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Jessica Casey, Editor, LNG Industry, highlights some key African LNG projects under development. 42 The role of artificial intelligence in
Daniel Patrick, Market Segment Manager – LNG & Hydrogen, Atlas Copco Gas and Process Division, outlines the role of integrally geared machinery in unlocking liquefaction performance.
Joseph Demonte, Teddy Tilahun, and Andrea Sutti, Emerson, explain how LNG poses significant challenges for control, isolation, and relief valve applications – which can be addressed with specially designed solutions.
Sukhpal Basi, Principal Process Engineer, KBR, discusses how the LNG industry can move towards a more sustainable footing by focusing on decarbonisation of the LNG value chain via energy efficiency improvements and emissions reduction.
Rupesh Parikh, Sales Director, Global Accounts at Rockwell Automation, untangles the complicated nature of LNG’s position in the energy transition and illuminates how LNG can continue to evolve in a changing global market.
66 LogisTech (Ningbo) Co., Ltd, considers how artificial intelligence is transforming the assessment and management of liquid cargo such as LNG, monitoring and safeguarding goods for owners and investors in real time.
ABBY BUTLER EDITORIAL ASSISTANT
COMMENT
FManaging Editor
James Little james.little@palladianpublications.com
Senior Editor
Elizabeth Corner elizabeth.corner@palladianpublications.com
or those of us in the northern hemisphere, having recently celebrated the Summer Solstice on 21 June, the warm temperatures of summer are well and truly upon us. Here in the UK, though events like Glastonbury music festival have concluded for the year, July is still packed with festivities. The first two weeks of the month are occupied by the 138th instalment of The Championships tennis tournament, held annually at Wimbledon. Then, looking towards the end of July, Northern Ireland prepares to host golfing champions at the 153rd Open Championship. A big month for European sport, France is also readying up for the annual Tour de France, lasting four weeks and bringing together a range of international cyclists. Over in the US, celebrations began early with Independence Day on 4 July whilst, back in Europe, France observes Bastille Day, also celebrating freedom, on 14 July.
In the LNG sector, this theme of independence and energy freedom is experiencing mounting significance. In the past month, I was fortunate enough to attend Wood Mackenzie’s third annual Gas, LNG, and the Future of Energy conference in London. Across two days, the summit addressed a broad range of key industry questions, such as LNG’s place in a shifting geopolitical landscape, how net-zero and decarbonisation goals will continue to impact the sector, the future of gas and LNG in Europe, and more.
As expected, US LNG activity remains at the forefront of discussions as President Trump continues to ramp up infrastructure to achieve both domestic independence and to enhance global exports. In fact, US LNG activity formed a key takeaway from the summit; don’t bet against US LNG. Although concerns have been raised about the permit restrictions that may return should the Democratic Party be restored to office come the 2028 election, the sheer volume of LNG entering the market from the US is currently unparalleled, solidifying the US’ position as a safe investment option for stakeholders and banks in the sector.
With Russian involvement in the market lowered, the demand for US LNG continues to soar in Europe whilst Asian imports are continuing to increase. With increased volumes of LNG entering the market, prices have begun to soften. Panellists and Wood Mackenzie analysts noted how, despite China’s reduction in US LNG imports, many Asian countries, such as South Korea, Japan, and Taiwan, are looking to capitalise on these softer prices, creating a self-correcting mechanism where total Asian imports are increasing despite China’s decline in consumption. This demand is expected to continue rising as, in a keynote interview discussing how to navigate the challenges and opportunities in a dynamic global LNG market, experts shared 100% certainty that Asian demand will remain high long term.
For European LNG growth, the potential return of Russian LNG to the market persists as a salient topic. A poll presented to the audience during a panel discussion revealed that the majority of attendees considered the return of Russian gas through Nord Stream pipelines a matter of when, rather than if. However, Dr Tatiana Mitrova, research fellow at the Center on Global Energy Policy, noted that unless a suitable peace agreement is reached, whereby Ukrainian transit routes for Russian gas are restored, Nord Stream revival looks unlikely.
The conference concluded with discussions about emerging players in the LNG sector, most significantly Qatar. With access to the North Field, the world’s largest natural gas field, Qatar has export capacity potential to rival the US. The country is ramping up its annual LNG production and experts predict that the country will control 25% of the market by 2030.1 Qatar is also incorporating decarbonisation efforts into new builds, aligning with net zero efforts from the jump through installing carbon capture technology into newly built infrastructure. This month’s issue aligns with Qatar’s efforts, exploring how sustainability efforts can be integrated into various aspects of LNG technology including terminal technology, storage technology, and liquefaction optimisation.
References
1. ‘LNG Giant and Solar Dreams: Qatar’s Next Energy Chapter’, Middle East Council on Global Affairs, (26 January 2025), https://mecouncil.org/publication_chapters/lng-giant-and-solar-dreams-qatars-next-energy/
2-5 FEBRUARY 2026
Italy
OLT commissions new small scale LNG service
OLT Offshore LNG Toscana has completed the commissioning of the new small scale LNG service that will be offered by the company, through the FSRU Toscana terminal. Testing activities involved the bidirectional transfer of LNG between a small LNG carrier – the Avenir Aspiration operated by Axpo – to the terminal and from the terminal to the small LNG carrier itself.
This new service, which the FSRU Toscana terminal will provide first in Italy, will enable small LNG carriers to load LNG at the OLT terminal. The small scale LNG carriers will then be able to refuel, directly at sea, LNG-fuelled naval units, or discharge the fuel at coastal storage facilities in major Mediterranean ports. In addition, it will be possible to receive LNG from small LNG carriers to be regasified and fed into the grid.
With the launch of small scale LNG, OLT is confirmed as a strategic hub for the development of maritime bunkering and the LNG supply chain; in particular, following the designation of the Mediterranean Sea as a Sulphur Emission Control Area (SECA) – which came into effect on 1 May 2025 – ships will have to use sulfur-reduced marine fuel throughout the Mare Nostrum.
USA
LNGNEWS
USA
HD Hyundai and Tampa Ship sign MoU
HD Hyundai has launched a strategic shipbuilding collaboration in the US centred on Tampa Ship, a major US shipyard operating within the Edison Chouest Offshore (ECO) family of companies, to construct containerships in the US.
HD Hyundai recently held a signing ceremony with US-based Tampa Ship LLC, a company within the Edison Chouest Offshore family of affiliated companies (ECO), to establish a strategic and comprehensive collaboration that outlines a multi-faceted alliance to build medium-sized LNG dual-fuel containerships at Tampa Ship, with first deliveries targeted for 2028.
As part of the collaboration, HD Hyundai will provide critical support to Tampa Ship in vessel design, procurement of specialised equipment, and transfer of advanced shipbuilding technology. HD Hyundai will also participate in the fabrication of certain ship blocks and invest in key technical infrastructure to enhance the capability of Tampa Ship.
The signing ceremony was attended by Choi Hannae, Vice President, Head of Corporate Planning Division at HD Korea Shipbuilding & Offshore Engineering, and Dino Chouest, Executive Vice President of ECO.
Cheniere announces positive FID on Corpus Christi Midscale Trains 8 & 9
Cheniere Energy, Inc. has made a positive final investment decision (FID) with respect to the Corpus Christi Midscale Trains 8 & 9 and debottlenecking project (CCL Midscale Trains 8 & 9) and has issued full notice to proceed to Bechtel Energy, Inc. for construction of CCL Midscale Trains 8 & 9. CCL Midscale Trains 8 & 9 is being built adjacent to the Corpus Christi Stage 3 Project (CCL Stage 3) and consists of two midscale trains with an expected total liquefaction capacity of over 3 million tpy of LNG and other debottlenecking infrastructure. Upon completion of CCL Midscale Trains 8 & 9, and together with expected debottlenecking and CCL Stage 3, the Corpus Christi LNG terminal is expected to reach over 30 million tpy in total liquefaction capacity later this decade.
Cheniere also announced an updated run-rate LNG production outlook, which reflects an increase in the combined liquefaction capacity across the Cheniere platform at Sabine Pass and Corpus Christi by over 10% to over 60 million tpy inclusive of CCL Midscale Trains 8 & 9, CCL Stage 3, and identified debottlenecking opportunities across the platform.
In addition, Cheniere is developing further brownfield liquefaction capacity expansions at both the Corpus Christi and Sabine Pass terminals. The company expects these expansions to be executed in a phased approach, starting with initial single-train expansions at each site which, if completed, would grow Cheniere’s LNG platform to up to approximately 75 million tpy of capacity by the early 2030s.
LNGNEWS
USA
Chiyoda and McDermott agree terms for Golden Pass Trains 2 and 3
Chiyoda International Corp. and McDermott LLC, the construction JV partners for the Golden Pass LNG export project in Texas, the US, continue to progress work on the project.
McDermott and Chiyoda have continued co-operatives discussions with Golden Pass LNG Terminal LLC and have signed a binding term sheet addressing the key components of an agreement for completion of Trains 2 and 3 of the project.
When combined with the amendment of the EPC contact for the completion of the full scope of Train 1, and when converted into approved contract amendment, this term sheet addresses the full scope and commercial terms for completion of the project.
McDermott, Chiyoda, and Golden Pass LNG Terminal LLC will continue engagements to finalise amendment to the contract and will disclose when such agreements have been concluded.
USA Woodside completes Louisiana LNG sell-down to Stonepeak
Woodside has announced the completion of the sell-down of a 40% interest in Louisiana LNG Infrastructure LLC to Stonepeak, a leading global investment firm specialising in infrastructure and real assets.
The completion follows Woodside’s announcement on 7 April 2025 that it had signed an agreement with Stonepeak, enhancing Louisiana LNG economics and strengthening Woodside’s near-term capacity for shareholder returns.
Under the transaction, Stonepeak will provide US$5.7 billion towards the expected CAPEX for the foundation development of Louisiana LNG on an accelerated basis, contributing 75% of project CAPEX in both 2025 and 2026.
