OSSA LNG

Daily News

13 October 2026

Global LNG, Energy, Shipping & Technology Intelligence

Edition · 13 October 2026

LNG tightness shifts from headline risk to physical constraints

Europe enters winter with a thinner storage buffer, Gulf LNG remains slower to recover than oil, and emerging Asia is reassessing gas-fired power plans. The common thread is deliverability: molecules, ships, insurance and onboard systems must all work together.

01 — LNG & Energy Markets

Europe’s thin storage buffer raises the value of every flexible LNG cargo

Reuters reported on 12 October that European gas storage is expected to reach only 75–78% by 1 November, about ten percentage points below the five-year average. European benchmark gas prices have risen by more than 150% this year as disrupted Gulf LNG flows intensified competition for Atlantic Basin cargoes. These are forecasts and market observations, not evidence of an unavoidable physical shortage.

Why it matters

Storage normally covers roughly 25–30% of EU winter gas consumption. A lower starting buffer means Europe may need to remain a price-responsive LNG buyer not only this winter but during the 2027 injection season. MyLNG analysis: the important mechanism is the loss of optionality—each additional supply outage has a larger price effect when inventories cannot absorb it. A mild winter, stronger non-Gulf supply or durable de-escalation could materially soften that conclusion.

Impact

Higher and more volatile European gas prices can strengthen the pull on flexible LNG cargoes, but the available evidence does not establish an outright shortage.

  • EU storage
  • spot LNG
  • winter risk

Source

02 — Shipping & Transport

Oil transit is recovering faster than Qatari LNG — an operational, not purely geopolitical, gap

A Reuters Open Interest analysis published on 12 October, citing Kpler, said Qatar exported 1.6 million tonnes of LNG in September—less than one quarter of its pre-war average—and October shipments were tracking near 0.6 million tonnes. By contrast, Middle East crude shipments through Hormuz recovered to about 80% of pre-war levels in September. The export estimates are third-party tracking data reported by Reuters.

Why it matters & sources

Why it matters

LNG cannot restart like a simple terminal switch. Feedgas from the North Field, condensate removal, liquefaction-train availability, limited LNG storage and confidence that specialised carriers can enter and leave Hormuz must all align. MyLNG analysis: intermittent safe passages may restore oil flows while remaining insufficient for an integrated LNG chain. The strongest alternative view is that QatarEnergy has indicated production could restart within weeks after Hormuz reopens; the pace will depend on asset condition and durable route security.

  • Hormuz
  • Qatar LNG
  • tanker risk

Source

03 — LNG & Energy Markets

Emerging Asia still grows LNG demand, but its planned gas-power buildout is shrinking

Reuters reported on 12 October that Wood Mackenzie expects only 14.9 GW of Southeast Asia’s planned 53 GW gas-fired project pipeline to be operating by 2030. The same report said regional LNG consumption could still rise from 27 million tonnes in 2025 to 39 million tonnes in 2028, while Rystad Energy has cut its longer-term Asia LNG demand forecasts by 3% for 2040 and 7% for 2045. These are company forecasts, not committed outcomes.

Why it matters & sources

Why it matters

The evidence points to slower infrastructure conversion rather than disappearing LNG demand. High and volatile fuel prices, scarce gas turbines and cheaper renewables weaken project bankability, while domestic gas decline and grid-balancing needs still support some LNG growth. MyLNG analysis: terminal capacity and long-term supply contracts face greater utilisation risk when the associated power plant slips. Faster data-centre demand, affordable long-term LNG or improved turbine availability could reverse part of the downgrade.

  • Southeast Asia
  • gas-to-power
  • demand outlook

Source

04 — Shipping & Transport

Freight and insurance now threaten delivery economics alongside commodity price

OPEC and non-OPEC ministers said on 12 October that shipping and insurance costs for crude oil and products had risen to more than one third of commodity value. Reuters reported the statement after meetings in Riyadh. The figure applies to crude and refined products; no equivalent LNG-specific percentage was provided.

Why it matters & sources

Why it matters

War-risk premiums and route disruption can raise delivered energy cost even when production remains available. LNG is especially exposed to route concentration and a specialised carrier fleet, but the OPEC figure must not be transferred directly to LNG. MyLNG analysis: the useful signal is the mechanism—freight, insurance and voyage uncertainty can become a binding constraint in their own right. LNG-specific charter and insurance data would be needed to quantify the effect.

  • marine insurance
  • freight
  • route security

Source

LNG Technology & Innovation

06 — Tech insight · BOG

Technical background: shore power can remove the load that consumes LNG boil-off gas

What is new
Technical background — CE Delft published this study page in February 2026; the underlying report is dated November 2025. It models LNG-fuelled containerships with Type B or membrane fuel tanks during port stays. In a conventional call, auxiliary engines can generally consume the generated boil-off gas. When Onshore Power Supply replaces those generators, that consumption path disappears. The ships inventoried generally lacked reliquefaction, sub-cooling, dedicated gas-combustion units or enough pressure accumulation to absorb large BOG volumes.
How it works
Heat ingress continuously vaporises a small fraction of LNG. Tank pressure must remain below the relief-valve set point, and emergency venting is not an ordinary control method. With auxiliary engines shut down under OPS, a dual-fuel boiler may burn BOG independently of the electrical grid. CE Delft found that the burn rate needed for pressure control often exceeds useful steam demand, so gas can be combusted without useful energy output. Higher tank design pressure can extend holding time, but the report says the exact design-pressure-to-holding-time relationship still requires evidence.
Why it matters
OPS can reduce local air emissions while creating a separate energy-efficiency problem if BOG control was designed around running engines. The study does not show that emergency venting is inevitable: it assesses that risk as relatively low where a suitable dual-fuel boiler is installed. Important limitations are that equipment fit could not be confirmed for every ship, the work is principally desk-based, and only five stakeholders supplied feedback. Open question: which measured port-call data best capture dynamic BOG generation and useful boiler demand under real OPS operation?
LNG / shipping impact
For LNG-fuelled containerships, OPS readiness and tank-pressure control should be treated as one integrated design interface. The conclusion should not be generalised to LNG carriers, Type C tanks or vessels with reliquefaction without vessel-specific evidence. For existing ships, the practical trade-off is between retrofit cost, pressure-holding capability and avoidable combustion—not a simple choice between shore power and safety.

Technology maturity

  1. concept
  2. prototype
  3. pilot
  4. demonstration
  5. commercial

Potential impact

medium

Source