~30–35 MW needed in Bissau), covering current demand and future increases. This will reduce dependence on fuel oil imports and unpredictable and seasonal hydropower, aligning with governments' strategy to reduce dependence on diesel and increase access to modern energy. Natural gas also has lower CO₂ emissions and local pollutants than the fuels currently used, contributing to climate and environmental goals. The importance of the gas transition in the regional energy mix is already recognised – for example, the first floating LNG plant recently came into operation in Senegal, marking a turning point in West Africa's energy transition.
The Bissau LNG project would position Guinea-Bissau as a pioneer in the region in the adoption of natural gas for energy production and industrial fuel, while catalyzing economic development (reliable energy for industry, possibility of boosting mining projects, cement, agri-food processing, etc.).
Selected bibliography:
Hannah Ritchie and Max Roser (2020) - "Energy". Published online at OurWorldInData.org. Retrieved from: https://ourworldindata.org/energy
IEA Statistics Report (2021) - “Natural Gas Overview: Information”. Published online from: https://www.iea.org/reports/natural-gas-information-overview
Co-author/s:
Teodor Ovidiu Tender, President, Tender Oil & Gas.
Alexandru Boscaneanu, General Director, Prospectiuni.
Dr. Jean Gorie, Guest Professor, University of Bucharest
Yosep Ismail Zulkarnain
Speaker
Manager Gas Distribution & ORF Management Manager
PT Nusantara Regas
As global energy systems transition toward lower carbon intensity, LNG remains a strategic enabler for delivering cleaner energy—particularly in archipelagic nations like Indonesia. This case study highlights Indonesia’s first Floating Storage Regasification Unit (FSRU), which plays a crucial role in ensuring secure, flexible, and sustainable energy supply for the national power grid.
Located offshore Jakarta, the FSRU terminal regasifies LNG for power plant consumption while managing increasing operational complexities, including fluctuating demand, multiple LNG suppliers, and co-mingled cargoes. Structured operational excellence programs have been implemented, including robust frameworks for process safety, reliability engineering, and performance monitoring to ensure uninterrupted gas delivery.
This abstract outlines the strategic approach and innovative practices applied to maintain operational reliability. It explores key challenges and the corresponding solutions, including the adoption of digital transformation, workforce upskilling, and adherence to evolving regulatory requirements. The use of digital tools—such as real-time analytics, predictive maintenance, and remote monitoring—has strengthened operational agility and enhanced resilience against disruptions stemming from geopolitical events, extreme weather, or market volatility.
Aligned with Indonesia’s roadmap toward Net Zero Emissions (NZE) by 2060 and the United Nations Sustainable Development Goals (SDGs), the FSRU infrastructure supports clean energy access (SDG 7), resilient infrastructure (SDG 9), and climate action (SDG 13). By maintaining high operational standards and fostering collaboration across stakeholders, this model offers a scalable approach to LNG midstream operations that supports both national development and global sustainability objectives.
This case provides practical insights into how operational excellence in LNG infrastructure can enable a reliable and resilient transitional pathway in the evolving global energy landscape.
Located offshore Jakarta, the FSRU terminal regasifies LNG for power plant consumption while managing increasing operational complexities, including fluctuating demand, multiple LNG suppliers, and co-mingled cargoes. Structured operational excellence programs have been implemented, including robust frameworks for process safety, reliability engineering, and performance monitoring to ensure uninterrupted gas delivery.
This abstract outlines the strategic approach and innovative practices applied to maintain operational reliability. It explores key challenges and the corresponding solutions, including the adoption of digital transformation, workforce upskilling, and adherence to evolving regulatory requirements. The use of digital tools—such as real-time analytics, predictive maintenance, and remote monitoring—has strengthened operational agility and enhanced resilience against disruptions stemming from geopolitical events, extreme weather, or market volatility.
Aligned with Indonesia’s roadmap toward Net Zero Emissions (NZE) by 2060 and the United Nations Sustainable Development Goals (SDGs), the FSRU infrastructure supports clean energy access (SDG 7), resilient infrastructure (SDG 9), and climate action (SDG 13). By maintaining high operational standards and fostering collaboration across stakeholders, this model offers a scalable approach to LNG midstream operations that supports both national development and global sustainability objectives.
This case provides practical insights into how operational excellence in LNG infrastructure can enable a reliable and resilient transitional pathway in the evolving global energy landscape.
