Liquefied Natural Gas Facilities Research Articles

Emissions reduction in LNG production facilities through emerging post-combustion carbon capture and storage technologies

The liquefied natural gas (LNG) sector relies extensively on gas turbines for on-site power generation and to drive refrigeration compressors. They provide an efficient and reliable energy source for LNG operations in remote locations. With upcoming changes to the Safeguard Mechanism in Australia, there is an increased focus on Scope 1 emissions, so management and targeted reduction are a priority to reduce liabilities. Despite technology advancements, gas turbines remain one of the largest sources of carbon dioxide (CO2) emissions in LNG production facilities. Also, in Australia, many facilities are not grid-connected, meaning that displacement of Scope 1 emissions through renewable electricity sourcing is a challenge. To develop deeper cuts in Scope 1 emissions, one solution is to deploy post-combustion carbon capture and storage (CCS) on existing gas turbines, with the potential to reduce associated emissions by over 90%. Globally, a number of LNG facilities are already deploying CCS to permanently store reservoir CO2 from the LNG processing trains. Several Australian LNG facilities are located in close proximity to potential CO2 storage reservoirs, meaning that a coordinated approach to both reservoir and post-combustion CO2 should be considered when sizing pipelines, shipping systems and storage wells to optimise and leverage the required investment. This paper outlines the technological, economic and policy aspects of integrating both reservoir post-combustion CCS on LNG facilities, including barriers and opportunities for deployment. It will discuss new developments and enablers for CCS to be more widely deployed at LNG production sites.

Charting a path to low-carbon leadership: unlocking up to 90% emissions reductions in greenfield LNG

The liquefied natural gas (LNG) industry stands at the cusp of a transformation driven by the climate imperative. Focussing on the Middle Arm Industrial Precinct, this paper shows how carbon dioxide (CO2) emissions are being reduced in a proposed world-class LNG project by assessing, screening and selecting known technologies using a Marginal Abatement philosophy linked to key emissions drivers. (1) We propose a new breed of electrified LNG facilities that could deliver an up to 90% reduction in CO2 intensity. (2) We show that through developing strategic partnerships in upstream renewable power, hydrogen supply, and enabled downstream carbon capture and storage (CCS), the significant low carbon energy requirements of an LNG facility can be delivered. (3) We discuss a Marginal Abatement assessment strategy which ensures a pathway to viable lowest cost opportunities selected in an ‘Avoid & Mitigate’ first approach. This proposed strategy ensures that CO2 emission reduction opportunities are assessed and selected consistently to determine both a lifecycle cost ($) and volume (tons CO2e) of emission reduction. These innovative strategies collectively articulate a roadmap for a low carbon future for LNG and other heavy industrial industries, underlining Australia’s potential to become a leading provider of low-carbon natural resources.

Innovative waste management approaches in LNG operations: A detailed review

As the liquefied natural gas (LNG) industry continues to expand globally, the imperative to address environmental concerns and enhance sustainability within LNG operations becomes paramount. This paper conducts a comprehensive and detailed review of innovative waste management approaches within the LNG sector. Traditional waste management practices in LNG operations, including disposal and recycling, are examined, highlighting the associated challenges. The focus then shifts to innovative approaches, encompassing recycling and circular economy initiatives, advanced waste-to-energy technologies, and the adoption of sustainable packaging solutions. Case studies and examples illustrate successful implementations of innovative waste management strategies in various LNG facilities, providing insights into the environmental and operational benefits achieved. The paper explores the implications of these approaches, emphasizing reduced carbon footprints, enhanced resource efficiency, and cost-effectiveness. Additionally, the review delves into the barriers and challenges hindering widespread adoption, including technological, economic, and regulatory considerations. This detailed examination aims to contribute valuable insights for industry stakeholders, policymakers, and researchers, fostering the integration of sustainable and innovative waste management practices in the ever-evolving landscape of LNG operations. Keywords: Innovative, Waste, Management, LNG operations, Review.

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.

