FSRU: How Floating Storage and Regasification Units Work and Where the Market Stands in 2026
- Vikas Pandey
- 11 hours ago
- 12 min read
Key Takeaways
An FSRU does everything an onshore LNG terminal does, from a vessel. It receives LNG by ship-to-ship transfer, stores it in cryogenic tanks, converts it back to gas, and delivers it to a pipeline. That's the whole function: import, store, regasify, deliver.
Speed and cost favor FSRUs at small to mid-scale. A newbuild costs under $300 million and reaches first gas in 12 to 18 months. A comparable onshore terminal costs $1 billion or more and takes 4 to 8 years. That gap is why countries facing sudden supply shocks reach for an FSRU first.
Weather and vessel supply are the two constraints the market underweights. Ship-to-ship transfer stops above roughly 2.5 to 3.0 metres of wave height, which matters most at exposed or northern anchorages in winter. And the spot FSRU fleet is small: a handful of specialist operators control it, so a simultaneous multi-country deployment demand would run into availability limits that no fast-track plan solves.
Germany's 2022 to 2023 deployment is the reference case, with caveats. Five FSRUs went into service in about 18 months, but shore-side work, jetty readiness, pipeline connections, metering, grid interconnection, didn't compress on the same timeline as the vessels. And the charter rates reflected a tight spot market with clear operator leverage.
The FSRU-versus-terminal decision comes down to scale and duration, not just urgency. FSRUs win for uncertain or under-5 to 8 MTPA markets that need gas fast. Land-based terminals win at 15 to 20 MTPA scale backed by 20 to 30 year supply contracts, where the lower annualized cost per unit outweighs the longer build time.
QUICK ANSWER: An FSRU (Floating Storage and Regasification Unit) is a vessel that imports LNG, stores it in cryogenic tanks on board, and converts it back to natural gas via onboard vaporization equipment for delivery into a coastal or offshore pipeline network. FSRUs cost under USD 300 million to build versus several billion for comparable onshore terminals, and can be deployed within 12-18 months. The International Gas Union counted roughly 50 FSRUs in operation globally in its 2024 World LNG Report, with further units under construction or conversion for delivery through 2027.
What an FSRU Is and How the Regasification Process Works
LNG is natural gas cooled to approximately negative 162 degrees Celsius, at which point it liquefies and reduces to approximately 1/600th of its gaseous volume. This density makes it economical to transport by sea in cryogenic tankers. An FSRU receives LNG from a supply vessel via a ship-to-ship transfer operation, stores it in cryogenic tanks, and converts it back to gas for onshore delivery.
The regasification process requires heat input. Modern FSRUs use one of three vaporization methods. Open-rack vaporizers use seawater as the heat source and are the most energy-efficient but require seawater temperature above approximately 4-5 degrees Celsius, which limits their use at high latitudes in winter. Submerged combustion vaporizers use combustion gases and work across a wider temperature range. Ambient air vaporizers work in temperate climates and carry lower operating costs.
The vaporized gas is then pressurized and delivered through a high-pressure gas transfer system from the vessel to either a shore-based jetty structure or an offshore pipeline manifold. Excelerate Energy’s fleet can deliver regasified LNG at pipeline pressure with send-out rates from 690 million standard cubic feet per day (MMscf/d) up to more than 1,200 MMscf/d continuously, according to the company’s published fleet specifications.
The ship-to-ship transfer from the supply LNG carrier to the FSRU is the operationally sensitive step. Transfer operations are limited to wave heights below approximately 2.5-3.0 metres. Beyond that threshold, side-by-side mooring becomes unsafe and transfer operations pause. I have conducted LNG ship-to-ship transfer operations, and the weather window constraint is the first operational question any FSRU siting analysis should address, not an afterthought.
