Regasification Units Research Articles

Теоретические основы оценки аэродинамического воздействия ветровых потоков на сооружения завода по подготовке и сжижению природного газа

Leaks (spills) of liquefied gases evaporate rapidly on the ground (water) and initially generate a cold plume of heavy vapors. The plume spreads fast downwind, heats up with time, and can become positively volatile in case the concentration of interest for the study (above the lower flammability limit) is reached; therefore, the plume can rise and transform into a vapor cloud. The plume or the vapor cloud can ignite in the flash form. Such situations are possible at liquefied natural gas production plants or regasification units where large amounts of explosive substances are handled involving changes in their aggregate state. The article analyses the significance of the wind impact on the facilities of natural gas liquefaction plants for regular operation and the potential consequences of emergencies. In order to assess the wind impact, the direct numerical modeling of the structure of local wind flows generated at the airflow around the plant facilities by vertical method is suggested. An example of numerical modeling for a natural gas liquefaction plant based on the modular constructions of the process line is provided.

A global heat flow topology for revealing the synergistic effects of heat transfer and thermal power conversion in large scale systems: Methodology and case study

In the processes of modeling, optimization, heat transfer analysis, and thermal power conversion analysis in large-scale complex systems, challenges are encountered regarding intricate design and optimization. In this paper, a global heat flow topology is proposed that reveals the synergistic effect of heat transfer and thermal power conversion in large-scale systems. The approach involves the construction of a heat flow topology, mathematical model development, analysis of specific parameters, and multi-objective optimization. It integrates various methods and tools, including heat flow topology, numerical simulation tool, entransy transfer analysis, global thermal resistances visualization, genetic algorithm (GA), and technique for order preference by similarity to ideal solution (TOPSIS). By using the LNG cold energy recovery and regasification process in floating storage and regasification units (FSRU) as a case study, the methodology provides a comprehensive understanding of the interactions and conversions between heat transfer and thermal power within the system. The results demonstrate that the optimal configuration achieves a maximum thermal efficiency of 21.73 % and a maximum cold recovery efficiency of 58.48 %. Additionally, the interaction between LNG pressure and seawater temperature exhibits limited synergistic impact on both LNG cold exergy efficiency and entransy transfer efficiency. Similarly, the combined influence of LNG pressure and evaporator temperature shows weak synergistic effects on parameters such as supply/demand ratio, thermal efficiency, and entransy transfer efficiency. The analysis of the global thermal resistance bubble chart reveals the significant impact of evaporator temperature and seawater temperature on the evaporator resistance, as well as the notable impact of LNG pressure on the condenser resistance.

Liquefied Natural Gas Value Chain: A Comprehensive Review and Analysis

AbstractOver the past few decades, the liquefied natural gas (LNG) business has experienced astounding expansion and gained global relevance. LNG has emerged as a key element in meeting the world's rising energy demand while working to cut carbon emissions, since it is a cleaner and more adaptable energy source. The entire process from natural gas extraction to consumption is covered in the presented analysis of the LNG value chain, starting out by looking at the discovery and production of natural gas reserves, highlighting important innovations and methods used during the extraction stage. The procedures used to treat and purify natural gas in order to meet the strict standards for liquefaction are detailed. Analysis of the liquefaction process reveals numerous liquefaction technologies, e.g. the well‐known conventional liquefaction and the cutting‐edge floating LNG and small‐scale LNG facilities. LNG storage and transportation, as critical components in the value chain, are examined in great detail. When the LNG reaches its destination, regasification plays a crucial role in repurposing it as a gas for distribution and consumption. Regasification technologies, such as conventional onshore terminals, floating storage and regasification units, and land‐based regasification facilities, are covered. Concerns regarding methane emissions and the carbon footprint, the potential for reducing greenhouse gas emissions through new technology, the environmental impact of LNG, and the economics of LNG are also considered across its value chain.

