Analysis
ADNOC said on 5 October 2026 that its trading arm will supply Thailand’s Gulf Group with approximately 2 million tonnes of LNG over a multi-year term beginning in 2027. The announcement does not specify the number of years, delivery schedule, price or calorific value. It therefore supports a total mass commitment, not an annual volume or a monetary value.
A separate September LNG Canada notice describes a west-coast plant expansion from 14 to 28 Mt/year and a roughly ten-day shipping route to Asia. The two announcements are not evidence that Canadian cargoes fulfil the Thailand contract. They illustrate different links in the LNG chain: an export facility’s annual nameplate, a sales agreement’s aggregate mass and a voyage time under one geographic route.
Evidence and measurement
Mass must be translated into usable heat with a contractual heating value. For a transparent illustration only, assume 50 gigajoules per tonne of LNG. Then 2 million tonnes contain 100 million GJ before voyage, regasification and end-use losses. Actual energy depends on composition and the contract’s higher- or lower-heating-value convention; 50 GJ/t is an assumption, not a measured cargo quality.
If one additionally assumes a 2% loss between loading and delivered usable energy, the illustrative 100 million GJ becomes 98 million GJ. At 5% it becomes 95 million GJ. These rates deliberately combine logistics and conversion losses for a sensitivity exercise; actual boil-off can be used as ship fuel and contract delivery points determine which party bears each difference.
Engineering chain
A multi-year term cannot be reduced to 1 Mt/year merely because total supply is 2 Mt. If the hypothetical term were two years with even delivery it would average 1 Mt/year; four years would average 0.5 Mt/year. Neither duration is stated by ADNOC. Take-or-pay, destination flexibility, seasonal nominations and cargo size could make the actual annual profile uneven.
The monetary comparison also requires common units. A quoted price per million British thermal units applies to energy, while transport and storage may be charged per tonne or cargo. Converting tonnes with an assumed heating value before comparing prices avoids a unit error; one must also specify whether the energy figure refers to loaded or delivered gas.
Economic mechanism
For illustration, at a hypothetical US$1/GJ change in delivered margin, 98 million GJ of delivered energy would change total pre-tax contribution by US$98 million over the agreement, if that energy were actually delivered. This is not the contract price or expected profit. Financing, taxes, shipping charters, penalties and timing are absent.
The route matters because ship time ties up vessel capacity and working capital. LNG Canada’s roughly ten-day Asia sailing estimate applies to its own route; it cannot be assigned to an ADNOC-to-Thailand shipment. Port queuing, weather, canal or strait conditions, berth availability and regasification slots alter delivered cost and timing.
Illustrative sensitivity
Terminal throughput is another distinct unit. A 28 Mt/year nameplate, if someday achieved, would be an annual maximum under design conditions; ADNOC’s 2 Mt is an aggregate contracted volume over unspecified years. Dividing one by the other would be a hypothetical share of nameplate, not evidence of plant allocation or common supply origin.
A buyer evaluating a deal should seek the delivery point, energy quality band, cargo-size range, annual delivery programme, price index and review clauses. An exporter should also map vessel availability, loading slots and credit exposure. Those contract details turn a mass headline into a cash-flow schedule, but they are absent from the public announcement.
Uncertainty and decision gates
At the 6 October evidence cutoff, supply begins in 2027 according to ADNOC, with no public proof of delivered cargoes under this agreement. LNG Canada’s Phase 2 remains an investment project. Neither source reports the particular cargo heating value or a realised delivered margin, so every conversion and earnings figure above remains conditional.
For 2026–27 decisions, keep three ledgers separately: tonnes contracted, tonnes loaded or delivered, and energy accepted at the destination. Reconcile them with the contract’s measurement convention and date. Only then compare alternative routes or suppliers on a common delivered-energy cost basis.