Fragile Equilibrium: Balancing LNG Trade and Market Risks

_ Liquefied natural gas (LNG) has been in global energy supply discussions for decades. Geopolitical tensions, however, recently elevated it from a bullet point to the entire conversation. Rarely does a day pass without mention of signed long-term LNG purchase agreements or LNG terminal construction projects advancing, one day making it possible to transport the curiously cold molecules across oceans to eventually power industries or heat homes. So strong are the fundamentals of the LNG industry, for example, that they were cited as a primary driver in the conversion of one of the largest pure-play US-listed shipping companies—Capital Product Partners led by Greek shipowner Evangelos Marinakis—to a pure-play LNG shipping company. In addition to changing its name to Capital New Energy Carriers, the partnership is selling off its modern fleet of 15 Neo-Panamax and Panamax container vessels. It will spend $3.13 billion to purchase 11 newbuild LNG carriers (LNGC). According to an announcement on 13 November, the first of the new vessels arrived in October 2023. The company already had seven LNG carriers in its fleet, with the remaining 10 newbuild vessels scheduled for delivery through March 2027. Jerry Kalogiratos, chief executive of Capital Product Partners, said the acquisition was transformative, noting that the partnership “expects our contracted revenues to increase by 87% percent to $3.1 billion, our revenue weighted charter duration to 7.2 years as of the closing date, and the average age of our LNG fleet to decrease to 3.2 years by the time all LNGCs have been delivered in 2027.” LNG Market Overview Events like the Russian invasion of Ukraine in February 2022 and the sudden loss of Russian pipeline gas supplies upended global energy markets. European buyers turned to LNG imports to meet demand. According to Wood Mackenzie, the current conflict in Israel/Gaza, possible pipeline sabotage in the Baltics, and the threat of fresh strike action at Australian LNG facilities all pushed spot prices up 35% through October. In a November blog post, Wood Mackenzie noted that a record 200 mtpa of new supply is under construction as “players bet big on Asia’s push to reduce its dependence on coal and Europe’s need to replace Russian gas.” While the proliferation of LNG projects is prompting concerns that there may be too much LNG on the market once these projects are completed, this is not the case, according to Wood Mackenzie. “Increased supply availability will bring prices down and boost demand growth,” said Gavin Thompson, vice chair of Europe, Middle East, and Africa, and Massimo Di Odoardo, vice president, gas and LNG research for Wood Mackenzie, noting that the market will need another 60 mtpa of new LNG by 2033. “Much will hinge on sustained economic growth, driving increased demand across emerging markets in Asia. China’s LNG demand will increase by 12% in 2023, and with 50 mtpa of LNG contracted over the past 2 years, imports will double by 2030. LNG demand in South and Southeast Asia will also grow twofold by this time,” they said.

Application of Hybrid Laser Arc Welding for Construction of LNG Tanks Made of Thick Cryogenic 9% Ni Steel Plates

AbstractHybrid laser-arc welding (HLAW) was applied for butt welding of 14.5 mm thick plates of ferritic cryogenic steel X8Ni9 containing 9% Ni, which is used for manufacturing storage and transport facilities of liquefied natural gas (LNG). The weld seam formation and the achievable metallurgical and mechanical properties of the hybrid welds were investigated experimentally for two types of filler wire, an austenitic wire dissimilar to the base metal (BM) and an experimentally produced matching ferritic wire. Safe penetration and uniform distribution of the austenitic filler metal in the narrow hybrid weld could only be achieved in the upper, arc-dominated part of the weld. The pronounced heterogeneous distribution of the austenitic filler metal in the middle part and in the root area of the weld could not ensure sufficient notched impact toughness of the weld metal (WM). As a result, a decrease in the impact energy down to 17 ± 3 J was observed, which is below the acceptance level of ≥ 34 J for cryogenic applications. In contrast, the use of a matching ferritic filler wire resulted in satisfactory impact energy of the hybrid welds of up to 134 ± 52 J at the concerned cryogenic temperature of -196 °C. The obtained results contribute to an important and remarkable conversion in automated manufacturing of LNG facilities. In other words, the results will help to develop a new laser-based welding technology, where both quality and productivity are considered.The efficiency of the developed welding process has been demonstrated by manufacturing a prototype where a segment of the inner wall of large size LNG storage tank was constructed. In this concern, hybrid laser arc welding was conducted in both horizontal (2G) and vertical (3G) positions as a simulation to the actual onsite manufacturing. The prototype was fabricated twice where its quality was confirmed based on non-destructive and destructive examinations.