The closing payment of approximately US$1.9 billion received by Woodside reflects Stonepeak’s 75% share of CAPEX funding incurred since the effective date of 1 January 2025.
Finland
RMC delivers Spirit of Tasmania V to TT-Line
Rauma Marine Constructions (RMC) has delivered the second Spirit of Tasmania car and passenger ferry to TT-Line Company. The Spirit of Tasmania vessels are now the southernmost LNG-powered car and passenger ferries in the world.
Spirit of Tasmania (TT-Line Company Pty Ltd) ordered two car and passenger ferries from RMC for operation on the challenging open sea route between Geelong and Devonport in the Bass Strait of Australia. The first vessel was delivered in 2024, and now the Spirit of Tasmania V has also been completed.
The new high-speed Spirit of Tasmania vessels have been specifically designed for challenging sea conditions and will replace their predecessors built in Finland in the 1990s. They boast significantly higher passenger, vehicle, and freight capacity in comparison to the older vessels.
The total employment impact of the project has been more than 3500 person years.
This delivery completes one of the largest bilateral export projects ever between Finland and Australia.
THE LNG ROUNDUP
X Coastal Bend LNG initiates development of LNG export facility
X Centrica and PTT sign HOA for long-term LNG supply
X IEEFA: Strait of Hormuz disruption would jeopardise 10% of Europe's LNG imports
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Turbomachinery and Pump Symposia 2025 Texas, USA https://tps.tamu.edu
07 – 08 October 2025
Marine Fuels 360 Singapore www.marinefuels360.com
19 – 21 October 2025
Americas LNG Summit & Exhibition Louisiana, USA www.americaslngsummit.com
03 – 06 November 2025
ADIPEC Abu Dhabi, UAE www.adipec.com
02 – 05 December 2025
World LNG Summit & Awards Istanbul, Türkiye www.worldlngsummit.com
02 – 05 February 2026 21st International Conference & Exhibition on Liquefied Natural Gas (LNG2026) Ar-Rayyan, Qatar https://lng2026.com
Energy Transfer and Chevron sign SPA
Energy Transfer LP has announced its subsidiary, Energy Transfer LNG Export, LLC, has signed an incremental sale and purchase agreement (SPA) with Chevron U.S.A. Inc. for additional LNG supply from its Lake Charles LNG export facility. The 20-year agreement for 1 million tpy increases Chevron’s total contracted volume from Energy Transfer LNG to 3 million tpy, following the initial 2 million tpy agreement signed in December 2024.
As with the first SPA, the LNG will be supplied to Chevron on a free-on-board basis and the purchase price will consist of a fixed liquefaction charge and a gas supply component indexed to the Henry Hub benchmark. The obligations of Energy Transfer LNG under the SPA remain subject to Energy Transfer LNG taking a positive final investment decision, as well as the satisfaction of other conditions precedent.
Italy A2A and bp sign 17-year LNG SPA
A2A and bp have signed a sale and purchase agreement (SPA) for LNG, under which A2A will purchase up to 10 LNG cargoes (equivalent to approximately 1 billion m3 of natural gas) per year from 2027 – 2044.
The volume will be supplied to A2A on both a delivered ex-ship and a free on-board basis. Under the terms of the agreement, bp will provide A2A with LNG from its diverse, global portfolio. LNG will be received and regasified at the OLT Offshore LNG Toscana terminal in Livorno, Italy, where A2A has secured multi-year regasification capacity through an auction, as well as other terminals in Europe. The contracted LNG supply will meet around 20% of A2A Group’s demand.
Gas deliveries will begin in 4Q27, with a reduction in volumes starting from 2042.
The two companies will also work together to enable A2A to optimise shipping capacity for a portion of the volume. During the final years of the agreement, A2A expects lower domestic gas consumption, meaning part of the supply may be redirected to other markets.
USA
Glenfarne and PTT sign co-operation agreement
Glenfarne Alaska LNG, LLC has announced that PTT Public Company Ltd (PTT), the largest publicly traded company in Thailand, has signed a co-operation agreement for strategic participation in the Alaska LNG project, including for the procurement of 2 million tpy of LNG from Alaska LNG over a 20-year term. Alaska LNG is held under 8 Star Alaska, LLC, a joint venture between Glenfarne Group, LLC subsidiary, Glenfarne Alaska LNG, LLC, the majority owner and lead developer of Alaska LNG, and the Alaska Gasline Development Corporation. PTT is the publicly traded national oil and gas company of Thailand with a BBB+ investment grade credit rating.
The signing was witnessed by Thailand Permanent Secretary of Energy, Dr Prasert Sinsukprasert, and the US Ambassador to Thailand, Robert Godec.
The co-operation agreement defines the process for Alaska LNG and PTT to move towards definitive agreements for partnership on Alaska LNG, including long term LNG offtake.
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Jessica Casey, Editor, LNG Industry, highlights some key African LNG projects under development.
The Russian invasion of Ukraine, starting in February 2022, highlighted the overdependence of many countries on Russian natural gas, specifically in Europe. Three years on from the start of the conflict, companies are still looking for alternative ways to source their energy. One option is Africa –specifically North Africa – due to its proximity to Europe and abundant gas reserves.
The continent is rife with potential – according to the African Energy Chamber’s State of African Energy 2025 Outlook Report, Africa’s gas resources could support a four-fold increase in LNG export capacity (an increase from the current exports of approximately 40 million t to almost 175 million t by 2040).1
This was noticed by European investors and International Oil Companies, with numerous deals, memorandums of understanding, licensing rounds being pursued, and exploration and development by companies such as Eni, BP, and TotalEnergies.1 LNG developers, largely spearheaded by European oil and gas majors, are targeting almost 14 million tpy of new African liquefaction capacity by 2028.2
This project overview looks at some of these projects that have been proposed or are under development across Africa.
North Africa
Some of the largest LNG exporters in North Africa include Algeria and Egypt.
Algeria is one of the world’s largest exporters of LNG, and has a strong history in the market, with the first commercial shipment of Algerian LNG in 1964 to the UK and France. However, growing domestic gas consumption and increasing pipeline exports will likely put pressure on the country’s LNG feedstock supplies.2
Egypt already has LNG terminals in operation, with the first export of LNG in 2004. The country halted LNG imports in September 2018 after it reached self-sufficiency of gas, but declining outputs and increasing domestic demand means the terminals remain severely underutilised.3
Morocco
Morocco is looking to enter the LNG market with a liquefaction facility at the Tendrara field in the east of the country. Sound Energy’s Micro LNG project aims to bring gas supply to Morocco, reducing its reliance on imported LPG.
Currently, the country relies heavily on imported natural gas, with imports from Spain via the Gazoduc Maghreb Europe (GME) pipeline increasing 403% from 5.8 billion ft3 in 2022 to 29 billion ft3 in 2023.4 Gas is also planned to be sold to local power stations via pipeline links to displace the use of coal, which ties in to the country’s National Energy Strategy’s aim to introduce 3900 MW of new gas-fired power to replace coal.4
The project consists of an exploration portfolio across two locations and two gas developments within a single concession. Phase 1 consists of the development of Micro LNG and the completion of a central processing facility and LNG tank. Construction of the LNG tank commenced in November 2022, with the storage tank announced as nearing completion with the installation of an LNG cold box in March 2025.5 Phase 2 consists of the identification and approval of financing agreements, with first LNG delivery within 24 months of reaching a final investment decision (FID).
Micro LNG is preparing to produce LNG for the first time in the country’s history, starting in 4Q25. According to Sound Energy’s CEO, Graham Lyon, in an interview with Asharq, production trials are expected to begin in summer 2026, with commercial production expected to commence at 10 million ft3/d by the end of autumn and capacity expected to rise to 40 million ft3 in the future.6 There is also the potential to run operations onsite at Tendrara using renewable sources, which would further help the country reach its climate targets.
Turkish company, Karpowership, has also recently shown interest in helping bridge the country’s energy needs through floating LNG solutions, outlining the company’s vision during an interview at the Africa Energy Forum in South Africa.7
West Africa
Nigeria
Western Africa produces nearly half of the continent’s LNG. Nigeria is at the heart of this, contributing nearly two-thirds of West Africa’s LNG output and over one-third of the continent’s total.8 The region contains a large amount of undeveloped offshore gas resources, so countries like Nigeria might need to explore alternative solutions such as floating LNG (FLNG) and smaller scale LNG projects to capitalise on these resources and keep up with export and domestic demand.
However, production issues and vandalism have contributed to drops in annual liquefaction rates in
recent years. Nevertheless, despite Nigeria’s declining LNG production impacting West African exports, the region still contributed more than 60% of Africa’s LNG exports in 2024 –a total of 22.7 million t.8
Nigeria LNG
Nigeria LNG (NLNG) is a well-established project in the country. Growing from a two-train plant in 1999 to a six-train facility in nine years, the project is now looking at expanding its operations with the NLNG Train 7 project. The expansion will boost production capacity by 35%, taking it from 22 million tpy to 30 million tpy – an increase of 8 million tpy.9 The FID for the Train 7 project was made on 28 December 2019, with the EPC contract awarded to the SCD JV Consortium (affiliates of Saipem, Chiyoda, and Daewoo) in May 2020.
Mauritania and Senegal
In 2015, Kosmos Energy discovered an accumulation of natural gas offshore the countries.10 A Kosmos-BP partnership is developing the Greater Tortue Ahmeyim (GTA) project – the latest FLNG to start operations – located in water depths of up to 2850 m. After several delays, bp achieved first gas flow at GTA in January 2025,11 before transferring approximately 174 000 m3 of LNG to the British Sponsor LNG carrier from Golar LNG FLNG vessel located approximately 10 km offshore loaded for export in April 2025.12
Phase 1 of the project is expected to deliver approximately 2.5 million tpy. Further evaluation for Phase 2 has been confirmed, with the expansion project expected to add another 2.5 million tpy, doubling the total to 5 million tpy.13 The project is estimated to be approved at best in 2026.
