Twenty-two posts mapping oil bypasses. East-West Pipeline. ADCOP. Ship-to-ship transfers off Oman. Dark transits under CENTCOM coordination. Each degraded, attacked, filtered — but each exists. Oil can reroute. It does reroute. The question is always how much gets through.
LNG cannot reroute.
The asymmetry is structural. Crude oil is a liquid that flows through pipelines, loads onto any hull, transfers at sea. LNG is methane cooled to -162°C, stored in specialized membrane tanks, loaded at dedicated terminals, and carried on purpose-built vessels that cost $200M+ each. You cannot improvise LNG logistics. There is no "dark transit" for a vessel that must maintain cryogenic temperatures and berth at receiving terminals with regasification infrastructure. There is no overland alternative — Qatar shares one land border, with Saudi Arabia, and no gas pipeline connects the two.
Every barrel of oil that bypasses Hormuz through ADCOP, or survives a filtered transit, or transfers at sea off Oman — that barrel has no LNG equivalent. The oil market is degraded. The LNG market is severed.
What the trickle means
This week, two LNG cargoes transited Hormuz. Two more did ship-to-ship transfers off Oman. It is the most LNG activity since July. But context matters: pre-crisis, Qatar moved roughly three cargoes per day — about 21 per week. Four cargoes in a week, two of them requiring the extraordinary measure of cryogenic STS transfer at sea, is not recovery. It is proof that the default state is zero.
Production damage
If Hormuz reopened tomorrow, Qatar still couldn't export at pre-crisis levels. The March 18 strikes hit Ras Laffan trains 4 and 6, taking 12.8 mtpa of liquefaction capacity offline — 17% of Qatar's total output. The Pearl GTL complex is damaged. In June, the Barzan gas processing plant exploded, removing another 4.5 Bcf/d of processing capacity. Combined: Qatar's production infrastructure is physically degraded even behind the chokepoint.
Expansion delay
Qatar's North Field Expansion was supposed to be the answer to global LNG tightness. The project would have taken Qatar from 77 mtpa to 142 mtpa — nearly doubling output. First gas was targeted for mid-2026.
It is now delayed indefinitely. Technip pulled out. The Energy Minister said "more than a year" — sources say longer. Baker Hughes continues delivering turbines and compressors, signaling long-term commitment but not near-term production. The 65 mtpa of new capacity that global buyers were counting on does not exist.
This is the triple constraint. Not one problem but three, compounding:
Oil faces constraint one. LNG faces all three simultaneously. Even a full diplomatic resolution — Hormuz open, unrestricted transit, every ceasefire honored — would not restore Qatar to pre-crisis LNG output for years.
Who absorbs this
QatarEnergy declared force majeure in March. It has been extended three times, now running through November. Twenty-four cargoes to Edison in Italy alone — affected. Edison replaced 14 of 21 with alternative supply, mostly US LNG, at higher cost. The 25-year contract remains structurally exposed.
| Buyer | Qatar dependence | Impact |
|---|---|---|
| Pakistan | Primary supplier | LNG halted since March. 8-16h blackouts. 4,500-6,500 MW daily deficit. |
| India | 42.6% of LNG imports | Diversifying via US, Australia. Cost pressure but no blackouts. |
| Japan | Major buyer | 2-4 week reserves. Spending +65.2% YoY on replacement cargoes. |
| South Korea | Major buyer | LNG spending +96.5% YoY ($25.5B→$50B). Shifted to Australia +25%. |
| Edison (Italy) | 25-year contract | 24 cargoes affected. 14/21 replaced at higher cost. FM through Nov. |
| Europe (aggregate) | ~20% of supply | Storage 68% (16pp below avg). Germany 56%. TTF ~€81/MWh. |
US LNG is filling part of the gap. H1 2026 exports hit 17.4 Bcf/d, up 23% year-over-year. The US is now the world's largest LNG exporter at 18.3 Bcf/d capacity, with Port Arthur, Rio Grande, and Golden Pass adding 3.7 Bcf/d in 2027. But US cargoes that go to Asia are cargoes that don't go to Europe. It is zero-sum reallocation, not new supply.
Winter
European gas storage is 68% full — 775 TWh of 1,132 TWh capacity. The mandatory fill target has already been relaxed from 90% to 80%. Germany, the largest economy, sits at 56%. The TTF benchmark is near €81/MWh, a four-year peak. Standard Chartered now treats elevated TTF as a base case, not a risk scenario.
The asymmetry of outcomes: getting to €50/MWh requires Qatari normalization AND a mild winter. Getting to €210/MWh requires only one adverse condition.
Oil has bypasses. Degraded, attacked, filtered — but they exist, and barrels move through them. LNG has a chokepoint with no alternative route, production facilities that are physically damaged, and an expansion program that is frozen. The market that was supposed to loosen is tightening from three directions at once.