The LNG maritime industry started to anticipate offshore LNG production in tandem with increasing demand for FLNG platforms as offshore gas resources were developed further. The rapid expansion of FLNG deployment demands equipment and procedures that handle challenges associated with weight and space constraints. The chemical composition of LNG will result in slightly fewer CO₂ emissions. While not significant, another crucial aspect is that LNG predominantly comprises methane, which is acknowledged as a greenhouse gas and is more harmful than CO₂. This requires investigation into clean energy fuel supply for power generation systems, carbon emissions from the process, and thermodynamic analysis and optimisation. Focus on supplying fuel for FLNG power generation to reduce the essential management of boil-off fuel gas, which can be researched on the direct reforming method of hydrogen as a marine fuel gas to support the power generation system. The principal reason for choosing hydrogen over other energy sources is its exceptional energy-to-mass ratio (H/C ratio). The most effective method for hydrogen production is the methane reforming process, recognised for generating significant quantities of hydrogen. To optimise the small-scale plant with a carbon capture system (CCS) as integrated into the reforming process to produce blue hydrogen fuel with zero carbon emissions, this research selection focuses on two alternative processes: steam methane reforming (SMR) and autothermal reforming (ATR). Furthermore, the research article will contribute to other floating production platforms, such as FPSOs and FSRUs, and will be committed to clean energy policies that mandate the support of green alternatives in substitution of hydrocarbon fuel utilisation.

Global carbon emissions are driving the maritime industry toward cleaner fuels, with LNG already established as a transitional option that reduces SOx, NOx, and particulate emissions relative to conventional marine fuels and in line with decarbonisation strategies. This research aimed to explore the transition of offshore and marine platforms from conventional marine fuels to cleaner alternatives, with liquefied natural gas (LNG) emerging as the principal transitional fuel. Subsequently, floating liquefied natural gas (FLNG) platforms are increasingly being deployed to harness offshore gas resources, yet they face critical challenges related to weight, space, and energy efficiency. The study proposes pathways for transitioning FLNG energy systems from LNG to zero-carbon fuels, such as hydrogen derived directly from LNG resources, to optimise fuel supply under the unique operational constraints of FLNG units. The work unifies the independent domains of pure-fuel and blending-fuel processes for LNG and hydrogen, viewed in the context of thermodynamic processes, to optimise hydrogen–LNG co-firing gas turbine performance and meet the base power line of 50 MW. Furthermore, the research article will contribute to the development of other floating production platforms, such as FPSOs and FSRUs. It will be committed to clean energy policies that mandate support for green alternatives to hydrocarbon fuels.

The LNG maritime industry started to anticipate offshore LNG production in tandem with increasing demand for FLNG platforms as offshore gas resources were developed further. The rapid expansion of FLNG deployment demands equipment and procedures that handle challenges associated with weight and space constraints. The chemical composition of LNG will result in slightly less CO2 emissions. While not significant, another crucial aspect is that LNG predominantly comprises methane, acknowledged as a greenhouse gas and is more harmful than CO2. This requires investigation into clean energy fuel supply for power generation systems, carbon emissions from the process, and thermodynamic analysis and optimization. Focus on supplying fuel for FLNG power generation to reduce the essential management of boil-off fuel gas, which can be researched on the direct reforming method of hydrogen as a marine fuel gas to support the power generation system. The principal reason for choosing hydrogen over other energy sources is its exceptional energy-to-mass ratio (H/C ratio). The most effective method for hydrogen production is the methane reforming process, which is recognized for generating significant quantities of hydrogen. To optimize the small-scale plant with a carbon capture system (CCS) as an integrated reforming process to produce green hydrogen fuel with zero carbon emissions, this research selection focuses on two alternative processes: steam methane reforming (SMR) and autothermal reforming (ATR). Furthermore, the research article will contribute to other floating production platforms, such as FPSOs and FSRUs, and will be committed to clean energy policies that mandate the support of green alternatives in substitution of hydrocarbon fuel utilization.

The transition to hydrogen-fueled gas turbines is vital for decarbonising power systems, especially in space- and weight-constrained applications such as offshore FLNG and FPSO. While hydrogen offers zero-carbon emissions at the point of use, its use in gas turbines faces technical challenges due to high flame speed, flammability limits, low energy density, and high flame temperature. These increase the risks of flashback and NOₓ formation, especially when retrofitting existing combustors. Developing hydrogen-ready combustors for both pure hydrogen and blends is an ongoing research area. This study investigates a can-type, annular gas turbine combustor for use with pure hydrogen and blends. Using CFD simulations in ANSYS Fluent, it analyses flow, flame, temperature, and stability across hydrogen ratios from 0% to 100%. The model employs RANS equations, a realizable k–ε turbulence model, non-premixed combustion, and species transport; thermal radiation is modelled with the P-1 method, and NOₓ with the Zeldovich mechanism. Results show hydrogen increases flame reactivity, shortens flame length, and enhances recirculation zones, maintaining stability at ~50% hydrogen. Higher fractions increase flame temperature and velocity, increasing the risk of flashback. Pure hydrogen produces compact, high-temperature flames that require advanced designs for stability. Model predictions match experimental and published data from NASA, Siemens SGT-800, GE LM6000, and Kawasaki, confirming credibility. This CFD assessment offers insights into hydrogen combustor design, supporting the move towards hydrogen-ready turbines and low-carbon offshore power generation.

The global increase in carbon emission is one factor in using clean fuels to minimise air pollution by avoiding fossil fuel usage in the marine sector. The current effort of changing the energy source to LNG fossil gas fuel was assumed to be the cleanest fuel due to lower carbon emission to ease the rapid growth of carbon emission. Recent development in the LNG market drives the shipyard industry to build the LNG offshore platform FLNG, which is like the LNG plant with no land base but offshore. The LNG marine industry forecasts that increasing demand for FLNG vessels will accelerate the de-velopment of gas resources, research work on the system process analysis and optimisation of the Liquefaction system. The rapid growth in equipment and processes of FLNG development is the response to weight and space limits challenges. This paper describes the optimisation process of LNG turboexpander technologies’ benefits based on the different pro-cesses. Since the Single Nitrogen Expander that less efficiency and irreversible losses, another consideration of the dual expander process models and comparison from the simple model to the complex expander process. This article will focus on the LNG liquefaction research process results and analyses the design and optimisation based on power consumption, LNG production and future research directions of FLNG. This research is to aid in a small-scale liquefaction process with a refrigerant cycle proposed in this study to meet these FLNG challenges. The research methodology is to study all models of the expander liquefaction process and analyse the differential pressure of natural gas entry to vary the temperature, heat flow, exergy, and enthalpy. The Aspen Plus and Hysys simulator used a state-of-the-art run simulation for processes for all models.