East Africa
East Africa, particularly the countries of Tanzania and Mozambique, is emerging as a significant player in the global LNG market. Larger scale projects will account for the majority of the new facilities coming online in Mozambique, Tanzania, and Ethiopia.
Mozambique
Mozambique is currently the only major exporter of LNG in the region, and the newest producer of LNG. The country is estimated to have one of the largest natural gas reserves in Africa, and is aiming to become a major global LNG supplier.
Mozambique LNG
The Mozambique LNG project reached FID in 2019, and plans include the construction of two liquefaction units with a capacity of 13 million tpy, with a possible expansion capacity of up to 43 million tpy.14 The project is operated by TotalEnergies, with a stake of 26.5%, followed by Mitsui & Co. with 20%, and Mozambique’s state-owned ENH holding 15%. Indian state firms and Thailand’s PTTEP own the rest.15
The project has been in a state of force majeure since 2021, following violence in the area. However, Reuters has recently reported that Patrick Pouyanne, TotalEnergies CEO, revealed he expects the US$20 billion project to resume development “this summer” (2025) during a session at the Japan Energy Summit in Tokyo in June 2025,15 with production of LNG beginning in 2029.16 Mozambique’s Energy Minister has also said that he is optimistic about the company’s plan to
resume its development shortly, stating that the force majeure will be lifted as soon as TotalEnergies determines conditions are in place to resume operations.17
Rovuma LNG
The Rovuma LNG project is part of the development of large gas fields discovered in the Rovuma Basin, one of the largest of the past 15 years. The first phase of the project focuses on fields in the Mamba complex, and will be utilised by the construction of modular onshore liquefaction trains, resulting in an overall production capacity of 18 million tpy of LNG.18
XRG has recently announced its entry into the project, which includes stakes in the operational Coral South FLNG, the planned Coral North FLNG, and Rovuma LNG’s onshore development projects.19
The onshore Rovuma LNG Phase 1 project is being led by ExxonMobil, and is expected to complete its FEED phase in 2025.19 The FID for Rovuma was originally planned for the end of 2025, but has now been rescheduled for 2026.20
Coral South and North FLNG
Coral South FLNG is the first floating natural gas liquefaction unit built for the African continent, the third of its kind in the world, and has a capacity of 3.5 million tpy of LNG. Coral North FLNG development plans were approved by the Mozambique government on 8 April 2025, paving the way for an imminent FID.21 The expansion would produce an additional 3.5 million tpy of offshore LNG. Both projects are led by Eni.
The first cargo of LNG departed from the project in November 2022,22 and Eni celebrated its 100th LNG cargo from Coral South FLNG in April 2025.23 The project is expected to start production in 2H28.21
Tanzania
Tanzania LNG
Tanzania LNG is the largest gas project in Eastern and Southern Africa,24 and will position the country as a major LNG exporter. Tanzania’s Deputy Prime Minister, Doto Biteko, said the government wants to agree the terms of the natural gas facility with negotiators for the consortium comprising Shell, Equinor, and ExxonMobil by October 2025, when presidential elections are scheduled. Negotiations are still ongoing with discussions about issues including the authority’s demand that at least 3% of gas from the LNG project is reserved for domestic use.25 The project aims to reach FID in 2028.24
Conclusion
With global LNG demand forecast to increase by approximately 60% by 2040,26 Africa is well-positioned to help meet this growth. There may be some potential challenges to overcome, but the pipeline of projects planned or under development offer a positive outlook for the continent and its position within the global LNG market.
References
A list of this article’s references can be found on the LNG Industry website at: www.lngindustry.com/special-reports
Daniel
Patrick, Market Segment Manager – LNG & Hydrogen, Atlas Copco Gas and Process Division, outlines the role of integrally geared machinery in unlocking liquefaction performance.
LNG plays a critical role in global energy supplies, especially where pipeline infrastructure is limited or demand fluctuates seasonally. In recent years, the industry has seen growing momentum behind small scale LNG projects due to their lower capital requirements, faster deployment timelines, and suitability for remote and distributed applications. These include power generation for off-grid locations, LNG bunkering, marine fuelling, peak shaving, and virtual pipeline networks.
As LNG technology adapts to these new deployment models, efficient and scalable liquefaction solutions are essential. Refrigeration compressors, in particular, have a direct impact on plant performance, energy efficiency, and reliability. This article reviews two key refrigeration cycles
used in small scale LNG liquefaction: the reverse Brayton cycle and the mixed refrigerant cycle (MRC). In addition, it explores the role of integrally geared compressors (IGCs), turboexpanders, and companders, highlighting how these machines unlock performance, flexibility, and cost advantages. The article also briefly looks at the challenges and other considerations that plant engineers should take into account.
Refrigeration cycles for small scale LNG
Reverse Brayton cycle (nitrogen)
The reverse Brayton cycle is commonly used in land-based small scale LNG facilities, offshore applications such as
floating LNG (FLNG) and marine reliquefaction systems. Reverse Brayton cycles are characterised by a gaseous refrigerant (most commonly nitrogen), which is compressed and then expanded by one or more turboexpanders. The turboexpanders generate refrigeration through near-isentropic expansion, while a booster compressor re-compresses the process gas to recover the turboexpander’s shaft power (reducing the motor load). As nitrogen is non-toxic and readily available, it provides a safe and economical refrigerant option. Nitrogen’s molecular weight of 28.02 g/mol also provides high performance for the turbomachinery used in this cycle. The reverse Brayton cycle is favoured for its safety (using inert nitrogen), ease of start up, and operational flexibility.
Integrally geared machines, and especially companders, are well suited for reverse Brayton cycles due to their compact nature, high reliability, and ability to integrate the expander stages directly onto the gearbox for a single machine solution.
Mixed refrigerant cycle
MRCs use a tailored blend of hydrocarbons (e.g. methane, ethane, propane, butane) and nitrogen to provide continuous cooling across a broad temperature range. By leveraging the different boiling points of these components, MRCs closely match the natural gas cooling curve, resulting in higher thermal efficiency than single-component systems like nitrogen cycles. They also have reduced machinery complexity
as they utilise Joule-Thomson valves rather than expanders for the cooling step. The higher efficiency makes them the preferred choice for medium and large scale LNG applications.
MRCs, however, require more sophisticated refrigerant management. The refrigerant mixture must be constantly monitored to ensure the correct composition. As refrigerant is lost or consumed due to normal operating conditions, such as through machinery seals, refrigerant make-up must be added to maintain the specific mixture, otherwise the performance will suffer. For this reason, MRCs have some additional complexities that are not present in reverse Brayton cycles.
IGCs are well suited for MRC applications up to 1 million tpy per train, offering excellent stage-by-stage optimisation, intercooling, and a compact installation footprint.
Machinery configurations
Integrally geared compressors
IGCs consist of multiple high-speed pinions driven by a central bull gear, with each pinion supporting one or two compression stages. This architecture allows each stage to operate at its optimal aerodynamic speed, which enables higher polytropic efficiency and reduced power consumption. The ability to independently adjust impeller speeds enhances efficiency, reduces power consumption, and simplifies side-stream and intercooling integration. Compared to inline (barrel-type) compressors, IGCs offer a smaller footprint, lower weight, and shorter installation time. While barrel compressors require precise shaft and coupling alignment in the field, IGCs are typically delivered as pre-aligned, skid-mounted units.
At the Zhongtai small scale LNG plant in China, for instance, a 27 MW IGC was deployed in a mixed refrigerant cycle. This configuration provides high compressor efficiency and reliability while at the same time supporting fast installation and commissioning, something that is particularly important in such a remote region. The compressor was installed as part of a modular plant design, integrating the driver, seal gas, lube oil, and control systems into a single skid. This not only minimised on-site assembly, but also allowed the plant to be brought online faster, supporting local gas demand in a remote area with limited infrastructure.
Turboexpanders
Turboexpanders are a critical component in reverse Brayton cycles for their ability to deliver highly efficient refrigeration. The working fluid is accelerated through inlet guide vanes and directed radially into the impeller, where energy is extracted through a mix of impulse and reaction forces – depending on the specific aerodynamic requirements. Cryogenic turboexpanders produce cooling through near-isentropic expansion, reaching the low temperatures required for natural gas liquefaction. In traditional
Figure 2. Turboexpander with active magnetic bearings and energy recovery via a compressor.
Figure 1. The mixed refrigerant IGC package ready for shipment to the Zhongtai small scale LNG plant.
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expander-compressor configurations, the expander shaft power is recovered via a directly coupled booster compressor, which provides ‘free’ compression back to the cycle. In small scale LNG applications, turboexpanders offer several advantages: compact footprints that support modular design, mechanical simplicity that enhances reliability, and effective integration with the coldbox for efficient refrigeration and minimal heat ingress.
When paired with IGCs, turboexpanders can be incorporated into single-skid systems or even integrated into a compander, offering further footprint and efficiency gains. Their ability to handle rapid start-up/shutdown cycles also makes them ideal for applications with fluctuating demand, such as peak shaving or virtual pipeline systems.
Companders
A compander is a specialised machinery configuration that combines both compressor and expander stages on a single gearbox. This configuration utilises one oil system, one control system, and one seal-gas panel. This architecture is particularly advantageous in space-constrained or offshore LNG applications, where reducing equipment count and footprint is critical. The integrally geared technology offers great flexibility, particularly regarding the number of stages and stage arrangements that can be employed. As previously mentioned, the gearbox provides the speed flexibility, allowing each stage to be designed to the highest aerodynamic performance.
By integrating compression and expansion duties into one mechanical package, companders eliminate the need for separate foundations and additional interface points associated with standalone machines. Combined with shared auxiliary systems that further reduce site work, companders typically enable installation times that are about 25% faster than traditional configurations.
