Converts old LNG tankers into floating gas liquefaction plants anchored directly above deepwater gas fields.
At a glance
- Depends onUpstream position: supplies 3 industries, depends on 0
- ScaleLevered free cash flow is in the bottom 5% globally
Converts old LNG tankers into floating gas liquefaction plants anchored directly above deepwater gas fields.
What this company is and how it runs — written from structure, not news.
Golar LNG converts old LNG carrier hulls into floating liquefaction plants that can be moored directly above deepwater gas fields too remote for a pipeline, chilling gas down to -162°C on a hull that pitches and rolls in open ocean. Because each hull has its own structural geometry, the cryogenic processing equipment and the subsea wellhead connection on the seabed are all engineered specifically around that one vessel — which means the vessel and the gas field become a matched pair for the duration of the campaign. Once a territorial government issues field-development approval naming that particular unit at those specific seabed coordinates, the field operator has no alternative way to get gas to market, and replacing Golar would mean rebuilding the seabed infrastructure and restarting the entire regulatory approval from scratch. Growth comes one campaign at a time — each new gas field needs its own dedicated vessel parked at its own mooring position for years — so scale depends on how many of those multi-year pairings the company can build and win, not on expanding any single site.
How does this company make money?
The company charges a tolling fee for every million British thermal units (MMBtu) of gas that is liquefied aboard its vessels. These fees are collected under multi-year processing agreements with the gas field operators, so once a vessel is moored and certified, a predictable stream of payments flows in for the full duration of the campaign.
What makes this company hard to replace?
A gas field operator who has signed a multi-year mooring commitment cannot simply move to a different provider mid-campaign — the subsea wellhead connection on the seabed was built to fit this specific vessel and cannot be quickly adapted for a different one. The marine operating permits and the field development approval issued by the territorial government name this particular FLNG unit at this location, so replacing it would require restarting a lengthy regulatory process. The physical and legal infrastructure all points back to one vessel.
What limits this company?
Each converted vessel sits at one precise spot on the seabed for several years, and the wellhead connection underneath it is built to fit that ship's exact size and weight. You cannot add a second vessel to the same field to produce more, and moving the vessel to a new field means going through the full engineering and regulatory approval process all over again from scratch.
What does this company depend on?
The company cannot operate without four things: cryogenic liquefaction equipment that is specifically rated to keep working on a moving ship; dynamic positioning and mooring systems that hold the vessel in place in deepwater; subsea wellhead connections at the client's gas field; LNG carrier vessels to collect and transport the finished cargo. It also needs acceptable marine weather windows to carry out cargo transfers safely.
Who depends on this company?
Gas field operators with stranded offshore reserves — fields too remote or too small to justify a pipeline — have no way to sell their gas if the floating liquefaction vessel is not there. LNG buyers at receiving terminals in other countries face supply gaps if an FLNG vessel goes offline and cannot maintain its production schedule. Offshore drilling contractors also depend on the company indirectly: without a floating liquefaction option, many deepwater gas discoveries simply stay in the ground and generate no revenue.
How does this company scale?
Once the company has proven a liquefaction module design and built up marine engineering expertise on one vessel, that knowledge can be applied to the next conversion more efficiently — the design work does not have to start from zero each time. What cannot be scaled is the mooring itself: each gas reservoir needs its own dedicated vessel parked at specific seabed coordinates for years, so growth means adding campaigns one by one rather than expanding any single site.
What external forces can significantly affect this company?
IMO maritime safety rules govern how LNG carrier ships may approach and operate alongside floating liquefaction facilities, and any tightening of those rules affects daily operations. Deepwater licensing regimes in West Africa and Southeast Asia — the regions where most stranded gas reserves sit — control whether and when the company can operate in those waters. Shifting weather patterns in key offshore gas provinces can reduce the number of safe operational windows available for cargo transfers each year.
Where is this company structurally vulnerable?
Maritime regulators at the IMO, or deepwater licensing authorities in West Africa or Southeast Asia, could decide that when a converted vessel moves to a new gas field it needs to be fully re-certified and re-approved from scratch. If that happens, the assumption that a proven vessel and its conversion design can move smoothly from one campaign to the next collapses — and the multi-year tolling agreements that generate revenue depend entirely on that assumption holding.
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3 interpretations currently present — each is a set of fired observations whose alignment reads as one structural pattern. Click an observation to see the numbers behind it.
Screen for these patternsIs this company financially stable?
Three financing observations align: debt issuance is large relative to operating cash flow, absolute financing cash flow is large relative to operating cash flow, and long-term debt is a large share of total debt. Together they describe heavy financing activity with a long-term-debt-dominant mix.
Three liquidity ratios co-occur in their elevated ranges: current ratio (industry-benchmarked), quick ratio, and cash ratio. The simultaneous firing means coverage is elevated through progressively more liquid asset layers, not concentrated in inventory or receivables.
Is this company growing?
Two observations co-occur: industry-benchmarked Capex/OCF is in its elevated range (capex consumes a high share of OCF relative to peers), and Capex/Depreciation exceeds 1.0 (gross capex outpaces the rate at which the existing asset base is being charged off). The configuration describes capex-heavy capital allocation at the current snapshot.
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Follow gas from reservoir to processing, liquefaction, cryogenic storage, ocean transport, regasification, pipeline delivery, use, and retirement. LNG preserves a molecule across distance, but each handoff can spend energy, capacity, money, and evidence.
Follow gas from wells through gathering, processing, transmission, compression, storage, distribution, meters, use, and retirement. Gas abundance, nominations, and storage inventories do not by themselves establish that a particular burner will receive fuel during a disturbance.
Follow oil and gas from reservoir through wells, separation, divergent transport and processing routes, use, emissions, and abandonment. A resource estimate or barrel count does not establish the particular fuel, molecule, pressure, timing, or waste route a user needs.
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