FSRU Component | Function | Key Parameter |
LNG storage tanks | Hold LNG at cryogenic temperatures | Capacity 100,000-204,000 m3; membrane or moss-type design |
Boil-off gas management | Handle natural LNG evaporation from storage | Reliquefaction or BOG use as vessel fuel |
LNG loading arms | Transfer LNG from supply tanker to FSRU storage | Operational limit: wave height below 2.5-3.0 m |
Vaporizers (ORV or SCV) | Convert LNG back to gaseous natural gas | ORV requires seawater above 4 degrees C; SCV uses combustion gases |
High-pressure gas compressors | Compress gas to pipeline delivery pressure | Delivery pressure typically 50-100+ bar |
High-pressure gas transfer system | Deliver gas from vessel to shore or offshore pipeline | Flexible arm or rigid arm connection to jetty |
Mooring system | Hold FSRU on station | Side-by-side; end-on; or turret mooring depending on site |
The Fleet: Who Operates FSRUs and on What Commercial Terms
The global FSRU market is dominated by a small number of specialist operators who charter vessels to utilities, national gas companies, and governments on long-term contracts. The market is not a commodity market. Vessel availability is limited, and the negotiating dynamics between a government facing an energy security crisis and the two or three operators capable of delivering an FSRU quickly strongly favour the operator.
Excelerate Energy pioneered the open-access FSRU model. The company operates ten vessels with storage capacities from 138,000 m3 to 173,400 m3. Höegh LNG operates and charters more than ten FSRUs globally with over 50 million cubic metres of daily regasification capacity. Golar LNG runs over eight FSRU units. BW LNG, New Fortress Energy, and Dynagas LNG are also material fleet operators.
In September 2025, Höegh LNG launched a digital platform to optimise operational efficiency across its FSRU fleet using analytics and AI integration. In July 2025, Singapore’s Seatrium secured a contract to convert an LNG carrier into an FSRU, illustrating that conversion remains a viable route to adding capacity faster than new construction.
New-build FSRUs are primarily constructed at South Korean yards. HD Hyundai Heavy Industries, Samsung Heavy Industries and Hanwha Ocean (formerly DSME) have launched designs with storage capacities above 180,000 m3 and regasification throughput up to 20 million cubic metres per day. A notable newbuild, Excelerate’s Hull 3407 (170,000 m3), is scheduled for delivery in mid-2026 and will be deployed at Khor Al Zubair Port in Iraq to provide approximately 1 billion cubic feet per day of regasification capacity (Excelerate Energy, published vessel programme).
Mitsui O.S.K. Lines is building a 170,000 m3 FSRU for delivery in 2027 to serve the planned Gdansk terminal in Poland, under charter arrangements with Gaz-System, per the parties’ own announcements. A 204,000 m3 FSRU is under construction through HD Hyundai Heavy Industries for an Asian shipowner.
The Germany Deployment: What It Actually Taught the Industry
Germany commissioned five FSRUs within approximately 18 months in 2022-2023 at Wilhelmshaven, Brunsbüttel, and Lubmin after Russian pipeline gas supplies were cut. That deployment is widely cited as the template for energy security response. The practical lessons are more nuanced than the headline narrative suggests.
First, the deployment was fast by land-based infrastructure standards, but not without substantial cost. The German government paid charter rates reflecting a spot FSRU market with very limited available vessel inventory. The spot FSRU charter market operates differently from the VLCC spot market. There are fewer vessels, and the negotiating leverage sits firmly with the operator when government urgency is visible.
Second, the sites chosen involved varying degrees of shore-side infrastructure readiness. Wilhelmshaven had an existing jetty capable of receiving the vessel. Brunsbüttel required more adaptation. The assumption that FSRU deployment is purely a vessel question underestimates the shore-side requirements: high-pressure gas pipeline connections, metering, odorization, and grid interconnection all have independent lead times that do not necessarily compress to match the vessel mobilisation timeline.
Third, the Germany experience accelerated FSRU deployment planning across Europe and beyond. The construction pipeline at end-2024 was concentrated in Asia-Pacific, with Europe second, and single projects underway in the Middle East, Latin America and Africa.