The nitrogen-based reverse Brayton cycle is the most common use case for companders, where the expander stage(s) provides cooling and shaft power, and the compressor stages drive the cycle. In a typical compander layout, one or two expander impellers are mounted on separate pinions with speeds optimised for maximum refrigeration. The corresponding compressor impellers are paired with the
expander stage (or additional pinion) that best matches its speed requirements. This allows each aerodynamic stage – whether for compression or expansion – to operate at its optimal speed.
Design flexibility is a key advantage. As each stage is independently mounted and driven, engineers can tailor performance characteristics to specific project requirements. This high level of customisation, along with the ability to deliver high turndown ratios and efficient partial-load operation, makes companders a compelling solution for marine and small scale LNG systems.
Opportunities and considerations for IGCs in small scale LNG
IGCs are ideal for distributed LNG infrastructure where standardisation, ease of transport, and modular deployment are priorities. Their ability to maintain efficiency at partial loads makes them suitable for peaking and variable demand applications. Regarding integrated services opportunities, a single IGC can handle multiple refrigerant loops (such as propane and MR) and accommodate side streams. IGCs can even incorporate expander stages on the same gearbox in a compander configuration, thanks to independent volutes and pinions. In addition, by design they offer fast installation, based on pre-packaged, pre-aligned skids that eliminate the need for complex field alignment and allow reduced commissioning time.
It is worth noting that the industry has reviewed and accepted IGCs for single train capacities up to 1 million tpy, while for larger capacities inline compressors may still be required (although at these sizes, the plant would no longer be classified as ‘small scale’). Ultimately, selecting the appropriate refrigeration cycle and machinery configuration requires careful consideration of plant capacity, site footprint, location, and operational requirements.
Conclusion
As LNG markets continue to evolve, small and medium scale liquefaction is becoming increasingly important to meeting distributed and remote energy needs. The growing momentum in recent years behind small scale LNG projects is due to their lower capital requirements, faster deployment timelines, and suitability for remote and distributed applications. IGCs offer a proven, efficient, and compact solution tailored to the specific requirements of these applications.
Their flexibility, modularity, and aerodynamic efficiency – especially in mixed refrigerant and nitrogen Brayton cycles – position IGCs as a key enabler of high-performance small scale LNG. IGCs also offer a smaller footprint compared to inline compressors, have lower weight, shorter installation time, and are typically delivered as pre-aligned, skid-mounted units. Paired with turboexpanders or integrated into compander systems, they support faster deployments, lower lifecycle costs, and reliable operation across a range of conditions. These benefits are clearly demonstrated in the Zhongtai small scale LNG project, which showcases the real-world performance and efficiency gains made possible by integrally geared designs – affirming their role in the future of LNG liquefaction.
Figure 3. Schematic of a nitrogen cycle compander configuration with two pinions (one expander and three compressor stages).
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Joseph Demonte, Teddy Tilahun, and Andrea Sutti, Emerson, explain how LNG poses significant challenges for control, isolation, and relief valve applications – which can be addressed with specially designed solutions.
The processing, storing, and transport of LNG has become a worldwide undertaking. LNG provides an economic means to move large quantities of low-carbon energy from producers to consumers, spurring the construction of massive LNG facilities across the globe. Processing, storing, and transporting LNG requires a host of control, isolation, and relief valves,
and these valves must perform reliably under very challenging conditions.
Cryogenic temperatures push materials to their limits, while requirements for tight shut-off isolation and fugitive emissions containment are increasingly demanding. Failure in any of these areas can pose significant safety risks, while increasing operational and capital costs.
This article uses success stories from real-world applications to show how control valves, isolation valves, and relief valves have proven themselves in LNG applications. This equipment has saved significant capital costs, improved production efficiency, and reduced maintenance costs by providing improved performance and longer service life.
LNG service
Natural gas provides an immediately available supply of low-carbon energy. However, producers and consumers are often widely separated, so some means of long-distance
transport is required. Overland transfers can utilise pipelines because pressurised gas moves easily in this medium. However, when intercontinental transport is necessary, the preferred solution is LNG since that product is much better suited for transportation by ship.
LNG terminals serve as the interface between LNG ships and pipelines (Figure 1). An outgoing LNG terminal accepts pipeline gas from producers, liquefies it, and stores the product until ships arrive for loading. Receiving LNG terminals reverse the process, accepting LNG from ships, storing it as necessary, and ultimately vaporising and pressurising the gas for pipeline transport.
LNG operations are typically quite large and involve both onshore and offshore facilities operating in a difficult marine environment. Most facilities have a multitude of massive LNG storage tanks and a forest of automated valves and interconnected piping to quickly move product between the ships and pipelines. The main challenges of the LNG process include extremely low temperatures, very large piping sizes, a need for reliable seal off and isolation, and very tight emission limits. To satisfy these requirements, specialised equipment designed for this service is necessary.
Cryogenic applications
The boiling point of LNG is -162˚C at atmospheric pressure, so LNG applications often involve cryogenic temperatures at or below that value. Such temperatures pose obvious challenges associated with material selection, and off gassing, high velocities, and two-phase flow are commonly encountered since the product is often operating close to boiling point.
Gas liquefaction is made possible by pressurising the gas, cooling it, then quickly reducing the pressure to sub-cool it further via the Joules-Thomson (J-T) effect. As the gas undergoes continued pressure/de-pressure cycles, the temperature continues to fall until the gas eventually reaches cryogenic temperatures and condenses to a liquid. Very tight control of these energy intensive operations is imperative for efficient operation, and J-T control valves are critical for this application.
J-T valves operate in parallel with the turboexpander and provide a means to fine tune the liquefaction process by making immediate and precise adjustments as required to minimise energy usage. The application is punishing on control valves because it involves temperatures at or below -157˚C, as well as very high pressure drops, high vibration, and extreme vapour velocities.
Poorly performing J-T valves force site personnel to revert to manual control and greatly reduce process efficiency. Since liquefaction operations are one of the more energy consuming operations on the site, this can have enormous negative implications. Higher performing J-T valves must handle 50 bar pressure differentials, yet still provide 0.0625% step change resolution at -185˚C.
At one site, J-T valve replacement not only generated significant operational savings, but it also increased terminal throughput, allowing an additional LNG ship to be loaded per month. The energy savings alone were enough to justify the cost of a replacement valve, but the production increase paid off the investment in very short order.
Figure 1. LNG terminals transfer product between oceangoing ships and pipelines. Most terminals are massive in size and include onshore and offshore facilities, and large storage tanks.
Figure 2. Emerson supplied a number of triple offset valves for the world’s largest LNG plant.
Isolation valve applications
Proper isolation valves are mainstays of LNG terminal operations. Transfer piping runs between a multitude of storage tanks, ships, and pipelines, and product is continuously diverted and pumped from location to location. Isolation valves for this service face cryogenic temperatures and variable pressures, and they must work reliably while providing very tight shutoff and fugitive emissions containment to enable efficient and safe operations.
The critical importance of isolation valves in LNG operations is exemplified by the world’s largest LNG project to date, where over 2000 Emerson Vanessa triple offset valves (TOVs) were installed. This Middle Eastern facility, featuring four LNG mega trains with a combined capacity of 32 million tpy, demonstrates the scale of modern LNG operations.
TOVs are the workhorse for this application, providing reliable tight shutoff with minimal flange-to-flange dimensions. TOVs are offered in a broad selection of pipe sizes and flange ratings, and in larger facilities, TOV sizes can be quite large. In fact, the world’s largest TOVs were created for this Middle Eastern facility, including 66-in. double-flanged cryogenic valves customised for Class 600 piping, and huge 120-in. and 126-in. double-flanged valves in more basic configurations (Figure 2).
These valves incorporate advanced emissions-capture technologies to address one of the industry’s primary concerns: fugitive emissions from valve equipment. The valves were specifically engineered to meet and exceed the most stringent requirements for operability, tightness, and safety in LNG applications. The actuators were also custom designed, with electric actuator gears featuring mirroring shapes for easy installation, and pneumatic actuators tailored to meet specific valve and process requirements.
Thousands of these valves are reliably operating in LNG terminals across the world. TOVs are available with customised actuator configurations for space constrained, offshore facilities, and they utilise specialised actuator coatings for marine environments. They can also be provided with very low emission packing to keep product loss and fugitive emissions to nearly undetectable levels.
The success of this TOV solution in the world’s largest LNG facility has led to their selection for the facility’s two-train expansion, further validating their performance in critical applications. Their long service life, tight shutoff performance, and very low fugitive emission losses provide efficient, safe, and profitable terminal operations at many sites worldwide.
Storage tank relief valves
Most LNG terminals rely on a number of very large tanks to store product awaiting ship loading or transfer to pipelines. A critical component of these tanks are the relief valves that protect the tanks from overpressure. If the cooling system of an LNG tank fails, the tank will slowly heat up and generate increasing amounts of vapour. Should a fire occur, the boiling liquid within the tank will generate vast quantities of natural gas, which must be safely piped away to avoid tank failure. However, during normal operations, the relief valve must seal tightly to avoid needlessly venting product away.
As terminals incorporate larger and larger storage tanks into their designs to improve efficiency, the relief valve gas load for any given tank becomes enormous. Often a tank must rely on several relief valves to provide the necessary flow capacity.
To address these issues, very high-capacity pilot-operated relief valves have been designed for LNG service and marine environments (Figure 3). The pilot valve provides an extremely precise opening at setpoint, so the relief valve remains essentially leak-free up to 95% of setpoint. Once the setpoint is reached, the pilot valve actuates to open the main valve, providing very high flow capacity. Once the overpressure event has passed, the valve consistently reseats to again form a leak-free seal.
Tight shutoff to within 5% of setpoint keeps product loss and environmental emissions to a minimum, and the extremely high flow capacity of this model allows a single tank to be fully protected with far fewer relief valves. The reduced number of devices saves capital costs of the devices themselves, and it also provides significant installation savings since the tank requires far fewer tank penetrations and roof supports. In one application, the reduced installation costs alone totalled over US$260 000 when compared to the next higher capacity relief valve.
