LNG and Natural Gas Benchmarks Explained: Henry Hub, TTF, JKM and Global Pricing
Natural gas does not have a single universal world price. Henry Hub, TTF and JKM describe different regional markets and contract conventions, while liquefied natural gas (LNG) links those markets through ships, liquefaction terminals and regasification infrastructure. A spread between benchmarks can indicate an incentive to redirect cargoes, but it is not a guaranteed arbitrage profit.
This article explains how to compare natural gas benchmarks and why unit conversion, location, delivery period and transport costs must come before an interpretation of price differences.
Key takeaways
- Henry Hub references US natural gas; TTF is a European virtual gas hub; JKM represents an Asian LNG price assessment.
- Quotes can be in USD/MMBtu or EUR/MWh and may reference different delivery windows.
- Liquefaction, shipping, regasification and contractual commitments affect whether regional price spreads can be captured.
- Storage, pipeline constraints and weather can make regional prices diverge even when LNG trade expands.
Essential concepts and market terminology
Henry Hub
A key US natural gas pricing point in Louisiana, commonly referenced in US physical and futures markets and quoted in dollars per million British thermal units.
TTF
Title Transfer Facility, a Dutch virtual trading hub widely used as a European gas benchmark; gas futures often quote in euros per megawatt-hour.
JKM
Japan Korea Marker, an Asian LNG price assessment commonly referenced in physical supply contracts and derivatives, with specific delivery and assessment terms.
LNG
Natural gas cooled into liquid form for shipping. Liquefaction and subsequent regasification require specialised terminals, energy and infrastructure.
MMBtu
One million British thermal units, an energy unit used frequently in natural gas and LNG contracts.
MWh
A megawatt-hour, an energy quantity frequently used for European gas pricing; conversion to MMBtu requires a consistent energy basis.
Liquefaction toll
A charge or cost associated with converting feedgas to LNG, potentially arising under contracted capacity arrangements.
Regasification
The process of returning imported LNG to gaseous form for delivery into a local network; terminal capacity and fees can be constraints.
Freight spread
The additional delivered cost or difference arising from vessel hire, routing, canal access, port availability and voyage duration.
Basis risk
A mismatch between the market benchmark being hedged and the actual delivered gas exposure, including location, timing, currency and quality.
How to analyse LNG price benchmarks
Henry Hub, TTF and JKM refer to different markets
Henry Hub is associated with US pipeline gas pricing. TTF serves as a key reference for European gas, while JKM is used for LNG cargoes delivered to northeast Asia under relevant assessment conventions. The economic relationship depends on the route and delivery market: a cargo originating from the US Gulf Coast may be able to reach Europe or Asia, but only if contractual, shipping and terminal capacity make a transfer possible.
The benchmarks should be labelled with quotation units and delivery month. A prompt-month futures price, a spot physical cargo assessment and a long-term contract index are different objects. Comparing them without aligning the period can create a false apparent spread.
Start by converting the units correctly
Natural gas quotes may use USD/MMBtu and EUR/MWh. Because 1 MWh of energy is approximately 3.412 MMBtu, a euro-per-MWh figure can be converted to USD/MMBtu using the relevant EUR/USD exchange rate and dividing by roughly 3.412. The heating value, billing basis and contractual formula may create differences from a simple textbook conversion.
A price difference after conversion is still not a net tradable margin. Fees, fuel losses, freight and terminal charges must be included. Foreign-exchange movements can affect the dollar value of euro-denominated TTF prices even when the underlying European gas quote is stable.
LNG arbitrage requires ships and infrastructure
To redirect a cargo between markets, a company needs LNG supply rights, a vessel, route access and a regasification slot. Long-term supply contracts may specify destination clauses or cargo obligations. A higher Asian cargo price does not automatically mean that a European-bound cargo can profitably change destination at short notice.
Fuel consumption, boil-off, waiting time and port congestion can add costs. During peak demand, the price of incremental terminal capacity may surge. A simple difference between JKM and TTF omits these operational and legal constraints and can misstate the available commercial opportunity.
Weather matters through demand and infrastructure
Winter heating demand can strengthen European and Asian gas markets while summer power demand can raise US consumption. Storage levels, nuclear generation, wind output and pipeline disruptions affect regional balances. Seasonal conditions can alter not only outright prices but the forward curves and storage incentives.
Weather forecasts introduce uncertainty; a colder week in one geography may be offset by milder demand elsewhere or by unusually high storage. An analyst should distinguish daily weather sensitivity from structural supply conditions and the timing of LNG arrivals.
Price transmission is incomplete
International LNG imports and exports create a link between regions, but natural gas remains less globally fungible than crude oil. Infrastructure, contract duration, storage and weather contribute to persistent price differences. A US export terminal’s capacity and the domestic pipeline network can constrain the speed at which overseas demand reaches Henry Hub.
Regional supply dynamics also differ: European pipeline imports and underground storage are distinct from US shale output and the seasonal export logistics of Asia. A model assuming instant global price convergence will often misrepresent near-term market conditions.