Region | FSRU Capacity Under Construction (end-2024) | Key Markets |
Asia-Pacific | 21 MTPA | Vietnam; Philippines; Bangladesh; Sri Lanka |
Europe | 9.8 MTPA | Poland (Gdansk); Germany continuing; Cyprus |
Latin America | 6.1 MTPA | Brazil; Colombia; Dominican Republic |
Africa | 4.2 MTPA | Ghana; South Africa; Tanzania |
Middle East | Iraq deployment (Excelerate Hull 3407) | Khor Al Zubair; ~1 BCF/day |
Note: Regional capacity figures are indicative, compiled from operator and government project announcements. Precise MTPA totals vary by compiler and are omitted from citation pending a Tier 1 source.
Counter-Consensus: FSRU as Energy Security Tool Has Limits the Market Underweights
The prevailing view treats FSRUs as near-universal solutions for countries wanting to access LNG imports quickly. That framing understates three constraints that become significant at scale.
Weather tops the list of underweighted constraints. I have seen this play out in siting analyses where the wave height regime at a proposed anchorage was not adequately modelled before charter commitments were made. In exposed anchorages or northern locations during winter, ship-to-ship transfer downtime from wave heights exceeding 2.5-3.0 metres can be substantial. Operators and energy offtakers who have not modelled this downtime risk into gas supply planning have encountered supply shortfalls during adverse weather periods. The regasification process continues through most sea states once the FSRU is moored; the transfer constraint is the binding one.
Vessel availability is the constraint that no emergency deployment plan fully solves. I know of no fast-track mechanism that creates FSRU inventory that does not already exist. The spot FSRU market has very few vessels. During the European energy crisis of 2022-2023, Germany’s rapid deployment was possible partly because several vessels happened to be available or approaching the end of existing charters. A simultaneous multi-country FSRU deployment demand, as could arise from a broader European gas supply shock, would face vessel availability constraints that cannot be resolved quickly. New-build time is 2-3 years. Conversion is 12-18 months. Neither answer quickly enough for genuine emergency response.
Charter economics are the third and least visible constraint. Long-term FSRU charters, typically 10-20 years, at rates that reflect operator leverage in a constrained market, can result in annualised regasification costs that exceed what a land-based terminal would have cost if it had been built on a 4-8 year timeline. Countries that deployed FSRUs under emergency conditions in 2022-2023 are now working through the implications of those charter economics as the crisis environment has normalised.
FSRU vs Land-Based Terminal: When
the Numbers Favour Each Option
The commercial case for an FSRU over a land-based terminal is strongest under three conditions: the market is new or uncertain and government does not want to commit to permanent infrastructure; the timeline is urgent and volume requirements sit within FSRU capacity parameters, roughly up to 5-8 MTPA for a single large vessel. In my experience reviewing FSRU deployment proposals, the government side almost always underestimates how much the urgency premium costs them at the negotiating table.
The case for land-based terminals arises at scale and duration. A 15-20 MTPA terminal serving a market with 20-30 year LNG supply contracts can be financed on the terminal’s contracted throughput. Annualised cost per unit of regasification capacity becomes materially lower than a long-term FSRU charter at that scale.
Factor | FSRU | Land-Based Terminal |
Construction cost | Under USD 300 million (newbuild) | USD 1-5 billion+ depending on scale and location |
Time to first gas | 12-18 months from contract | 4-8 years |
Operational flexibility | Can be redeployed to another market | Fixed; no redeployment |
Weather constraints | Ship-to-ship transfer limited to wave height below 2.5-3.0 m | No equivalent weather constraint on onshore operations |
Optimal scale | Up to 5-8 MTPA per vessel | Economic above approximately 5 MTPA; scales to 20+ MTPA |
Long-term cost efficiency | Higher per unit at scale vs onshore | Lower per unit at scale with long-term contracts |
A Worked Example: FSRU Charter Cost vs Onshore Terminal for 3 MTPA Market
The following is illustrative and does not represent any specific project or Shipfinex activity.