Choose wisely
The design team for an LNG terminal construction or expansion project would be wise to carefully consider the key control components required for their process. Critical control valves, such as J-T valves, enable very tight process control and maximise production throughput and efficiency. Reliable TOVs ensure efficient and safe operations and provide long service life, while minimising fugitive emissions. When very large LNG storage tanks are involved, high-capacity tank relief valves provide dependable tank overpressure protection, while reducing installation costs and keeping product loss and fugitive emissions to an absolute minimum. When taken together, these carefully designed devices are proven in use to significantly improve LNG terminals’ bottom line.
Figure 3. Extremely high-capacity relief valves, like Emerson’s Anderson Greenwood 9300H low pressure pilot operated relief valves, save significant capital since multiple valves are not required for very large LNG storage tanks.
Sukhpal Basi, Principal Process Engineer, KBR, discusses how the LNG industry can move towards a more sustainable footing by focusing on decarbonisation of the LNG value chain via energy efficiency improvements and emissions reduction.
The global LNG industry continues to expand as natural gas plays a key role in the energy transition, serving as a bridge between carbon-intensive fuels and renewable energy sources. It is known that LNG has long been marketed as a cleaner energy alternative, but in LNG it is now being recognised that continued reliance on carbon-based fuels does not provide the solution to climate change. Instead, LNG stands as a stepping stone in terms of a sustainable future.
In the short term, demand for LNG will continue to grow as part of the drive to displace ‘dirtier’ fuels from industrial and domestic consumption, before LNG itself is eventually replaced by renewable technology. This positions LNG as a transition fuel that bridges the gap between oil and coal and future cleaner renewable energy sources.
The range of LNG demand forecasts shows considerable uncertainty in a rapidly evolving energy landscape. Meanwhile, pressure from activists and investors to accelerate the decarbonisation of existing portfolios has led some companies to market ‘green LNG’ or ‘carbon-neutral’ LNG cargoes. But, what do these terms mean and how reliable are the credentials of this cleaner LNG?
The LNG value chain emissions challenge
LNG value chain emissions can be broadly split into downstream emissions, which typically account for about 75% of the total, and other emissions across the upstream, liquefaction, and transportation segments. These figures are not set in stone
though – actual emissions vary significantly depending on the source and quality of feed gas, liquefaction facility configuration, distance to market, and regasification technology used.
Two main approaches have emerged to produce cleaner LNG cargoes:
z Carbon-neutral LNG: Offsetting greenhouse gas (GHG) emissions generated across the LNG value chain through mechanisms that balance emissions against carbon removal projects (like reforestation) or GHG avoidance (such as wind farms). This approach does not necessarily reduce actual emissions in the operation of the LNG value chain.
z Green LNG: Reducing LNG carbon intensity can be achieved by minimising GHG emissions across the value chain. This approach does not eliminate emissions, but reduces them through specific measures designed to maximise thermal efficiency at each link in the value chain.
The growing demand for greener LNG stems from the environmental, social, and governance (ESG) requirements of both buyers and sellers. However, many lobbyists have started to label carbon offsetting as ‘greenwashing’ – seeing it as a quick fix to meet net zero goals by buying credits instead of investing in operational efficiency, technological innovation, or renewables integration.
A typical LNG cargo of 70 000 t equals about 200 000 t of carbon dioxide (CO₂). Carbon offset credits have historically cost between US$1 – US$10/t of CO₂, but with large price swings possible. More critically, buyers paying a premium for green LNG increasingly want verification through monitoring, reporting, and verification systems.
In a comparative study that benchmarked the CO₂ emissions of nine facilities delivering LNG to northeast Asian power generation markets, the distribution of CO₂ emissions varied significantly across different segments of the value chain. Upstream carbon emissions ranged from a mere 0.1% in the best case to almost 38% of the entire chain’s emissions, while liquefaction-based emissions varied from 5% – 21%.
Given this variability, it is crucial to identify emission sources throughout the LNG value chain to develop targeted, cost-effective mitigation strategies for each segment.
Planning for sustainability from design stage
When approaching a new LNG facility design, incorporating sustainability principles from the earliest planning stages is key to creating a greener value chain. The performance of an LNG plant hinges on numerous factors, from feed gas composition and inlet conditions to liquefaction technology selection, cooling medium, and equipment design choices.
The technology then comes into the design stage to minimise the carbon footprint of a new LNG facility. There are various examples of technology which can be applied at this stage.
z Electric motors: Electric motors offer efficiency, reliability, and operational simplicity, with fewer outages and longer maintenance intervals. Large electric motors with variable frequency drives allow refrigerant compressors to restart from settle-out conditions without depressurisation, avoiding refrigerant loss to the flare. This not only reduces emissions during restart events, but improves overall plant reliability.
z High-efficiency gas turbines: These turbines have powered liquefaction facilities for decades. Switching to high-efficiency aeroderivative gas turbines can improve thermal efficiency by 10% compared to heavy-duty industrial gas turbines (44% vs 34%). Their wide operating speed range offers greater flexibility for turn-down operations while maintaining efficiency across both the compressor and gas turbine.
z Heat recovery systems: Installing heat recovery systems on gas turbine exhausts boosts plant thermal efficiency. This can be further enhanced with heat recovery steam generation (HRSG), using steam to drive turbines and provide heating.
z Vacuum insulated piping: LNG transfer lines between storage tanks and offloading facilities can use vacuum insulated piping – a pipe-in-pipe system that reduces heat gain tenfold compared to conventional insulation. This minimises boil-off gas generation and improves thermal efficiency, particularly in large complexes with extended jetties.
z Hydrogen blending: Reducing carbon footprints through hydrogen blending into the fuel gas network presents another option. Current gas turbines and fired equipment can typically handle up to 20% hydrogen by volume without combustor modifications. While existing facilities face infrastructure challenges for safely managing high-purity hydrogen, new designs can incorporate this capability from the start.
z Off-specification gas recycling: During start-up, considerable quantities of off-specification feed gas are typically flared until meeting required specifications. Designing systems from the outset for recycling this gas back to the inlet during start-up or other transient operations can significantly cut emissions.
z Refrigerant recovery systems: Purpose-built refrigerant recovery systems can capture refrigerant to storage (for later reuse) or re-inject hydrocarbons into LNG product, avoiding flaring during maintenance or after compressor trips.
z Carbon capture, utilisation, and storage (CCUS): The largest carbon emissions within an LNG facility come from acid gas removal units and fired equipment. Designing for pre-combustion capture of acid gas streams is economically viable and increasingly considered for new projects. Facility layouts can also be optimised during design to accommodate post-combustion CO₂ capture from gas turbine exhaust stacks.
Incorporating these technologies at the design stage enables new LNG facilities to achieve significantly lower emissions than retrofitted existing assets. For new facilities, carbon intensity analysis during pre-FEED studies helps understand the relationship between CO₂ intensity and facility cost (t of CO₂/t of LNG vs US$/t of LNG).
Improving existing assets and the economics of greener LNG
While designing new facilities for minimum emissions offers the greatest potential for carbon reduction, improving the performance of existing assets presents a different challenge.
The emissions profile of any facility stems from its equipment type, process configuration, and operational practices. When comparing LNG facilities, CO₂ intensity serves as a common metric for energy efficiency and emissions performance.
Three key strategies can improve CO₂ intensity for existing facilities:
z Improving energy efficiency.
z Increasing LNG throughput by removing bottlenecks to utilise all installed margins.
z Reducing trips and restarts to minimise flaring and achieve higher annual production.
Identifying efficiency improvements requires a thorough understanding of facility design and operating philosophies, current practices, and potential design enhancements that improve efficiency without major changes or costs.
A systematic approach to finding and quantifying opportunities involves initial data gathering, joint workshops with engineering and operations experts, opportunity screening using assessment matrices, and detailed assessment of the most promising ideas. For many opportunities, simulation models of the entire LNG process help determine relative differences in power requirements, fuel gas consumption, and thermal efficiency.
The economic assessment can assign value to CO₂ emissions and/or fuel gas based on carbon taxes, carbon credit costs,
feed gas costs, or LNG prices. As buyers increasingly demand verifiable green LNG cargoes, operators who can demonstrate actual emissions reductions rather than just purchasing offsets may command premium pricing in the market. This premium creates a market-driven incentive for investing in emissions reduction technologies and operational improvements.
Forging a sustainable path for LNG
Achieving truly green LNG through actual emissions reduction rather than carbon offsetting demands a concerted effort to examine both the operation and design of assets. While existing facilities realistically cannot achieve the CO₂ intensity of purpose-built low-emission plants, significant improvements remain possible with the right approach.
For new facilities, incorporating sustainability principles from the earliest design stages offers the greatest potential for minimising lifecycle emissions. By carefully selecting technologies and configurations with emissions reduction in mind, operators can substantially reduce their carbon footprint while maintaining operational efficiency.
As LNG continues its role as a transition fuel in the global energy mix, demonstrating commitment to emissions reduction through both new designs and retrofits of existing assets will be crucial to maintaining the industry’s social license to operate. Through methodical analysis, appropriate technological choices, and ongoing performance monitoring, the LNG industry can steadily reduce its carbon intensity while supporting the world’s journey towards a more sustainable energy future.
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Rupesh Parikh, Sales Director, Global Accounts at Rockwell Automation, untangles the complicated nature of LNG’s position in the energy transition and illuminates how LNG can continue to evolve in a changing global market.
LNG has long been a cornerstone of the global energy market, bridging traditional fossil fuels and the promise of a low-carbon future. Its role, however, remains the subject of intense debate.
Supporters argue that LNG provides essential energy security while reducing emissions compared to coal. Critics point to methane leakage and carbon intensity as critical concerns that could undermine
its sustainability credentials. As the energy transition accelerates, LNG’s position is under increasing scrutiny, with regulatory pressures and technological advancements shaping its future.