Thermodynamic analysis of cold energy recovery from LNG regasification

The LNG market connects numerous export and import markets, and the global LNG trade has been growing steadily. Despite the availability of multiple alternatives, only a small fraction of this global cryogenic potential is currently utilized, and a negligible number of regasification terminals are equipped with cold energy recovery systems. This paper explores various options for recovering cold energy from LNG regasification processes including electricity production, refrigeration, cryogenic separation processes, CO 2 capture and liquefaction. The present study examines the industrial recovery options, proposing both conventional and innovative process schemes and analysing them in terms of their thermodynamic modelling and feasibility. Nine case studies were selected and simulated using Aspen Hysys software, considering material and energy balances. Specific energy consumptions are calculated, and an exergetic comparison methodology is adopted to provide a unified approach capable to embrace heterogeneous systems utilizing mechanical/electrical energy, thermal energy, and “chemical energy”. The temperature profiles are examined, and sensitivity analyses are performed on key parameters. The integration of direct cooling and condensation brings high exergy efficiency of above 40% and economic advantages due to the absence of an external refrigeration cycle. Coupling regasification with CO2 liquefaction reduces specific energy consumption by 53% compared to the conventional process. Similarly, in the case of an ethylene production plant, energy consumption is reduced by 95%. Simulations for electricity generation using an ORC cycle with LNG as the cold source achieve around 25% exergy efficiency, but the LCOE (Levelized Cost of Electricity) is attractive, ranging from 0.07 to 0.09 €/kWh. Integration with an Air Separation Unit (ASU) for cryogenic distillation leads to a 41% decrease in specific energy consumption. Further integration with Allam and cascade ORC cycles has been simulated. Globally, air separation shows exergy efficiencies of 37–38%, which is higher than the average 25% obtained from conventional thermodynamic cycles with low-temperature hot sources. Regarding cryogenic CO2 capture, it exhibits lower specific energy consumption compared to traditional processes. The exergy efficiency is high at 22%, and the LCOP (Levelized Cost of CO2 Production) of 55 €/ton is attractive for carbon capture processes that can be coupled with regasification units and NG utilization (a.e. for hydrogen and electricity production).

Review Spotlights Methane Detection, Quantification Technologies

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 205166, “Deployment of Methane Detection and Quantification Technologies,” by Noor A.A. Talip, Mohd H.M. Pikri, and Shahrul A.Z. Abidin, Petronas, et al. The paper has not been peer reviewed. _ In supporting the energy transition, a need exists to improve accurate quantification and reduction of methane emissions and determine long-term reduction targets to drive the competitive advantages of natural gas as a low-carbon fuel. The complete paper reviews an initiative taken to measure baseline data for methane emissions for gas-processing facilities and gas-transmission and regasification units through the use of accurate measurement tools and methodologies. Introduction A methane quantification tool has been developed in-house by Petronas, with two of the operator’s business units as the first users. Methane emission is quantified based on methane sources listed in the Oil and Gas Climate Initiative Guidelines. The quantification covers the following methane-emission sources based on applicability to sample plants: - Unintended release (fugitive leaks, loss of primary containment) - Intended release (venting and flaring of hydrocarbon, stationary combustion, compressor seals, and pneumatic controls and pumps) Methane-emission volume from fugitive leaks, compressor seals, and pneumatic devices had not been quantified accurately by the operator until before the development of its methane-quantification tool. Much of the complete paper is dedicated to describing methodologies used to detect and quantify methane emissions; this synopsis identifies those methodologies but directs the reader to the complete paper for fuller discussions thereof, as well as equations used in those methodologies. Methodology Fugitive Leaks. Global fugitive-emission standards for quantification are nonbinding, regardless of regulations or policies. Nevertheless, the oil and gas industry is still working to develop regulations for methane-emission measurements for effective monitoring and, ultimately, setting the targets for emission reduction. The choice of methods to estimate emission depends on how the estimates will be used and the degree of accuracy required. Methods using site-specific data from direct measurement are preferred. Table 1 of the complete paper shows the fugitive-emission-quantification methodologies sorted into inclining order with respect to accuracy. The methodology-complexity level can be depicted per the terminology in Fig. 1. The five methods are described by the authors, and detailed in the complete paper, as the following: - Method 1: Facility-/plant-level average emission factors - Method 2: Equipment-level average emission factors - Method 3: Device-component-level average emission factors - Method 4: Alternative-leak/no-leak emission factors for optical-gas-imaging technologies - Method 5: Screened value correlation approach