Item | FSRU Option | Land-Based Terminal Option |
Upfront capital cost | USD 250 million (newbuild vessel) | USD 1.8 billion (3 MTPA onshore terminal) |
Charter / financing term | 15 years | 20 years |
Annual charter cost (illustrative) | USD 40-50 million/year | USD 75-90 million/year annualised capital service |
Total cost over term (illustrative) | USD 600-750 million | USD 1,500-1,800 million |
Weather-related downtime cost (annual estimate) | USD 5-15 million depending on site exposure | Minimal |
Time to first gas | 15-18 months | 5-7 years |
Verdict at 3 MTPA over 15 years | FSRU significantly lower total cost | Land-based lower over 20+ years at >5 MTPA |
Note: Figures are illustrative approximations. Actual charter rates, financing costs, and construction costs depend on market conditions; vessel specification, site conditions and applicable regulatory requirements.
FSRUs and Maritime Asset Tokens
Shipfinex FZCO, operating under VARA In-Principle Approval (IPA/26/01/002), structures Maritime Asset Tokens (MATs) that represent economic exposure to vessel-owning Special Purpose Vehicles. An IPA is not a full operational licence and is subject to completion of final regulatory requirements.
FSRUs are a vessel category of specific relevance to maritime asset tokenisation on a structural level. They are high-value assets, typically USD 200-300 million for a newbuild, with long-term charter contracts from creditworthy counterparties such as national gas companies, utilities, and governments. An FSRU held in an SPV structure under a 15-20 year charter to a creditworthy offtaker produces a revenue profile that differs substantially from a spot-market dry bulk vessel. The charter certainty is higher; the mark-to-market volatility is lower.
Where distributions are declared by the SPV, they are paid to token holders transparently and on-chain. MAT values may decline materially below purchase price. Secondary market liquidity for MATs is limited; early exit may not be possible.
Frequently Asked Questions
What does FSRU stand for?
FSRU stands for Floating Storage and Regasification Unit. It is a vessel that stores LNG in cryogenic tanks on board and converts it back to natural gas via onboard vaporization equipment for delivery to a shore-based or offshore pipeline network. It performs all functions of an onshore LNG import terminal while remaining a vessel.
How many FSRUs are operating globally?
The International Gas Union counted roughly 50 FSRUs in operation globally in its 2024 World LNG Report, up sharply from around 30 in 2020. Further units are under construction or in conversion, with deliveries scheduled through 2027, including newbuilds for Iraq and Poland.
What is the difference between an FSRU and an FLNG?
An FSRU (Floating Storage and Regasification Unit) imports LNG and converts it back to gas for onshore use. An FLNG (Floating Liquefaction, Storage and Offloading) unit does the opposite: it liquefies gas produced offshore for export as LNG. FSRUs are import infrastructure; FLNGs are export infrastructure. Both share similar hull architecture but serve entirely different roles in the LNG supply chain.
How long does it take to deploy an FSRU?
A new-build FSRU typically takes 2-3 years from contract to delivery. A converted LNG carrier can be ready in 12-18 months, sometimes faster under strong commercial pressure. Germany deployed five FSRUs within approximately 18 months in 2022-2023, though this required exceptional government prioritisation of permitting and shore-side infrastructure alongside vessel conversion and chartering.
What are the key weather limitations of FSRU operations?
The primary weather constraint is the ship-to-ship transfer of LNG from the supply tanker to the FSRU storage tanks. Transfer operations are generally limited to wave heights below 2.5-3.0 metres. In exposed anchorages or northern locations during winter, this can produce significant operational downtime. The regasification process and gas export operations continue through most sea states once the FSRU is moored. Open-rack vaporizers additionally require seawater temperatures above approximately 4-5 degrees Celsius.