LNG’s strategic importance is undeniable. The sector has experienced substantial investment, particularly as
geopolitical tensions have disrupted supply chains and altered global energy dynamics. For instance, the shift away from Russian gas in Europe has driven significant demand for LNG imports, prompting nations to bolster their LNG infrastructure. Policy incentives have further stimulated production in the US, solidifying its role in the international market. Yet, the question remains: is LNG a long-term solution or a temporary fix on the way to a greener energy mix?
The environmental equation and regulatory challenges
Despite its reputation as a cleaner alternative to coal, LNG’s environmental impact remains a focal point of industry discussion. While it produces lower carbon dioxide (CO 2 ) emissions than traditional fossil fuels, methane leakage during extraction, transport, and processing threatens to erode these benefits. The industry has acknowledged these challenges, leading to advancements in extraction methods and the reduction of routine flaring. However, concerns persist, mainly as methane is significantly more potent as a greenhouse gas than CO 2 over the short term.
Regulatory frameworks are evolving rapidly in response. New methane emissions reporting requirements and carbon pricing mechanisms are increasing scrutiny on LNG operators, demanding greater transparency and accountability. Governments and international bodies are pushing for stringent emissions reductions, prompting companies to accelerate their sustainability efforts. The ability to precisely monitor and mitigate point-source emissions has improved, allowing real-time adjustments to reduce environmental impact. Nonetheless, compliance with these regulations requires investment and an operational shift towards smarter, more automated solutions.
In addition to emissions regulations, governments are implementing policies to encourage the development of carbon capture and storage (CCS) technology in the LNG sector. CCS has the potential to significantly reduce the carbon footprint of LNG production by capturing emissions before they are released into the atmosphere. Although still in its early stages of widespread implementation, CCS is gaining traction as a necessary step in making LNG a more viable part of the energy transition. The challenge lies in ensuring that CCS projects remain economically feasible and scalable across different LNG operations.
The role of automation in compliance and efficiency
As regulatory pressures mount, digitalisation and automation have emerged as critical enablers of compliance and efficiency in LNG operations. The complexity of modern LNG facilities necessitates advanced process control, real-time monitoring, and predictive analytics to optimise performance while reducing emissions. Rockwell Automation
Figure 1. Digital transformation in LNG operations enhances real-time monitoring and compliance.
Figure 3. Rockwell Automation’s integrated controls, helping to meet sustainability and regulatory goals.
Figure 2. LNG facilities leverage automation to optimise efficiency and reduce emissions.
EPISODE EIGHT
In this episode, Juan Caballero, Chair of the AMPP Board of Directors, talks about AMPP’s global efforts to prevent corrosion and to protect assets, offering insight into how the association listens to its members and serves the pipeline industry.
Juan shares his insights on:
• The merger of NACE with SSPC to form AMPP.
• Materials protection challenges in 2025.
• AMPP’s training programmes, including a sneak peek into the newest offerings.
• Industry trends and how AMPP views sustainability.
• Which certifications are currently in demand.
• Digital learning for pipeliners.
• Regulations that we need to pay attention to now.
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has played a significant role in this transformation, providing integrated solutions that enhance visibility, efficiency, and safety across the LNG value chain.
Artificial intelligence (AI) and cloud-based automation reshape LNG operations, allowing centralised monitoring and remote process adjustments. Operators can minimise manual interventions by implementing closed-loop automation systems, ensuring consistent environmental performance across multiple sites. For instance, Rockwell’s PlantPAx distributed control system (DCS) enables LNG facilities to integrate real time data analytics with process control, facilitating better decision-making and optimised energy use.
Advanced process control and digital twins are also redefining how LNG plants operate. Digital twins, virtual replicas of physical assets, allow operators to simulate and test process optimisations before implementing them in live environments. Rockwell’s expertise in this area has enabled LNG producers to achieve greater operational flexibility while maintaining strict environmental standards. The ability to continuously monitor emissions and adjust operational parameters in real time represents a significant leap forward in LNG sustainability efforts.
Energy efficiency improvements are another major focus area for LNG operators. Optimising heat exchange systems, reducing energy consumption during liquefaction, and integrating renewable energy sources into LNG operations are all gaining attention. Rockwell Automation’s solutions facilitate energy efficiency by enabling precise process control, reducing waste, and improving the overall thermal efficiency of LNG facilities. Smart grid integration and demand-response strategies further enhance the sustainability of LNG operations by aligning energy use with grid conditions and renewable energy availability.
Case study: Digitalisation driving LNG efficiency
A Middle East-based national oil and gas company recently leveraged Rockwell Automation’s digital solutions to integrate automation across multiple LNG production sites. Facing the challenge of maintaining efficiency while adhering to stringent environmental regulations, the company implemented a unified digital platform incorporating real-time monitoring and advanced analytics. The result was significantly reduced engineering hours, streamlined regulatory compliance, and improved emissions tracking. Deploying a centralised remote operation centre further enhanced process efficiency, allowing for predictive maintenance and reduced operational downtime.
Another example comes from a global energy company transitioning towards lower-carbon operations. The company adopted Rockwell’s Integrated Control and Safety System (ICSS), smart motor control, and SCADA remote monitoring to optimise LNG production. This approach enhanced operational safety and reduced emissions from traditional flaring processes, contributing to corporate net-zero commitments. The success of these projects underscores how digital transformation is essential for the LNG sector to navigate environmental and regulatory challenges effectively.
Cybersecurity and the increasing digital footprint
Cybersecurity has become a pressing concern as LNG facilities become more digitally connected. Integrating automation and cloud-based control systems exposes operators to new vulnerabilities, making robust security measures imperative. Cyber threats targeting critical infrastructure, including LNG terminals and transport networks, pose significant risks that could disrupt supply chains and impact global energy markets.
Rockwell Automation has recognised this challenge, investing heavily in cybersecurity solutions tailored for the LNG sector. The company has developed a dedicated operational technology cybersecurity consulting practice, helping LNG operators safeguard their digital assets. Secure automation frameworks and regulatory-driven cybersecurity policies are now essential components of modern LNG operations. With the potential for cyberattacks on energy infrastructure increasing, ensuring resilience against digital threats has become a strategic priority.
AI-driven security solutions are also becoming integral to LNG operations. Machine learning algorithms can detect anomalies in real time, identifying potential cyber threats before they cause harm. By integrating AI into cybersecurity frameworks, LNG operators can proactively manage risks, ensuring safety and reliability. This level of protection is critical as the sector continues to digitalise and interconnect more systems.
The path forward and LNG’s evolving role
The future of LNG is intricately linked to broader energy transition strategies. While it remains a key transitional fuel, its longevity in the global energy mix will depend on policy developments and technological advancements. The emergence of alternatives such as green hydrogen presents a potential long-term replacement, but widespread adoption remains distant due to challenges in production, transportation, and storage.
LNG operators must focus on maximising efficiency, minimising emissions, and navigating an increasingly complex regulatory landscape. Automation and control system standardisation will be crucial, particularly for new LNG projects. Rockwell Automation advocates open process automation, enabling operators to integrate diverse technologies without vendor lock-in. The LNG sector can ensure it remains relevant in the evolving energy landscape by leveraging AI, digital twins, and advanced process control.
The global energy transition is unfolding at an unprecedented pace and LNG’s role will continue to evolve. While it may not be the final destination, its contribution as a stabilising force in the shift towards cleaner energy cannot be overlooked. For LNG to maintain its place in the transition, innovation and sustainability must go hand in hand, ensuring it remains an asset rather than a liability in pursuing a low-carbon future. The key to success will be ongoing investment in technology, enhanced regulatory co-operation, and a commitment to reducing the environmental footprint of LNG production and consumption.
Kara Boyer, Director of Client Solutions, Lisa Czyszczewski, Vice President of Growth Strategies – Data Solutions, and Ken Min, Executive Director of Asset Integrity Services, MISTRAS Group, Inc., identify how risk-based inspection can optimise LNG plant performance and costs.
As the global LNG market continues to expand and infrastructure ages, ensuring operational safety, reliability, and cost-efficiency becomes increasingly important.
Risk-based inspection (RBI) is a powerful practice that supports these goals by assessing risk to identify high-risk assets and prioritising in-service inspections.
What is RBI?
RBI is a systematic process that combines engineering knowledge, equipment design, operational data, inspection history, and risk analysis to determine how often and how thoroughly to inspect pressure equipment. Instead of following fixed interval guidance for inspection, RBI focuses inspection efforts on equipment with higher likelihood and/or consequence of failure.
As opposed to a traditional time-based inspection approach, where the inspection and test intervals are using generic fixed intervals for all assets (e.g. internal visual inspection every 10 years), a risk-based inspection approach instead evaluates the risk for each asset and determines the appropriate interval that is tailored to that risk.
RBI is typically implemented using industry standards such as API RP 580 and API RP 581, and may include either qualitative or semi-quantitative risk assessment methods. The consequence assessment should consider process safety hazards such as fire, explosion, toxicity, and environmental exposure, and may also consider business interruption consequences such as lost production following a failure. LNG facilities in the US may be covered by the U.S. Department of Transportation’s (DOT) pipeline safety regulation, 49 CFR Part 193, or by OSHA’s Process Safety Management (PSM) Standard 29 CFR § 1910.119. Regardless of coverage, the operating company can improve process safety and environmental performance by implementing best practice programmes utilising in-service inspection, including RBI as described by API RP 580.
