Get the definitions straight first. Japan's Ministry of Finance preliminary trade statistics for September (released 20 October 2026, reported 21 October) show LNG import volumes of 4.779 million tonnes, down 7.3% year on year, while import value rose 39.2% — an implied unit price gain of 50.2%. The same release has crude oil volumes up 3.1% and value up 51.1%, putting the average price per kilolitre up 46.6%; mineral fuel imports as a whole rose 39.4% to JPY 2.35 trillion, a single line item contributing 6.9 percentage points of the 18.9% rise in total imports. The September trade deficit came to JPY 536.6 billion, 93.2% wider than a year earlier and a fifth consecutive monthly deficit. The index decomposition says it most clearly: import volumes fell 1.6% while import unit values rose 20.8%. Japan's September import bill was entirely price-driven, with volume making a negative contribution.

The second tier is the gap between the landed average and spot. World Bank commodity data (Pink Sheet) put Japan's average landed LNG price at $14.25/MMBtu in September 2026, down 6.7% month on month but up 24.2% year on year, with Brent averaging $116.80/bbl, up 28.5% on the month and 71.8% on the year. The Northeast Asian spot marker JKM, meanwhile, reached $32.84/MMBtu on 30 October (with an alternative quote at $32.03), with a 7-day average of $31.89 and a 30-day average of $27.87. Spot is therefore around 2.3 times the weighted landed average. The two numbers are not in contradiction; they are two different accounts. The $14.25 is the volume-weighted landed cost of a mix dominated by oil-linked term contracts, lagging crude by roughly one to two months. The $32.84 is the marginal price of cargo deliverable right now. The fact that the September landed average still fell month on month tells us the oil-linked leg has yet to absorb Brent's 28.5% September jump — that cost lands in the fourth quarter.

The demand side is already responding. Japan's September LNG imports fell 7.3% year on year, a wider decline than July's -4.8% and August's -6.8%, which says high prices are genuinely squeezing out marginal demand. A structural subtraction is under way too: a Reuters column (carried by Jin10 on 1 November 2026), citing energy think tank Ember, notes that gas fell to 28.4% of Japan's power generation mix in 2026, below 30% for the first time, against close to 40% in 2019 and about 35% in 2022, with the replacement coming from higher renewable output and nuclear restarts; South Korea has also dropped below 29%. On inventories, METI data (via Global LNG Hub's weekly note of 29 October 2026, drawing on a JOGMEC series updated 26 October) show power-generation LNG stocks at 2.54 million tonnes as of 18 October, down 0.10 million tonnes week on week. Stocks are still being drawn, but Japanese buyers are trading inventory for time — waiting for spot to ease rather than chasing it above $32.

What this means for SNSUC. LNG and LPG sit inside our addressable categories, and Japan, as Northeast Asia's largest buyer, sets the liquidity and depth of the regional spot market. Three actionable judgements follow. First, Japan's current posture is to cut spot, absorb term volumes and draw stocks — so deals struck near $32 are mostly coming from third parties that need to refill before winter, not from Japan's core buyers. If we take part in regional spot scheduling, the counterparty's restocking urgency has to be priced as a separate variable. Second, Japan's term bill will catch up in the fourth quarter as September's $116.80 Brent works through, which lifts yen cost pressure and hardens its negotiating stance on any new long-term volume. Third, never mix the two benchmarks: quote JKM at $32.84 to customers, but use the $14.25 landed average when discussing Japan's import cost — conflating them produces entirely wrong cost conclusions. Risk note: this is a market observation based on public data and does not constitute investment advice.