Energy, exergy, economic and environmental analysis of a regasification system integrating simple ORC and LNG open power cycle in floating storage regasification units

A thermodynamic, economic and environmental analysis of a regasification system including a simple Organic Rankine Cycle (ORC) and an Open Organic Rankine Cycle (OC) to utilise the liquefied natural gas (LNG) cold energy is carried out in the present paper. The proposed system, called ORC-OC, uses ambient seawater as heat source (open loop) and is implemented on board a Floating Storage Regasification Unit (FSRU) in order to reduce the greenhouse gas (GHG) emissions associated with the electricity generation plant, i.e., dual fuel (DF) engines. Regarding the ORC working fluids analysed, an ethane/propane zeotropic mixture is applied. The ORC-OC is compared with the simple ORC architecture, giving the first one better energy (lower specific energy consumption), exergy (higher exergy efficiency) and environmental (lower CO2e emissions) results. When compared to the regasification systems installed on board, the ORC-OC system reduces the specific energy consumption by 86.99 % and increases the exergy efficiency by 17.82 % with respect to the most efficient conventional system installed on FSRUs (direct seawater regasification system), leading to a reduction of CO2e emissions of more than 80 %. In addition, the ORC-OC system is more cost-effective than conventional regasification systems when the LNG price is above 6,508 USD/MMBtu.

European Energy Crises, Climate Action and Emerging Market of Carbon-Neutral LNG

Liquified Natural Gas (LNG) has received world-wide attention due to its growing market demands as pointed out by International Energy Agency (IEA), and McKinsey. This article aims to observe contemporary European developments in accordance with the Union’s energy strategy and the Paris Agreement. With the reduction in import of Russian gas, purchasing LNG became an alternative policy option to meet overall energy needs in Europe. European governments and companies are making large investments in land-based regasification terminals and floating storage and regasification units (FSRUs). These trends have fueled hopes that Europe may be able to avoid the worst-case scenario of massive gas shortages, rationing, and industrial shutdowns in the coming months. Nonetheless, such positive short-term developments should not obscure the challenges Europe’s energy-dependent industries are facing due to high gas and electricity prices, which will likely remain elevated for some time. Industries with gas-intensive production or with high absolute demand for gas could still see disruptions during this winter.
 Moreover, this article also evaluates the role of carbon-neutral LNG in European energy crises and its link with eco-friendly processes as set out by the EU and its consequences for the Asian market. The major findings include that the existing carbon measurement framework does not meet the global needs of the LNG industry. Moreover, the breadth of LNG usage is linked to viable GHG emission framework availability.

Risk informed floating storage and re-gasification unit (FSRU) location selection for local natural gas supply