Why RBI is valuable for LNG plants
LNG plants are complex and capital-intensive, involving high-pressure systems, cryogenic temperatures, and flammable materials. These characteristics make asset integrity and process safety management a key priority. The systematic processes included in RBI assessments are helpful in improving asset integrity performance in a cost-efficient way. A powerful benefit of RBI is providing confidence to shift budgets to provide strategic attention to high-risk assets. This article will explore the key benefits that the facility can realise as part of the RBI programme:
1. Enhanced process safety.
2. Cost effectiveness and efficiency.
3. Improved plant availability/reliability.
4. Support digital transformation.
5. Facilitate knowledge transfer and integrity programme maturity.
Key benefit 1: Enhanced process safety
Safety is a top priority for local and global organisations alike. The consequences of loss of containment events in an LNG plant can be catastrophic, ranging from gas leaks and fires to large scale explosions. Traditional time-based inspection programmes (e.g. performing intrusive internal inspections every 10 years) may not adequately identify active damage mechanisms, susceptibility to damage, or cost-effective inspection alternatives that can help prevent failures.
By assessing both the likelihood of failure (e.g. due to corrosion, mechanical fatigue, or metallurgical embrittlement) and the consequences of failure (e.g. safety, environment, or financial), RBI ensures a more precise and meaningful basis for each inspection event.
Key benefit 2: Cost effectiveness and efficiency
Most pressure equipment inspection programmes devote considerable resources to inspecting assets that are either unlikely to fail or would not cause severe consequences if they did. By reducing maintenance spending on low-risk assets, resources can be reallocated to increasing inspection on high-risk assets, leading to both cost improvement and process safety improvement. By focusing on risk reduction rather than time-based schedules, RBI provides more flexibility in the timing of inspections to align with maintenance outages driven by other reasons. This flexibility can also improve the profitability of many facilities by allowing optimisation of the maintenance outage timing.
Although RBI is typically initiated to improve process safety performance, it naturally improves uptime and can specifically target minimising reliability losses to a facility. Unplanned downtimes at LNG facilities can disrupt production schedules, contractual obligations, and supply chains. RBI helps to reduce the opportunity for unplanned downtime by:
z Identifying and quantifying degradation trends: By considering historical data and consolidating operational experience, RBI assessments can highlight changes that may lead to unexpected failures.
z Preventative maintenance: RBI assessments often lead to modification or development of maintenance plans, including upgraded material, replacements, or other maintenance activities that extend life and optimise maintenance costs.
Figure 1. RBI is a systematic process that uses engineering knowledge, design data, and risk analysis to help plants identify and prioritise high-risk assets, enabling smarter resource allocation.
Figure 2. This asset integrity maturity model outlines the evolution from reactive maintenance to world-class asset management. An RBI programme often serves as the catalyst for progress by strengthening culture, technology use, and institutional knowledge.
z Predictive maintenance: RBI is typically implemented with complementary programmes such as establishing integrity operating windows (IOWs) and real-time corrosion or cracking sensor monitoring, which can alert personnel to inspect for accelerated damage ahead of a potential loss of containment event.
Key benefit 4: Support for digital transformation
As the energy sector embraces digital transformation, RBI can serve as a key enabler for technologies like IoT, digital twins, and artificial intelligence (AI)-driven analytics.
Many facilities following a traditional calendar-based inspection programme do not store all equipment data and inspection results in a structured database, limiting the application of more advanced digital tools. RBI programme rollouts typically include structuring and standardising data in digital formats that can be leveraged for other business/operational purposes. As an example, it is possible to provide data-driven flexibility on operating windows to improve production when RBI data is available by predicting corrosion susceptibility and changes in risk levels for various operating scenarios.
Key benefit 5: Facilitates knowledge transfer and integrity programme maturity
Several features of RBI improve the retention of critical asset integrity information at LNG facilities, supporting personnel knowledge transfer and the maturity of an organisation’s mechanical integrity programme. These include:
z The damage mechanism review (DMR) process (an input for the RBI assessment) is an opportunity for sharing historical experience across the operational team. Engineers, operators, and maintenance staff all typically acquire critical information to allow for data-driven decision-making through this exchange.
z Documentation of degradation mechanisms and failure history occurs as part of the RBI assessment and can help ensure that infrequent events are not overlooked (or lost) as turnover occurs.
z Standardising risk evaluation criteria across teams and sites is another common outcome of the RBI process, as teams seek to communicate in common terms to support effective and collaborative decision making.
The maturity in Figure 2 demonstrates typical milestones for operating facilities in their asset integrity programmes. Several factors come into play to progressing through the maturity map such as facility culture, available technology/tools, and knowledge base of the site personnel and the industry. An RBI programme commonly acts as the catalyst in improving in those factors.
Real-world application of RBI in LNG plants
Many major LNG operators have already embraced RBI as a part of their operating philosophy. For example:
z QatarEnergy has implemented RBI to optimise maintenance in its Ras Laffan LNG facilities, resulting in extended inspection intervals and reduced turnaround times.
z Chevron’s Gorgon project in Australia has used RBI in combination with digital twins to manage asset integrity in its liquefaction trains and subsea infrastructure.
z Shell has applied RBI in its Prelude floating LNG (FLNG) project to manage risks associated with FLNG production and storage.
MISTRAS is working with other LNG operators to develop comprehensive RBI programmes that lead to improvements in process safety cost and operational efficiency with significant return on investment.
Challenges and considerations
While RBI offers numerous benefits, implementation requires overcoming certain challenges. It can be helpful for facilities to work with third-party SMEs, such as MISTRAS Group, with expertise in RBI implementation and analysis to help navigate these common, but solvable, challenges:
z Data quality and availability: Accurate input data is critical, and can be costly to consolidate in a software package. Additionally, data such as operational conditions may be restricted due to data security practices. RBI service providers are familiar with these challenges and can offer options for streamlining the process.
z Change management: Shifting from time-based to risk-based inspection may require cultural and procedural adjustments. Many facilities have found that starting slow, with a pilot approach, and building momentum as the value case is established, is a helpful framework for beginning an RBI programme with site specific justification.
z Training and expertise: Personnel must be skilled in RBI methodologies, tools, and technologies. Service providers can usually provide subject-matter expert engineers and technicians familiar with RBI, corrosion, materials, and pressure equipment design to facilitate the process, and can provide training for the LNG operator’s employees.
z Ongoing maintenance: Risk profiles must be updated regularly to reflect new data and changing operating conditions. Some service providers, such as MISTRAS and its asset performance management (APM) software, PCMS®, may offer services to handle ongoing evergreening of RBI.
To maximise value, RBI should be treated as an ongoing process, not a one-time exercise.
Conclusion
The RBI framework has been evolving for decades and has been proven to improve process safety, reliability, and maintenance cost efficiency by a large number of operating companies in the oil and gas sector. For LNG operators facing growing complexity, regulatory scrutiny, and competitive pressures, RBI is not just a best practice – it is a business necessity.
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Leakhena Swett, President, ILTA, and Jay Cruz, Senior Director of Government Affairs and Communications, ILTA, consider the importance of trade associations and industry collaborations.
EPISODE 7
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EPISODE 8
In this special episode, a panel of experts from Johnson Matthey, A.P. Moller - Maersk, Honeywell, HIF Global and the Methanol Institute provide a clear analysis of the factors influencing e-fuel pricing, the economic challenges, and strategies for cost reduction.
EPISODE 9
Brandon Stambaugh, Owens Corning Director for Technical Services, discusses engineers’ demand for education and training to support three critical phases that affect the performance and longevity of insulating systems.
66 LogisTech (Ningbo) Co., Ltd, considers how artificial intelligence is transforming the assessment and management of liquid cargo such as LNG, monitoring and safeguarding goods for owners and investors in real time.
In the global trade of liquid bulk commodities, such as fuels like LNG, petrochemicals, or energy raw materials, persistent challenges have long plagued the supply chain. Key stages including port access, tank storage, financing, and delivery remain difficult to supervise and trust. These issues are especially acute due to the intrinsic physical characteristics of liquid goods: they are often homogenous, commingled in shared tanks, and visually indistinguishable. As a result, ownership becomes opaque, creditworthiness is fragile, and true visibility over inventory is nearly impossible to achieve with traditional methods.
From Southeast Asia’s chemical ports to Europe’s large scale tank farms, financial institutions, logistics providers, and cargo owners alike struggle to ‘see’ and control the actual goods underlying their trades or loans. Traditional oversight still relies on periodic manual spot checks or static level readings, which can only offer snapshot data at specific moments in time. This makes it difficult to support dynamic, real-time decision-making and modern risk control practices. In many cases, it renders asset-based financing unviable – or worse, leads to misappropriation, over-pledging, or disputes over collateral ownership.
At the same time, fundamental trust in trade infrastructure is eroded by systemic vulnerabilities such as the ambiguity of warehouse receipts and the inability to uniquely correlate a receipt with a defined volume of goods. These informational asymmetries expose both financiers and traders to significant contractual and legal risk.
Redefining liquid asset trust with artificial intelligence
To address these long-standing pain points, 66 Yunlian – a digital supply chain technology company under Sinochem Group – has launched the world’s first artificial intelligence (AI)-driven system specifically designed for managing liquid commodity assets: Xiao Liuzi. This platform redefines how liquid cargo like LNG is tracked, verified, and protected across the value chain. By embedding an intelligent agent into every operational node, Xiao Liuzi brings real-time cognition, digital identity, and autonomous execution to goods that were previously invisible and ungovernable.
Xiao Liuzi also represents a major scientific and technical achievement under China’s national ‘14th Five-Year Plan’ project for digital financial innovation in the industrial sector. It is a key output of the country’s most advanced research initiative in the area of asset penetration risk control and digital collateral infrastructure.
Connecting capital, cargo, and ownership: One system, end-to-end data chain
Xiao Liuzi is a purpose-built AI system that integrates sensors, smart contracts, and algorithmic logic to monitor liquid cargo in real time. It tracks and analyses every key parameter of the asset – ownership status, physical location, stored volume, and estimated value – forming a seamless data chain across capital, cargo, and rights.
At the heart of the system is a patented innovation by 66 Yunlian: converting fungible goods into digitally designated assets. In essence, each batch of liquid cargo is assigned a unique digital identity, much like a land deed or property title. Even in tanks where multiple customers’ products are stored together, Xiao Liuzi can accurately identify whose goods are stored in which tank, in what volume, and at what valuation.
