Spare LNG sells high
When Qatari liquefied natural gas supply is disrupted, the shortfall is felt first in the spot market. Most LNG moves under long-term contracts at fixed or oil-linked prices, so a seller's exposure to a spike in spot prices depends on how much of its output is uncommitted. Atlantic Basin producers and marketers with spare cargoes can redirect them to the buyers in Europe and Asia who are paying the most, while suppliers whose volumes are fully contracted see little change in what they receive. A portfolio under this thesis selects US-listed natural gas producers, LNG export project owners and gas marketers that retain merchant or uncommitted volumes and sell them at prevailing spot or hub-linked prices. It gives less weight to export terminals that earn fixed liquefaction and processing fees per tonne regardless of the cargo's sale price, since their revenue is largely insulated from the disruption that drives the idea.
Cheniere Energy owns and operates the Sabine Pass and Corpus Christi liquefaction plants, roughly 55 mtpa in operation, making it the largest US LNG exporter. the business is deliberately contracted: about 90% of capacity is sold under multi-decade fixed-fee SPAs that are insulated from JKM/TTF, and 2026 production of 53 to 54 mt splits into 46 to 47 mt long-term, about 5 mt spot sold through its in-house arm Cheniere Marketing (CMI), and about 1 mt commissioning. that merchant tranche is the only piece that expresses the thesis, but it is a direct earnings driver: Q3 2026 EBITDA rose 18% on higher marketing margins as TTF and JKM averaged above $21/MMBtu during the Hormuz disruption, and each $1/MMBtu on ~250 TBtu of CMI volume is roughly $250m against ~$9bn guided EBITDA. material exposure, not a pure merchant seller → 0.6. no equity in Qatari trains, so no offsetting loss.
Shell is a diversified integrated major — upstream oil, refining, chemicals, marketing — with the largest LNG portfolio and trading book among listed companies. the Integrated Gas segment (equity liquefaction plus LNG marketing, trading and optimisation) earned $2.7bn of $9.8bn adjusted earnings in Q2 2026 and $3.0bn of $10.8bn in Q3 2026, roughly 28% of the group. sold LNG volume (18.0–19.3 mt per quarter) runs about 2.4x equity liquefaction (7.4–7.7 mt), so most of what Shell sells is third-party or portfolio supply priced against destination hubs — exactly the merchant channel this portfolio targets. the live Qatari outage is the test case: Shell lost Qatari equity volumes (Qatargas 4, Pearl GTL, North Field stakes) yet Integrated Gas earnings rose 42% y/y on trading and optimisation gains and higher realised LNG prices, so net exposure is positive. LNG is a material minority of the business, not the whole, which fits the 0.6 tier.
BP is a diversified integrated major — upstream oil and gas, refining, fuels retail and trading. the thesis reaches it through its integrated LNG supply, marketing and trading book: a portfolio built to roughly 23 mtpa by 2023 with a 25-by-25 and 30-by-30 target, historically about half equity and half merchant, with US offtake at Freeport and Calcasieu Pass plus Coral, Tangguh and Greater Tortue Ahmeyim, and a trading desk that re-optimises cargoes between basins. this is the merchant and portfolio exposure the angle wants, and BP holds no equity in Qatari liquefaction, so there is no offsetting lost volume. but it is a minority earnings line: gas and low carbon energy was $3.2bn of $13.4bn group underlying RC PBIT in Q3 2026, and that segment also carries upstream gas production and renewables, so LNG marketing and trading is a single-digit to low-teens share of group earnings. material but not the business → 0.5.
Woodside is an Australian-based LNG and oil producer (North West Shelf, Pluto, Wheatstone, Sangomar, Gulf of Mexico) with an in-house marketing and trading arm. LNG is roughly 45% of 2026 guided production; crude, condensate and pipeline gas make up the rest. the thesis reaches the hub-linked LNG tranche: the company guides about 30% of produced LNG to gas-hub pricing (41.8% in Q4 2025, about 51% of LNG sold in Q1 2026, 39% in H1 2026), with a disclosed realised premium over oil-linked pricing, plus spot cargoes from the portfolio and a trading book worth about 3% of EBIT. that puts the spot-exposed slice near 15 to 20% of equity production, with the balance oil-indexed LNG, liquids and domestic gas. no Qatari equity, so no offsetting loss. material but not the whole business → 0.6. Louisiana LNG (2029) is outside the horizon; Scarborough first cargo Q4 2026 adds commissioning volumes.
Equinor is a Norwegian integrated major; roughly half of its 2.3 mboe/d output is gas, nearly all of it piped to Europe and sold at hub-tracking prices (realised European piped gas USD 12.95/mmbtu in q1 2026, which the company itself attributed to LNG supply disruption from the Hormuz closure). E&P Norway produced USD 7.7bn of USD 9.8bn group adjusted operating income, so a TTF spike reaches the bulk of earnings one-for-one — but through pipeline gas, not spare LNG cargoes. the LNG-specific merchant book is small: a 36.8% share of Hammerfest LNG (6.5 bcm/yr gross) plus ~3.5 mtpa of Henry Hub-indexed Cheniere offtake ramping from h2 2026, under 10% of gas volume. the thesis price channel is expressed at scale, the thesis asset (redirectable cargoes) is peripheral → 0.5, core-eligible but not merchant-pure.
Vermilion Energy is a Calgary-based, NYSE-listed e&p producing about 120 mboe/d, roughly 70% gas, split between Canadian Deep Basin and Montney gas (AECO-priced) and conventional gas in the Netherlands, Germany and Ireland sold directly at TTF and NBP. the european tranche was about 15% of 2025 production (13% to 17% in recent quarters, over 110 mmcf/d) but earns a multiple of AECO, so it is a disproportionate share of fund flows and the company's stated reason for a $6.01/mcf realised gas price versus a sub-$2 AECO benchmark. that is exactly the leg 3 pattern — a disclosed, non-trivial tranche with destination-hub pricing — and more direct than a jkm-indexed us sales contract. offsets: about half of european gas is hedged for 2026 at a $13 floor, the other 85% of volumes are AECO, WTI and Brent, and it is not a us producer. material but minority exposure → 0.5.