Developing a spatially explicit global oil and gas infrastructure database for characterizing methane emission sources at high resolution

Abstract. Reducing oil and gas methane emissions is crucially important for limiting the rate of human-induced climate warming. As the capacity of multi-scale measurements of global oil and gas methane emissions has advanced in recent years, including the emerging ecosystem of satellite and airborne remote sensing platforms, a clear need for an openly accessible and regularly updated global inventory of oil and gas infrastructure has emerged as an important tool for characterizing and tracking methane emission sources. In this study, we develop a spatially explicit database of global oil and gas infrastructure, focusing on the acquisition, curation, and integration of public-domain geospatial datasets reported by official government sources and by industry, academic research institutions, and other non-government entities. We focus on the major oil and gas facility types that are key sources of measured methane emissions, including production wells, offshore production platforms, natural gas compressor stations, processing facilities, liquefied natural gas facilities, crude oil refineries, and pipelines. The first version of this global geospatial database (Oil and Gas Infrastructure Mapping database, OGIM_v1) contains a total of ∼ 6 million features, including 2.6 million point locations of major oil and gas facility types and over 2.6×106 km of pipelines globally. For each facility record, we include key attributes – such as facility type, operational status, oil and gas production and capacity information, operator names, and installation dates – which enable detailed methane source assessment and attribution analytics. Using the OGIM database, we demonstrate facility-level source attribution for multiple airborne remote-sensing-detected methane point sources from the Permian Basin, which is the largest oil-producing basin in the United States. In addition to source attribution, we present other major applications of this oil and gas infrastructure database in relation to methane emission assessment, including the development of an improved bottom-up methane emission inventory at high resolution (1 km × 1 km). We also discuss the tracking of changes in basin-level oil and gas activity and the development of policy-relevant analytics and insights for targeted methane mitigation. This work and the OGIM database, which we anticipate updating on a regular cadence, help fulfill a crucial oil and gas geospatial data need, in support of the assessment, attribution, and mitigation of global oil and gas methane emissions at high resolution. OGIM_v1 is publicly available at https://doi.org/10.5281/zenodo.7466757 (Omara et al., 2022a).

Assessment of the mass burning rate of LNG pool fires by a validated CFD model

Liquefied natural gas (LNG) is widely used, because it provides an easy and economic solution to the transport and storage of natural gas (NG), especially on long distances or when transport by pipeline is not viable. The LNG pool fire is one major process safety accident at the LNG facilities according to the report of the U.S. Government Accountability Office. Moreover, due to the high surface emissive power of LNG compared to other hydrocarbon fuels, LNG pool fires have a high potential in causing domino effects and cascading events in process industry. Previous studies developed Computational Fluid Dynamics (CFD) models of LNG pool fires, but the mass burning rate was fixed manually as a model input, not considering that the mass burning rate is determined by the fuel’s physical properties and heat input vaporizing the fuel. In this study, a model of LNG pool fire controlled by material physical properties was developed using fire dynamics simulator (FDS), and was validated against LNG pool fire experiments carried out by Mary Kay O’Connor Process Safety Center (MKOPSC). Statistical performance measurement shows that the model is superior to the semi-empirical approaches in predicting the mass burning rate of LNG pool fire under different pool sizes. A flame geometry analysis software was developed comparing different algorithms, and the centroid method was selected. The results show that the fire model (200 kW/m3 as flame contour) can accurately predict the flame geometry observed in the experimental runs. The influence of wind velocity and dike height on the mass burning rate was also investigated. The results show that the height of the concrete dike is negatively correlated with the mass burning rate of LNG pool fire. The effect of wind velocity on LNG mass burning rate is twofold. The forced convective boundary layer at lower wind velocity promotes LNG combustion and increases the mass burning rate, while higher wind velocities reduce the mass burning rate due to the reduction of the thermal radiation feedback. The findings in this study will contribute to an accurate risk assessment of LNG pool fire accidents in the process industry.