Who are the major FSRU operators?
The major fleet operators include Excelerate Energy (US), Höegh LNG (Norway), Golar LNG (Bermuda), BW LNG (Norway), New Fortress Energy (US), and Dynagas LNG (Greece). Most charter vessels to utilities, national gas companies, or governments on long-term contracts of 10-20 years. The market also includes spot and short-term charter arrangements for emergency deployments, though vessel availability for spot deployment is limited.
What is the send-out capacity of a typical FSRU?
Modern FSRUs can deliver regasified LNG at send-out rates from approximately 690 MMscf per day up to more than 1,200 MMscf per day continuously, according to Excelerate Energy’s published fleet specifications. Storage capacity ranges from approximately 100,000 m3 for older converted vessels to 204,000 m3 for the largest newbuilds under construction. A vessel in the 138,000-173,000 m3 storage range covers the needs of a small to mid-sized national gas market.
Are FSRUs permanently moored or can they move?
Self-propelled FSRUs can navigate under their own power and are redeployable between locations, subject to shore-side infrastructure compatibility. Non-self-propelled FSRUs require tug assistance for repositioning. Long-term charter contracts typically tie an FSRU to a specific location for the contract duration, but the redeployment optionality is a structural advantage over onshore terminals when market conditions change.
What is boil-off gas (BOG) on an FSRU?
BOG is natural evaporation from LNG storage tanks caused by heat ingress. LNG does not remain perfectly static in storage; a small proportion evaporates continuously. Modern FSRUs manage BOG through reliquefaction systems that return the vapour to LNG, or by using BOG as vessel fuel. BOG management is a significant engineering and operating cost factor in FSRU design and is handled differently across membrane-tank and moss-type tank configurations.
What is the difference between a converted FSRU and a purpose-built FSRU?
A converted FSRU is an existing LNG carrier that has been modified to add onboard regasification equipment. Conversions are typically faster and cheaper than new builds: 12-18 months versus 2-3 years and lower upfront capital. Purpose-built FSRUs are designed from inception as combined storage and regasification platforms and typically offer higher regasification efficiency, larger storage capacity, and longer design life. New-build units command the larger share of the market by value, given their engineering advantages and longer deployment horizons.
Glossary
FSRU: Floating Storage and Regasification Unit. A vessel that imports, stores and regasifies LNG for onshore gas distribution.
FLNG: Floating Liquefaction, Storage and Offloading. A vessel that liquefies offshore gas production for export as LNG. Performs the opposite function to an FSRU.
LNG: Liquefied Natural Gas. Natural gas cooled to approximately negative 162 degrees C, reducing volume to approximately 1/600th of gaseous state for maritime transport.
MMscf/d: Million standard cubic feet per day. Standard measure of gas flow rate or send-out capacity.
ORV: Open-rack vaporizer. Regasification equipment using seawater as heat source. Requires seawater above approximately 4 degrees Celsius.
SCV: Submerged combustion vaporizer. Uses combustion gases to heat LNG for regasification. Operable in colder seawater temperatures.
BOG: Boil-off gas. Natural evaporation from LNG storage tanks; managed via reliquefaction or use as vessel fuel.
HPGTS: High-Pressure Gas Transfer System. Pipeline and loading arm connection from FSRU to shore-based pipeline.
MTPA: Million tonnes per annum. Standard capacity measure for LNG regasification facilities.
STS transfer: Ship-to-ship transfer. Transfer of LNG cargo between two vessels moored alongside each other; the operationally limiting factor for FSRU supply operations.
Capt. Vikas Pandey
Founder & CEO of Shipfinex
Capt. Vikas Pandey is Founder and CEO of Shipfinex, the first VARA-regulated (In-principle approval) platform for tokenized maritime asset participation. A mariner turned seasoned entrepreneur, he combines direct vessel operational experience with deep maritime finance expertise to build the infrastructure for accessible ship ownership.