In the present energy market due to high demand of liquefied natural gas (LNG) and the limited availability of land-based LNG import terminals, the use of offshore LNG terminals is destined to increase. Such terminals are referred to as LNG floating storage and re-gasification units (FSRUs). An FSRU terminal is a cost-effective and a time-efficient solution to quickly open up supply to onshore users with minimal environmental impact. This work focuses on the selection from a safety point of view of a possible location for an offshore or nearshore FSRU, given alternative candidate locations. For decision making, the maritime and process safety aspects of the LNG resupply operation have to be considered. This involves the approach of an LNG Carrier (LNGC) to resupply the FSRU. The whole resupply process is divided into three consecutive parts, beginning with the LNGC navigating in the inbound channel, going through its berthing operation, and ending with transfer of the LNG. The safety of the third part, the LNG transfer to the FSRU, could be evaluated by means of a quantitative risk assessment. For the maritime operations this was not possible and evaluation had to rely on expert elicitation. To create a comparison basis of navigating, turning and berthing hazards with the risks of the LNG transfer process, a novel safety utility value (SUV) was defined existing of five ranges. Hazard attributes of navigating and of turning and berthing of the maritime operations were identified/confirmed by simulator runs, their importance was ranked, as well as their safe operating ranges determined with the aid of queries to a large group of experts. Importance ranking was based on pairwise comparison judgment, responses aggregated by means of fuzzy number fits, processed in square matrices. Expert elicitation yielded safety attribute values (SAVs) for the five SUV ranges which were statistically treated. QRA provided potential loss of life (PLL) values, which also were converted into SUV ranges. Based on the importance ranking of the three parts and the SUVs, final results were obtained.

An Application: A Multi-Mode Natural Gas and Liquefied Natural Gas Supply Chain Management Problem

Natural Gas (NG) and Liquefied Natural Gas (LNG) are environmentally friendly and price-competitive energy resources that can be used in every part of the world. In this study, we develop a mixed-integer programming model for the NG and LNG supply chain that includes the location of liquefaction plants, regasification units, storage facilities, and distribution hubs together with the routing of the vehicles for inland distribution of LNG and cryogenic vessels for sea transportation. Unlike other models in the literature, the location of the NG and LNG facilities and routing of vehicles of different modes are optimized by considering the minimization of costs by using the 𝜺 – Constraint method, and different transportation modes, like sea, road, and pipeline, are used together for better effectiveness and cost reduction. The developed model is applied to Turkey to check whether the model is viable for real-world systems

Pathways to Overcoming Natural Gas Dependency on Russia—The German Case

The war in Ukraine has sensitized German policy makers towards the negative economic impact of a curtailment of natural gas flows from Russia. Given its large import dependency, Germany has implemented regulatory measures for mitigating a possible gas shortage and is seeking to diversify from pipeline imports of liquefied natural gas (LNG). In this context, we provide a comprehensive review of the natural gas crisis in Europe and place it in the context of the peculiar role of natural gas in Germany. We critically discuss the economic impact of an embargo, and assess demand and supply factors capable of mitigating a supply shortage. We derive a short-term import substitution potential of 13 bcm, assuming timely installation of Floating Storage and Regasification Units (FSRUs). We discuss the potential for demand reductions in the power sector, in industry consumption, and in households, and estimate a combined maximum of 24.1 bcm. Under decreased industrial demand, the most optimistic scenario indicates an import gap of about 9 bcm for a one-year perspective. Given our findings, we advocate for the delayed phasing out of coal and nuclear power, the accelerated deployment of renewable energy, and caution in the initial execution of storage quotas and restrictions to industrial consumers.

Improvement of Regasification Process Efficiency for Floating Storage Regasification Unit

Natural gas plays a vital role in the economically and environmentally sustainable future of energy. Its reliable deliveries are required, especially nowadays, when the energy market is so volatile and unstable. The conversion of natural gas to its liquefied form (LNG) allows its transport in greater quantities. Affordability and reliability of clean energy is a key issue even for developed markets. Therefore, natural gas usage enables to implement green solutions into countries’ economies. However, the LNG-production process consumes a considerable amount of energy. This energy is stored in LNG as cold energy. After LNG unloading into storage tanks at receiving terminals, it is vaporised and compressed for transmission to a natural gas pipeline system. During the regasification process, the large part of the energy stored in LNG may be recovered and used for electricity generation, seawater desalination, cryogenic air separation, hydrogen liquefaction, material freezing, carbon dioxide capture, as well as for combined LNG cold energy utilization systems. Moreover, increased efficiency of LNG terminals may attract potential clients. In the presented paper, a mathematical model is performed to determine the influence of LNG composition and regasification process parameters on the quantity of released LNG cold energy in a large-scale floating storage and regasification units (FSRU)-type terminal “Independence” (Lithuania). Flow rate of LNG regasification, pressure, and boil-off gas recondensation have been considered. Possibilities to reduce the energy losses were investigated to find the ways to improve the regasification process efficiency for real FSRU. The results analysis revealed that potential of LNG cold energy at FSRU could vary from 20 to 25 MW. A utilisation of industrial and urban waste heat for the heat sink FSRU is recommended to increase the energy efficiency of the whole regasification process.