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

Risk-averse stochastic bilevel programming: An application to natural gas markets

This paper presents a risk-based integer bilevel programming model that represents two players (leader and follower) who interact strategically over an infrastructure network. Both players seek to maximize their individual profits in the face of demand uncertainty. Variations of the basic model are proposed that allow us to identify optimal strategies under risk-neutral and risk-averse decision-making. To solve the resulting stochastic bilevel problem, we develop an algorithm that relies on iteratively solving a restricted version of the problem to obtain feasible solutions to the original model. Extensive computational experiments are performed to evaluate algorithmic tractability and solution quality. The methodology is demonstrated using an example that addresses emerging strategic issues in natural gas markets. The model considers two players, a liquefied natural gas (LNG) operator as the leader and a natural gas (NG) producer as the follower. The LNG operator makes decisions on the locations of LNG facilities and the amount of gas to buy from the producer. The NG producer decides how much gas to produce and how to ship it through the existing pipeline network. Both players face demand uncertainty in their respective markets and have to make investment, production, and sales decisions. Our case study focuses on the Gulf-Southwest region of the United States and demonstrates the impact of risk-averse decision-making on investment and operational decisions.

System Equilibrium Results in Zero Flaring During Offloading

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 30655, “Effective Boiled-Off-Gas/Fuel-Gas Balance Between Floating Liquefaction Facilities and Carrier Resulting in Zero Flaring During Offloading,” by Kinfai Wong and Rose Sapinah Hashim, Petronas, and Yosuke Yamamoto, JGC, et al. The paper has not been peer reviewed. Copyright 2020 Offshore Technology Conference. Reproduced by permission. Achievement of zero flaring during liquefied natural gas (LNG) offloading operations is governed by many factors. The proper management of the balance of fuel gas and boiled-off gas (BOG) between the floating LNG (FLNG) facility and the LNG carrier (LNGC) is critical during offloading to ensure that the system reaches equilibrium, leading to zero flaring. The complete paper details a process study to identify potential causes of flaring during LNG offtake and corrective measures to accomplish zero flaring without any capital plant modification. The study is applicable only for offloading operations to LNGCs with spherical Type B LNG tanks. Introduction PFLNG Satu (referred to hereafter as PFLNG1) performs LNG offloading to an LNGC on a monthly basis. This is known as an offloading mode of operations, in which the LNGC is moored at the PFLNG1 facilities and LNG is transferred from storage tanks to the LNGC. The LNG in the storage tank is transferred to the LNGC by three liquid-offloading arms, while the vapor return from the LNGC is recovered by a single vapor-return arm. Multiple gas-flaring incidents were observed with PFLNG1’s fuel-gas system because of an imbalance in the fuel-gas flow in the system during offloading operations.

Assessment of predictive methods for the heat transfer coefficient during flow boiling of R50 and R170 mixtures

Liquefied natural gas (LNG) is a binary mixture of methane (R50) and ethane (R170). Proper evaluation of the heat transfer coefficient during flow boiling of such a mixture is very important to design LNG facilities. Pure fluid correlations have been tested with and without the adoption of corrections to account for the lowered performance due to mass transfer resistances arising both in the nucleate boiling and in the convective boiling regimes. In total, the prediction of 13 correlations has been compared with a new data set from the literature. Results show that the correction related to nucleate boiling has the greatest impact though, in general, the adoption of the corrections leads to under predict the data.

Evaluation protocols for flammable and toxic dispersion models

AbstractThe siting of liquefied natural gas (LNG) facilities requires several types of hazards to be quantified so that the risk to the public and public property in areas surrounding each facility can be properly assessed. In order to quantify the hazards from potential accident scenarios, computational tools must be used. Given the multiplicity of tools available, ranging from empirical models to 3D computational fluid dynamics packages, the agency responsible for reviewing the hazard analysis may not have the methodologies or protocols necessary to determine the suitability of a given model to a certain scenario, its accuracy, and any other setup requirements. The Pipeline and Hazardous Materials Safety Administration (PHMSA) commissioned Blue Engineering and Consulting and the Gas Technology Institute to develop a set of model evaluation protocols (MEPs) that will allow the review of modeling tools for several different hazards, including flammable and toxic dispersion, source terms for dispersion models, vapor cloud explosions, and boiling liquid expanding vapor explosions (BLEVEs). The project will provide PHMSA with the means to properly evaluate modeling tools for these hazards, which are required to be evaluated in an LNG facility siting study. It will also provide clarity to LNG plant developers and their safety consultants on which models may be used and which safety factors need to be applied, and will increase the public's confidence in the regulatory review process of LNG facilities. This article discusses the first two MEPs completed as part of this project, which are focused on evaluating flammable dispersion and toxic dispersion models, respectively. This article describes the evaluation methodology, including the information to be submitted by the model proponents and the review process, and the model validation databases compiled for each protocol.