Compare regional curves rather than single prices
Instead of checking one prompt price, compare nearby and deferred contracts to assess seasonal expectations and storage economics. A steep winter premium can reflect seasonal demand and low storage headroom, but the curve can also incorporate risk compensation and market positioning.
Mark each futures instrument’s own expiry and settlement rules. A continuous chart may roll between contracts, creating apparent jumps that are not a price move in a single delivery month. Record underlying delivery date and source for all quotations.
What to include in an LNG research note
List the location, benchmark, pricing unit, currency, contract month, freight assumptions, import terminal utilisation and storage availability. Compare the delivered cost of a hypothetical cargo with the price at the intended destination only after allowing for existing contractual obligations.
Stress a freight-price jump, a pipeline interruption, an exchange-rate move and a weather reversal. Distinguish the market price of gas from an LNG operator’s actual netback, and avoid assuming all producers or utilities can respond to benchmark spreads in the same way.
Worked educational example
Suppose a hypothetical TTF quote is €30/MWh and EUR/USD is 1.10 dollars per euro. A rough energy-equivalent conversion is €30 × 1.10 ÷ 3.412 ≈ $9.67/MMBtu. If a separate JKM cargo assessment were $12.00/MMBtu, the nominal spread would be about $2.33/MMBtu before differences in delivery periods and commercial costs. If extra shipping and destination charges were $2.80/MMBtu, this simplistic comparison would not show a positive margin. Conversely, other routes might have different costs. The example uses invented values solely to illustrate the need for aligned units, dates and logistics.
Comparison table
| Benchmark | Main market | Typical quotation |
|---|---|---|
| Henry Hub | United States pipeline gas | USD/MMBtu |
| TTF | European gas hub | EUR/MWh |
| JKM | Northeast Asian LNG | USD/MMBtu |
| Delivered LNG netback | Cargo economics | After logistics and contract terms |
Practical research checklist and common mistakes
Before interpreting a market statistic, identify exactly what the number measures, where it applies and the date or delivery period. Use reliable primary sources and record whether a value is a forecast, a realised observation, a quoted bid/offer or a model estimate. Ensure prices, quantities and percentages use matching units and periods; mixing stock levels with flow rates or comparing contracts from different expiries can create plausible but erroneous conclusions.
Next, establish what the market already expected. A figure that appears large in absolute terms may be unsurprising and therefore have little incremental information. Test an alternative explanation for any observed relationship, including supply shifts, transportation bottlenecks, monetary conditions, inventory changes or revisions. Do not infer causation from a short price-chart response. Treat any worked numerical example here as illustrative, not an executable quotation.
Finally, record the sources of uncertainty: estimation, coverage, market liquidity, product specifications, funding, currency, settlement and regulatory changes. Futures and options may create additional margin requirements or losses. No commodity market indicator, chart, ratio or statistical release guarantees an investment outcome.
Worked comparison: price normalisation and cargo netback
Suppose a hypothetical LNG shipment can reach either Europe or Northeast Asia, with gross destination prices of $10.50/MMBtu and $12.10/MMBtu respectively on matched delivery dates. Assume total shipping and handling from the same origin are $1.40/MMBtu to Europe and $3.20/MMBtu to Asia. Ignoring fees and contractual restrictions, the indicative netbacks are $9.10 and $8.90 per MMBtu. Despite Asia’s $1.60 higher gross price, the European route yields a higher illustrative netback after these assumed transport costs. The real result can differ due to fuel losses, terminal congestion, charter commitments and cargo-specific rights.
A cross-regional spread is therefore not simply a difference between two line charts. Check if the reported JKM and TTF quotations use equivalent cargo delivery periods, whether the vessel is available, and which terminal or balancing point the quote refers to. A futures position referencing a regional benchmark does not confer legal rights to redirect an LNG ship. This distinction is essential when interpreting commercial ‘arbitrage’ commentary.
Risk scenario: A new pipeline outage could increase European hub prices while Asian spot LNG remains stable. Alternatively, a sudden fall in shipping costs could narrow delivered-price differences. Both events may alter spreads without changing US Henry Hub production immediately. Track production, storage, transport, regasification and currency factors separately before arguing that regional gas prices should converge.
Frequently asked questions
Is Henry Hub the global LNG price?
No. It is an important US gas reference; international LNG contracts and delivered cargoes have additional pricing, transport and infrastructure considerations.
Why can JKM be above TTF?
Weather, regional demand, shipping costs, contractual constraints and storage conditions can create different delivered values.
Can a high JKM–TTF spread always be traded?
No. Rights to cargoes, vessels, terminal access, timing and fees may prevent profitable cargo redirection.
Why are TTF and Henry Hub quoted differently?
Their local market conventions use different currencies, energy units and delivery references. Normalize before comparing.
Related Traders MBA education
Natural Gas Trading Fundamentals; Natural Gas Storage Reports; Commodity Futures Explained. Also see the Commodities category and Education Hub.
Sources and further reading
Important notice: This is general financial education, not personalised financial advice, investment research on a particular product or a recommendation to trade. Numerical examples are hypothetical. Physical commodities, derivatives and leveraged exposures involve substantial market, execution, funding and other risks, including possible losses.