Appraisal Modeling for FSRU Greenfield Energy Projects

Floating storage and regasification units (FSRU) provide a flexible and competitive energy distribution option when it comes to the regasification of liquefied natural gas (LNG). FSRU projects have become more and more popular, attracting the interest of investors, energy authorities, and governments; therefore, the project feasibility in terms of risks and profitability are a major concern. This paper deals with the appraisal of a greenfield LNG infrastructure project, where usually, decision complexity deals with the high number and different expectation of stakeholders, the capital-intensive financing nature, and the business risks in the project life cycle. Conventional wisdom is to provide a coherent, compact, and well-structured appraisal modelling framework, adjusted to FSRU technical, structural, and operational features on one hand; and business risks, long-term life cycle, and investment attractiveness on the other. Appraisal modelling structure and outputs are considered to provide key messages to the decisions involved and interested parties toward the project feasibility and the associated investment risks for the implementation of the FSRU project. The proposed modelling framework was applied to the Alexandroupolis FSRU project, where the first discussion was many years ago, but the existing conditions in the energy market are raising the interest for developing energy distribution facilities globally.

Thermodynamic and environmental analyses of a novel closed loop regasification system integrating ORC and CO2 capture in floating storage regasification units

Regasification systems in Floating Storage Regasification Units (FSRUs) that use the steam generated by the boilers as the heat source (closed loop) in the liquefied natural gas (LNG) regasification process are less detrimental to the marine environment than those systems that use seawater (open loop). Their drawback, however, lies in the significant increase in fuel consumption and, thus, CO2 emissions. The present paper performs an energy, exergy and environmental analysis of a novel closed-loop regasification system for FSRUs that integrates an organic Rankine cycle (ORC) and post-combustion CO2 capture system with a 30 wt% aqueous solution of monoethanolamine (MEA). LNG cold energy is utilised for power generation through the ORC as well as in the processes of CO2 capture, compression, drying and liquefaction. The system proposed is able to meet the electrical power demand of the FSRU without the use of dual fuel engines, while CO2 capture efficiency in the boiler flue gases exceeds 90%. Fuel consumption is cut by 18% in this system in comparison with existing closed-loop regasification systems, and exergy efficiency increases by 14%, while CO2 emissions decrease by approximately 75% compared to open-loop systems commonly installed on board.

Может ли Турция стать газовым хабом?

Since 1990s, Turkey has been committed to become an energy hub or center, which is, so far, one of the main pillars of contemporary national energy policy. Official documents do not directly mention the creation of a “gas hub” in Turkey as a main task, however all existing strategic plans focus on the development of Turkish gas market through creation of a predictable market and diversification of energy sources and suppliers. The latest requires the development of gas storage infrastructure, gas pipeline network, LNG and floating storage and regasification units (FSRU), and reorganization of energy enterprises. Approaches of various actors of Turkish energy policy regarding the ways of creating a gas hub still differ from each other: when liberals support the policy of reducing the share and role of state-owned companies in the market, others give priority to creating the necessary legislation and administrative conditions to ensure the transparent operation of state-owned companies while maintaining their vertically integrated structure. This study aims to identify the beneficial and unfavorable conditions in Turkey to achieve the mentioned goal. It is made up of four sections: the first section briefly examines the concept and criteria of a “gas hub”, the next one outlines the goals set in Turkey’s energy strategy and the last two sections put the strong and weak sides of the gas infrastructure and the market. Given the current state of the gas infrastructure and gas market, and also domestic and foreign political circumstances, it is still difficult to characterize Turkey as an “energy trading center/gas hub”, simultaneously, it is impossible to ignore its great potential and based on the criteria of the EU Agency for the Cooperation of Energy Regulators (ACER), it can be concluded that Turkey belongs to the category of “emerging gas hubs”.