Too many or not enough? A methodology for evaluating fire and gas detector layouts at LNG facilities

AbstractNFPA 59A Standard for the Production, Storage, and Handling of Liquefied Natural Gas (LNG) requires facilities to have the equipment necessary for the detection and control of fires, leaks and spills of hazardous materials, yet provides no requirements or guidance on the location of the detectors. Literature available in the public domain outlines key factors to consider in developing layouts for flame and gas detectors, but a methodology to use this information in evaluating a hazard detector layout is not clearly defined; instead, generic and non‐quantifiable terminology such as “quick and reliable” is often used. As a result, there is no consistent approach to developing flame and gas detector layouts for land‐based LNG facilities and there is no systematic method for regulators to evaluate these designs. The ability to quantify hazard detector performance and define performance targets are of particular interest to the Department of Transportation (DOT) Pipeline and Hazardous Materials Safety Administration (PHMSA), which regulates numerous LNG facilities in the United States. Blue Engineering and Consulting is working on a DOT‐PHMSA sponsored project to develop a risk‐based approach and criteria for hazard detector layouts at LNG facilities. This project builds upon performance‐based design principles outlined in NFPA 72 National Fire Alarm and Signaling Code and the International Society of Automation (ISA) technical report 84.00.07 Guidance on the Evaluation of Fire, Combustible Gas, and Toxic Gas System Effectiveness. The methodology divides the LNG facility into Detection Areas based on the hazards present and the plant layout, identifies the appropriate hazard scenarios to evaluate the detector layout, establishes performance targets for each Detection Area, and quantifies hazard detector coverage. This paper will describe and demonstrate the proposed methodology. It should be noted that, while performance targets must be chosen for the purposes of the demonstrative included in this paper, these targets should not be interpreted as requirements of DOT‐PHMSA nor as acceptable to them.

Developing a CFD heat transfer model for applying high expansion foam in an LNG spill

Liquefied natural gas (LNG) is widely used to cost-effectively store and transport natural gas. However, a spill of LNG can create a vapor cloud, which can potentially cause fire and explosion. High expansion (HEX) foam is recommended by the NFPA 11 to mitigate the vapor hazard and control LNG pool fire. In this study, the parameters that affect HEX foam performance were examined using lab-scale testing of foam temperature profile and computational fluid dynamics (CFD) modeling of heat transfer in vapor channels. A heat transfer model using ANSYS Fluent® was developed to estimate the minimum HEX foam height that allows the vapors from LNG spillage to disperse rapidly. We also performed a sensitivity analysis on the effect of the vaporization rate, the diameter of the vapor channel, and the heat transfer coefficient on the required minimum height of the HEX foam. It can be observed that at least 1.2 m of HEX foam in height are needed to achieve risk mitigation in a typical situation. The simulation results can be used not only for understanding the heat transfer mechanisms when applying HEX foam but also for suggesting to the LNG facility operator how much HEX foam they need for effective risk mitigation under different conditions.

Development of Liquefied Natural Gas Facilities in the Baltic Sea Ports: a Geographical Perspective

This paper presents an overview of the liquefied natural gas (LNG) facilities development in the Baltic Sea. The value of the paper lies in its seek to demonstrate how the process of interaction between the shipping and energy networks unfolds through infrastructural developments of ports. The analysis is based on mapping, cartographic and spatial contextual methods. The mapping of gas supply networks, LNG facilities and traffic patterns establish the originality of this research. It shows that factors motivating the development of LNG terminals in the Baltic ports come from areas of energy and maritime policy. Moreover, in future, the emerging LNG infrastructure may have an effect on port competition in the Baltic Sea Region.