Key features of the system include:
z Intelligent exception detection: Continuous monitoring of tank levels, inbound/outbound flows, and storage dynamics to identify anomalies.
z Contract-based response engine: Embedded logic based on contract terms ensures that any deviation triggers automatic fulfilment co-ordination.
z Full-cycle risk control: When restocking occurs after an alert, the system autonomously validates resolution and clears the warning.
z Operational visibility tools: Interactive dashboards and semantic query functions allow users to ask the system about real-time conditions, much like interacting with a human staff member.
The system is accessible via both web browser and mobile app, enabling stakeholders to monitor and manage assets whether they are in a central office or walking a tank farm. This dual-interface design bridges back-office decision-making and front-line operations, creating a closed loop from system logic to field enforcement.
Clear value for financial institutions and cargo owners
As a new form of digital collateral intelligence, Xiao Liuzi provides value to all major participants in LNG and liquid commodity supply chains:
For financial institutions:
z Receipt-to-asset precision: Liquid commodities stored in bulk are difficult to segregate. Traditionally, a bank issuing a loan against a warehouse receipt might not be able to prove which part of a 5000 t tank is actually pledged. Xiao Liuzi resolves this with its digital designation model, ensuring a one-to-one mapping between warehouse receipts and physically verified volumes.
z Proactive risk management: Instead of waiting for monthly static inventory reports, Xiao Liuzi enables real-time alerting on volume discrepancies, abnormal flows, or valuation deviations. These alerts immediately notify relevant parties and initiate contract-compliant remedies, automatically. This pre-emptive model vastly reduces the risk of unanticipated default.
z Modernising risk control infrastructure: In contrast to legacy human-guarded warehouses, where daily sampling and monthly reconciliations are still common, Xiao Liuzi operates continuously. Traditional systems
Figure 1. Example of gas depository which could utilise artificial intelligence for cargo management.
often produce outdated information, such as a once-a-day email or a post-incident report. Xiao Liuzi delivers live, actionable insights, marking a leap forward in digital collateral visibility.
For cargo owners:
z Transparent ownership confirmation: Digital identity tags enable sellers, buyers, and third parties to confirm the origin, volume, and custody of cargo without ambiguity.
z Faster and smoother transactions: Real-time system integration accelerates clearance, validation, and execution across trade steps, improving liquidity and operational agility.
z Stronger legal defensibility: With full-process traceability from inbound receipt to outbound fulfilment, the system records transaction history, flow paths, and contract deviations, offering crucial evidence in the event of trade disputes or regulatory scrutiny.
Real-world results: Scale, security, and zero incidents
To date, Xiao Liuzi has been implemented in over 30 third-party tank farm projects across China. These use cases span both inventory management and post-loan asset supervision, with an average of over 700 000 t of goods under real-time monitoring daily. The largest single-tenant asset value covered by the system exceeds RMB 700 million (US$97 million) and, critically, none of these projects have reported a single risk incident since deployment.
This is not only a technological success – it is a milestone in restoring trust between financiers, traders, and operators. Xiao Liuzi transforms static supervision into dynamic governance, giving business leaders and financial institutions the confidence that their liquid assets are not only accounted for, but actively safeguarded.
Case study 1: The ‘6 t anomaly’ resolved by AI
In one high-stakes floating collateral transaction, Xiao Liuzi detected an unexpected loss of 6.376 t of chemical liquid. Without any human intervention, the system responded as follows:
z A tank-level sensor recorded the discrepancy and triggered an alert.
z Based on the active smart contract, the system notified all stakeholders and initiated fulfilment.
z After replenishment, the system confirmed the volume recovery and closed the incident.
This end-to-end automation eliminated the need for manual action and provided immediate assurance to the
bank and cargo owner involved – setting a new standard for digital contract compliance and automated risk response.
Case study 2: From platform to digital employee
Unlike conventional software that waits passively for user input, Xiao Liuzi actively pushes daily updates – tracking asset valuations, tank fluctuations, contract deviations – and delivering messages such as: “Tank volume abnormal. Restocking process initiated,” and “Alert cleared. Asset baseline restored.”
It does not sleep or miss a deadline, like a human worker might, and never fails to report. Over time, clients report that they have begun to treat Xiao Liuzi not as a system, but as a diligent, data-driven team member.
Outlook: Advancing into a new era of trusted digital assets
Liquid bulk commodities – once considered among the most difficult asset classes to regulate – are now achieving unprecedented levels of transparency and controllability through the integration of AI and blockchain technology. Xiao Liuzi is not just a regulatory tool; it is evolving into a foundational infrastructure for trusted commodity trading in the digital era.
As global markets increasingly demand real-time visibility, verifiable compliance, and automated contract fulfilment, 66 Yunlian is committed to deepening the integration of AI and blockchain technologies in liquid bulk commodity scenarios. The company is building a trusted digital asset infrastructure centred on digital warehouse receipts, stablecoins, and smart contracts.
Particularly during the transition from physical to virtual assets, the system establishes a one-to-one mapping between cargo states and on-chain digital assets, enabling key processes such as ownership transfer, cargo release, and payment settlement to be executed automatically through smart contracts. This not only redefines the trust mechanism in commodity trading, but also accelerates the industry’s evolution towards intelligent, reliable, and automated fulfilment.
In the global circulation of LNG, petrochemicals, and other liquid commodities, this next-generation infrastructure is becoming a trusted foundation for financial institutions, logistics providers, and industrial clients – injecting greater resilience and efficiency into international energy trade.
Figure 2. Gas depository such as those monitored by the Xiao Liuzi system.
INDUSTRYNEWS
ASRY to take on LNG repairs
The Arab Shipbuilding and Repair Yard Company (ASRY) is preparing to start LNG carrier maintenance in 2025. The move is backed by its recent Gaztransport & Technigaz (GTT) certification, cryogenic repair capabilities, and a long-standing track record in vessel servicing. With LNG shipping facing tighter rules, emissions pressure, and a steady push towards cleaner energy, the Bahrain-based yard is expanding its services to include repairs, refits, and retrofitting for LNG carriers.
ASRY’s recent certification from GTT – a French engineering firm known for its work on containment systems for LNG transport and storage – marks a step forward in its LNG offering. The recognition was announced during the Seatrade Maritime Qatar conference, held in Doha in early February 2025.
The endorsement followed a detailed assessment of ASRY’s technical capabilities, including its facilities, workforce, and cryogenic repair capacity. It confirms the yard’s readiness to handle LNG carrier repairs in line with international standards, particularly where membrane systems and supercooled equipment are involved.
ASRY CEO, Dr Ahmed Al Abri, described the certification as a key step in the company’s growth in this field: “Receiving this certification from one of the leading global institutions in the LNG industry is an achievement in itself. It would not have been possible without our determination to deliver professional, high-quality services that meet internationally-recognised standards.”
“The number of LNG ships is set to rise over the coming years, largely driven by the global move towards cutting carbon emissions. Many of these vessels are being ordered by owners in the Arabian Gulf, yet there is not enough space at existing yards to meet the growing demand. This opens the door for ASRY to both fill a clear need and widen the range of services we offer by taking on more demanding ships such as LNG carriers.
“There are three aims behind this step: first, to grow the company’s revenue by taking on more specialised jobs; second, to forge closer ties with its clients, many of whom own both tankers and LNG ships, by offering them a one-stop shop for repairs. This way, they no longer need to send vessels to different yards; and third, to strengthen the company’s standing by working on more demanding ships. This will raise the technical level across the board.
“From a working point of view, LNG carriers present their own set of challenges. LNG has a boiling point of -167˚C, so handling LNG repairs calls for great care and skill, including stringent procedures. ASRY’s mechanical shops are already well prepared to tackle such work.
“However, other areas, such as maintaining a spotless working space and fine-tuning processes, will need some sharpening to meet the exact needs of LNG ship repair. This will be a key part of our focus as we grow into this field.”
Head of Technical Portfolio Development, Eng. Omar Al Enzi, commented: “This certification drives us to keep delivering reliable, efficient repair solutions to clients in the LNG transport and storage sectors, ensuring full compliance with international safety and environmental requirements.”
The shipyard is currently handling work on a different variety of vessels including LPG vessels, container vessels, and RORO vessels. ASRY’s facilities include a 500 000 DWT drydock, two floating docks, two slipways, and more than 4 km of berth space, enough to take on a wide range of vessels.
All repairs comply with the International Gas Carrier (IGC) Code, ensuring that safety and performance standards are maintained. ASRY works closely with manufacturers and service firms to stay efficient, using 3D scanning to carry out precise structural checks and reduce dock time.
Beyond LNG, ASRY is expanding its work in other fields, adjusting to changes in the maritime sector. Ongoing investment in equipment and site upgrades is helping ASRY respond to new energy demands while remaining a reliable choice for shipowners seeking repair, emissions-related, and upgrade work.
Figure 1. Aerial view of ASRY Shipyard, equipped for LNG repairs and set to launch maintenance in 2025.
15FACTS
Western Africa produces nearly half of the continent’s LNG
The capital city of Algiers is know as ‘Alger la Blanche’ (Algiers the White) because of its sun-bleached buildings
Nigeria contributed more than 60% of Africa’s 2024 LNG exports
Nigeria’s Yoruba people have the highest number of twins in the world
Nigeria is Africa’s most populous country
The Greater Tortue Ahmeyim project produced first gas flow in January 2025
Nigeria contributes nearly two-thirds of West Africa’s LNG output
Portuguese is the official language of Mozambique
The NLNG Train 7 expansion will increase production capacity by 8 million tpy
Most of Algeria’s population is on the Mediterranean coast
Mozambique is currently the only major LNG exporter in East Africa
Algeria exported its first commercial shipment of LNG in 1964
Freddie Mercury was born in Zanzibar, Tanzania
Mozambique is the only country in the world to have 5 vowels in its name
Tanzania LNG is the largest gas project in Eastern and Southern Africa