EXPLOITATION OF LIQUEFIED NATURAL GAS COLD ENERGY IN FLOATING STORAGE REGASIFICATION UNITS

This paper aims to review regasification technology installed in Floating Storage Regasification Units (FSRUs) and the potential offered by the exploitation of cold energy from liquefied natural gas (LNG) in these vessels. The assessment describes the main characteristics of regasification systems along with their respective advantages and limitations. Regasification systems in direct exchange (seawater and steam) and systems with intermediate fluids that use propane or water-glycol in the heat transfer process are studied. In recent years, water-glycol systems have cornered the market. The mixture, besides reducing the risk of freezing, is non-flammable, economical and highly available. Thermodynamic analysis of the regasification process shows that LNG cold energy is the main source of residual energy in these vessels; the specific energy and exergy content is more than double that of engine exhaust gases. Exploitation of this cold energy in power cycles could significantly reduce FSRUs harmful emissions and electrical energy could even be exported to shore. The organic Rankine cycle technology is the most well-known and widely studied, although scientific literature is scarce and there is a need to propose new regasification systems with cold energy exploitation that can be adopted on these vessels.

Energy efficiency and environmental measures for Floating Storage Regasification Units

In view of the need to reduce greenhouse gas emissions from the maritime sector, this paper proposes design and operation indicators for the assessment of Floating Storage Regasification Unit (FSRU) energy efficiency and carbon footprint. Such indicators are applied to the study of five regasification systems: seawater system without recondenser (Case 0), seawater system (Case 1), open-loop propane system (Case 2), closed-loop water-glycol system (Case 3) and open-loop system with Organic Rankine Cycle (ORC) (Case 4). Of the regasification systems installed in FSRUs, Case 1 proves most energy efficient, closely followed by Case 2. If the cold energy of liquefied natural gas (LNG) were to be exploited in the regasification process, Case 4 would present an Energy Efficiency Design Index (EEDI) 41.25% lower than that of Case 1, whilst positioned at the opposite end of the scale is Case 3 with an EEDI of 347.98% higher. The Carbon Footprint Design Index (CFDI), in comparison with the EEDI, further includes emissions deriving from the methane slip from dual fuel engines and the CO2 capture ratio factor for the possible implementation of Carbon Capture and Storage (CCS) systems. In the cases analysed, the CFDI with a methane slip of 5.5 g/kWh represents an increase of 4–28% with regard to the EEDI.

Energy, exergy and economic analysis of offshore regasification systems

Energy, exergy and economic analysis are proposed herein to evaluate regasification systems in Floating Storage Regasification Units (FSRUs). Three regasification systems typical in these types of vessels are considered: seawater system, open loop propane system and closed loop water-glycol system. The energy and exergy analyses were performed using the Engineering Equation Solver (EES), while Suite AspenONE programmes were used for the economic assessment. The exergy analysis provides a better understanding of the components of physical exergy (thermal and mechanical exergy) in order to define an exergy efficiency applicable to any liquefied natural gas (LNG) regasification system or FSRU. The results obtained prove the seawater regasification system to be most efficient from an energy and exergy standpoint. The specific energy consumption and exergy efficiency for this system are 227.33 kJ/kg and 50.00%, respectively. On the other hand, the open loop propane regasification system is most cost-effective for an LNG price between 1.32 and 11 USD/MMBtu. The vast amounts of destroyed exergy in the regasification process of current systems was also demonstrated and hence the need to develop new, more efficient configurations that could exploit the cold energy of LNG.

