Natural Gas and LNG: From Hub Benchmark to Delivered Industrial Cost

AI-generated editorial illustration; it does not depict a verified project, actual prices or chart data.

1. Economic decision

Cheap upstream gas does not automatically mean cheap delivered LNG. The purchaser buys a supply chain with transformation, transport, terminal access, retained-energy losses and local delivery. Henry Hub is a US gas hub; TTF is a European hub; a Japanese import CIF series is an import benchmark. Their spread is not a transport invoice and does not demonstrate an accessible arbitrage for an industrial customer. Start with the delivery obligation and usable thermal energy rather than selecting the lowest index and appending an undocumented premium.

2. Dated market evidence

The World Bank October Pink Sheet, released 2 October, records August→September 2026 prices: Henry Hub 2.77→2.95, European TTF 21.11→25.42 and Japan LNG 15.27→14.25 USD/MMBtu. The recent two Japanese observations are estimates and represent import CIF, not spot JKM. These different movements reinforce why location and contract basis matter. EIA's LNG explanation describes the physical chain; the figures below are deliberately separate hypothetical costs rather than a reconstruction of either import series.

3. Cost boundary and calculation

All worked costs are illustrative nominal-currency scenarios as of 7 October 2026, not vendor quotations or observed October averages. Recoverable VAT, finance, penalties and carbon costs are excluded unless expressly stated. Sources retain their own observation period and forecast classification.

Define every input per MMBtu on a higher heating value, HHV, basis. Let hub gas be 4 USD/MMBtu with an illustrative 1.02 feed factor; liquefaction toll 2.5, shipping 1.2 and regasification 0.5 USD/MMBtu. Upstream subtotal = 4 × 1.02 + 2.5 + 1.2 + 0.5 = 8.28 USD/MMBtu. Retained energy is 0.98 of the starting cargo, giving 8.28/0.98 = 8.44898. Add pipeline delivery 0.8 to obtain 9.24898 USD/MMBtu HHV. This formula puts the local pipeline charge after the retained-energy denominator; applying the denominator to every fee would change the contractual boundary.

A capacity reservation can make the average delivered price depend on utilisation. Suppose an additional terminal reservation is 1200000 USD/year and the purchaser uses 600000 MMBtu/year. That separate charge adds 2 USD/MMBtu. At 300000 MMBtu/year with the same reservation, it adds 4 USD/MMBtu. The chart deliberately excludes this fee; appending it is appropriate only if the actual offer does not already recover terminal access. A low spot commodity price can therefore coexist with a high average site bill at low utilisation.

4. Sensitivity and cost table

Illustrative HHV model: hub 3/4/5 USD/MMBtu, 1.02 input factor, liquefaction 2.5, shipping 1.2, regasification 0.5 USD/MMBtu; divide the upstream subtotal by 0.98 retained energy, then add pipeline 0.8. Results 8.2082/9.2490/10.2898 USD/MMBtu HHV; not actual offers.

The retained-energy factor must be attached to its physical leg. In this example the 0.98 factor describes the upstream cargo chain and the local pipeline fee follows it. A contract with shipping priced per delivered MMBtu needs different bookkeeping from a shipping invoice per loaded MMBtu. Do not infer a universal 2% voyage loss: this is an illustrative factor requiring replacement with voyage, terminal and custody-transfer records. Temperature, composition and measurement conditions also matter when converting a volume obligation into MMBtu; standard cubic metres alone do not supply a fixed universal energy content.

5. Operational interpretation

For the sensitivity chart, use the same model: at hub 3/4/5 USD/MMBtu the correct delivered costs are 8.2082/9.2490/10.2898 USD/MMBtu HHV. A 1 USD/MMBtu hub increase changes delivered cost by 1.02/0.98 = 1.04082 USD/MMBtu, not exactly one. Convert with 1 MWh = 3.412142 MMBtu: the base is approximately 31.56 USD/MWh thermal HHV. A boiler with 90% HHV efficiency needs 31.56/0.90 = 35.07 USD/MWh useful heat before its operating and capital costs. An LHV-rated efficiency cannot be inserted unchanged into an HHV-price calculation.

For a hypothetical 600000 MMBtu annual purchase, the base commodity-and-delivery model costs approximately 5549388 USD/year before the separate reservation. A one-dollar hub increase adds 600000 × 1.04082 = 624492 USD/year at unchanged volumes. If annual fuel use falls by 10% without releasing the reservation, the variable model falls approximately 554938.8 USD while the reservation remains. This separates avoidable fuel from sunk access commitments; do not report a 10% reduction of the complete bill as fuel savings.

6. Contract evidence and decision trigger

Check whether feed gas, fuel retention and boil-off are already paid through the toll or separately deducted from title energy. Verify terminal reservation, minimum take, voyage responsibility, pipeline capacity and balancing. Adding a generic shipping premium to an already delivered quote can duplicate transport. The procurement trigger is the comparable site cost at required volume and availability, not the hub spread alone. If an indexed LNG contract uses oil linkage, its slope, lag and constant must be applied as signed; do not substitute Henry Hub exposure simply because that index is public.

Evidence should reconcile three meters or records where applicable: energy loaded, energy delivered after terminal processing, and energy accepted at the industrial boundary. Assign settlement losses to the correct party. Check whether a buyer can redirect a cargo or release capacity before assigning flexibility value; a theoretical alternative market is not an executable contract right. When comparing LNG with pipeline gas, hold useful heat, required pressure, daily flexibility and supply continuity constant. A cheaper interruptible route may need priced storage or backup, which must be shown separately rather than hidden in a blanket delivery premium.

7. Frequently asked questions

Is Japan CIF LNG the same as spot JKM? No; the Pink Sheet import series has a different basis and recent estimates. Does MMBtu specify HHV automatically for every contract? No: confirm the contractual calorific basis. Can the hub difference fund guaranteed savings? No: capacity rights, tolls, losses, volume obligations and price exposure must be evidenced first.

8. References and related engineering

• World Bank October 2026 Pink Sheet
• EIA LNG explanation
• EIA energy conversion calculators
• EIA October STEO

• LNG shipping and delivered energy
• Generator spark spread and heat rate