Investigating the Unknown Abilities of Natural Gas Hydrates

The high capacity of gas hydrate in natural gas storage makes it attractive to use it for storage and transportation of natural gas and other gases as a competitor to liquefaction and condensation methods. Since the 1960s, when gas hydrate was introduced as a disturbing factor in gas pipelines, the idea of natural gas transfer by hydrate has been on the minds of many scientists. Because the hydrate transport temperature is higher than the liquefied natural gas (LNG) transport temperature, gaseous hydrate can be easily transported; Therefore, the technology of building hydraulic vessels will be much less complex than that of LNG vessels, and hydrogen production facilities can be designed much easier than LNG facilities. But the main problem is the smaller volume of gas transferred. According to studies in this field, each cubic meter of hydrate contains 175 cubic meters of gas. However, in LNG technology, the volume reduction reaches one hundred percent, and this issue is very important in the economics of gas transmission projects, especially long distances. Nevertheless, there is still great hope that hydrate will be used as a completely economical solution for gas transmission. In this regard, British Petroleum, in collaboration with other scientific centers such as the University of Gwasen, is building a small industrial unit that can produce 100 kg of hydrate per day.

Application, Selection, and Design of Three-Winding Transformers in LNG and Petrochemical Facilities

Transformers are used in power systems to transform (step-down) voltages while maintaining the same frequency. Electrical engineers designing the power systems for a liquefied natural gas (LNG) or petrochemical facilities typically use two-winding transformers to feed multiple process units in redundant distribution schemes throughout the facility. This method is repeated further to derive different voltage levels to feed process loads. As the industry moves toward larger production facilities, which increase the power demand, multiple large two-winding transformers are utilized. This approach leads to an increase in substation footprint, switchgear equipment, power feeders, site works, etc. This article focuses on an alternative design using three-winding transformers for LNG and petrochemical facilities. The input and output of a three-winding transformer generally consist of one primary ( H ) input winding and two output windings defined as secondary ( X ) and tertiary ( Y ). The three-winding transformers are connected in a redundant configuration to feed multiple process units. In this article, different types of three-winding configurations and construction (radial or axial) methods are reviewed. In addition, this article addresses the application of tap changers, overall system performance, defining impedance parameters, and specification requirements.

Quantitative risk assessment of fire & explosion for regasification process of an LNG-FSRU

As global energy consumption is continuously on the rise, there is an increasing interest in the design of floating liquefied natural gas (LNG) regasification facilities in order to prepare for additional energy demand. In this study, following a process simulation to find operational conditions, a quantitative risk assessment (QRA) was performed for a regasification process of an LNG floating storage and regasification unit (FSRU). The regasification process was designed and simulated considering the required gas processing capability to obtain the thermodynamic states and operation conditions. A QRA was performed with combinations of frequencies and consequences of fire and explosion. The leak frequencies, representative hole sizes, and ignition probabilities for four hole size categories were estimated. Consequence simulation was conducted to assess risk results. The probabilistic safety distance for the flame length was estimated. The final risk consequences were obtained as number of fatalities per year by applying lethality values. The individual risk was found to be in as low as reasonably practicable (ALARP) ron compared to acceptance criteria. An f-N curve for fatality showed that the group risk is also in ALARP ron. The method and results presented in this study will help design LNG-FSRUs and other LNG facilities.

Application of fuzzy failure mode effect and criticality analysis on unloading facility of LNG terminal

The energy demand in developed and developing nations is steadily increasing with Liquefied Natural Gas (LNG) being a prominent source of energy to meet the growing demand. However, the social acceptance of LNG facilities largely depends on the successful implementation of appropriate safety standards and risk management programs. Therefore, it is vital to continue to improve existing risk assessment strategies to deal with the safety concerns of these facilities. FMECA (Failure Mode Effects and Criticality Analysis) approach is very effective in identifying failure modes and prioritising them by developing a Risk Priority Number (RPN). Several literature have discussed the difficulty in prioritization of failure modes having identical RPN values. This paper presents the application of Fuzzy based FMECA approach to an LNG unloading facility in an LNG terminal located in south India. This fuzzy based FMECA approach uses Fuzzy RPN values which reduces the difficulties in prioritization of failure modes of critical failures. The effectiveness of this approach is demonstrated by applying it to an operational LNG unloading facility in one of the major LNG terminals. The successful identification and ranking of critical failure modes in LNG unloading facility is to be very useful for LNG industries to prioritize their corrective and preventive actions, thereby improving their safety standards.