JIP Drives New Ways of Managing Integrity of Floating Oil and Gas Assets

This article, written by JPT Technology Editor Judy Feder, contains highlights of paper OTC 30425, “Innovative Asset-Integrity Management To Drive Operational Effectiveness,” by Danny Constantinis and Peter Davies, EM&I, prepared for the 2020 Offshore Technology Conference Asia, originally scheduled to be held in Kuala Lumpur, Malaysia, 17–19 August. The paper has not been peer reviewed. Copyright 2020 Offshore Technology Conference. Reproduced by permission. While the focus on the growing floating gas industry is firmly on output, the industry needs to ensure safety, compliance, and profitability of high-value, complex, floating gas assets, some of which operate close to high population densities. Effective asset-integrity programs are a key part of such an effort, and it is widely agreed that better use of data and robotics will help reduce unnecessary work and human risk. The complete paper describes a joint industry approach for addressing asset-integrity management challenges that has proved successful for floating production, storage, and offloading vessels (FPSOs). Introduction Managing the integrity of offshore, near-shore, and berthed floating oil and gas assets faces numerous challenges, including the following: - Long service lives - The need to cut operating costs - Varying asset-integrity requirements of marine and process equipment - Growing global demand for gas - Increasing requirement to drive down carbon emissions - The need for enhanced sustainability Traditional cost-reduction strategies of prior lean market periods are no longer accepted by the industry, which the authors say needs to implement permanent cost reductions, increased sustainability and efficiency, and improved safety. These can be achieved only by new ways of managing asset integrity, targeted at consistent low price and efficiencies and developed, supported, and accepted by all sectors of the industry. Role of the Joint Industry Project (JIP) The Hull Inspection Techniques and Strategy (HITS) JIP has encouraged such innovations. The complete paper describes new methods facilitated by HITS that include diverless inspections of hulls and mooring systems and remote, unmanned methods of inspecting confined spaces such as cargo and water ballast tanks. Organizations such as the HITS JIP, whose membership includes oil majors, service providers, classification societies, and regulators, and the FPSO Research Forum, of which HITS is a part, have helped define the direction for improvements in inspecting, maintaining, and repairing floating production assets. These organizations have encouraged the development of new technologies that have improved safety and reduced operational costs. According to the paper’s authors, this direction has also shaped the drilling sector, can do the same for floating liquified natural gas (FLNG) and floating storage and regasification units (FSRU), and could potentially expand into floating renewable-energy-production assets. These and similar concepts are now being taken forward in a floating gas (FloGas) JIP.

The feasibility of performing the importation of floating storage regasification units: fsru through the application of the special temporary admission regime and customs warehouse regime

The feasibility of performing the importation of floating storage regasification units: fsru through the application of the special temporary admission regime and customs warehouse regime

A Simulation-Based Planning Tool for Floating Storage and Regasification Units

The objective of this paper was to propose a functional simulation model for the operation of floating storage and regasification units (FSRUs) used for the import of liquefied natural gas (LNG). The physical operation of an FSRU is decomposed for each critical component of the LNG carrier (LNGC) and the FSRU, in order to construct a realistic model in Simulink. LNG mass balance equations are used to perform flow calculations from the tanks of an LNG carrier to the tanks of the FSRU and from there to shore. The simulation model produces results for cases, when multiple LNG carriers discharge cargoes during a monthly time horizon. This produces an accurate operational profile for the FSRU with information about the volume of LNG inside each of the cargo tanks of the FSRU, LNG cargo discharging and gas send-out rate. Potential practitioners may exploit the proposed planning tool to explore the feasibility of alternative operation scenarios for an FSRU terminal. The simulations can check the system sensitivity to different parameters and support schedule regarding: (i) slots for LNG carrier calls, (ii) LNG inventory fluctuation, and (iii) impact of gas demand and send-out rate changes.