LNG pricing is complex and varies dramatically by region, governed by three major global benchmarks: Henry Hub (North America), TTF (Europe), and JKM (Asia-Pacific). In mid-October 2026, spot prices ranged from about $3/MMBtu in the US to roughly $28–30/MMBtu in Europe and Asia, which is the widest gap since the 2022 crisis. The cause is the loss of most Qatari supply after the March 2026 attacks on Ras Laffan (see below).
The Three Major Pricing Benchmarks
| Benchmark | Region | Current Price | Unit | Market Type |
|---|---|---|---|---|
| Henry Hub | North America (USA) | ~$3.10 | $/MMBtu | Pipeline gas futures |
| TTF (Title Transfer Facility) | Europe (Netherlands) | ~€85 (~$28) | €/MWh | Hub-based, liquid spot market |
| JKM (Japan/Korea Marker) | Asia-Pacific | ~$30 | $/MMBtu | Spot LNG assessment |
Henry Hub (HH) - USA Natural Gas Benchmark
- Location: Erath, Louisiana (pipeline hub)
- Traded on: NYMEX (New York Mercantile Exchange)
- Liquidity: Extremely high (most liquid gas contract globally)
- LNG Relevance: Base cost for US LNG exports; liquefaction adds ~$3-4/MMBtu
- Historical Range (2020-2026): $1.80-$9.20/MMBtu
Track Live Prices: Monitor real-time Henry Hub and global natural gas prices at NatGasChart.com for up-to-the-minute market movements and historical charts.
TTF (Title Transfer Facility) - European Gas Benchmark
- Location: Virtual trading point in the Netherlands
- Traded on: ICE Endex
- Unit Conversion: €/MWh → $/MMBtu (1 MWh ≈ 3.412 MMBtu)
- 2022-2023 Crisis: Spiked to €200+/MWh ($70/MMBtu) post-Ukraine invasion
- 2026 Status: Normalized to around €28/MWh in January, then repriced sharply after Qatari supply was lost in March. By October 2026 it was around €85/MWh
JKM (Japan/Korea Marker) - Asia-Pacific LNG Spot Price
- Assessment: Platts (S&P Global) front-month spot DES price
- Delivery: Northeast Asia (Japan, South Korea, Taiwan, China)
- Premium Driver: Asian buyers historically pay premium for energy security
- 2026 Context: Asian demand stayed soft, but JKM still rose to its highest level in nearly four years (~$29–30 in mid-October) as Qatari cargoes, mostly sold to Asia, went missing
2026: The Qatar Supply Shock and What It Did to Prices
For most of 2025 the market expected a supply glut. That changed in March 2026. Drone strikes on 2 March halted LNG production at Ras Laffan and Mesaieed, and further strikes on 18–19 March damaged two liquefaction trains. Those two trains are about 12.8 MTPA, or roughly 17% of Qatar’s capacity, and repairs are expected to take years. Shipping through the Strait of Hormuz, which every Qatari cargo must cross, has stayed disrupted, and QatarEnergy has repeatedly extended force majeure on contracted cargoes.
| Benchmark | January 2026 | Early March 2026 | Mid-October 2026 |
|---|---|---|---|
| Henry Hub | $3.50/MMBtu | Little changed | ~$3.10/MMBtu |
| TTF | €28/MWh | ~€46/MWh (+45% in a day) | ~€85/MWh (~$28/MMBtu) |
| JKM | $13.50/MMBtu | Up ~39% | ~$29–30/MMBtu |
The shock barely touched Henry Hub, because US gas is priced by domestic supply and US export plants were already running near capacity. Europe and Asia bid against each other for the remaining flexible cargoes, so TTF and JKM rose almost in step. As a result, the US–Asia spread is now several times wider than the cost of liquefying and shipping US gas. Our March report covers the first days of the disruption, and the Qatar LNG page covers the state of Ras Laffan and the North Field expansion.
The two hub benchmarks are compared directly — what each one actually prices, how to convert €/MWh to $/MMBtu, and why the gap persists — in Henry Hub vs TTF.
LNG Contract Pricing Mechanisms
1. Oil-Indexed Pricing (Legacy Model)
Traditional long-term contracts in Asia link LNG prices to crude oil benchmarks (JCC - Japan Crude Cocktail):
Formula: LNG Price = (α × JCC) + β
- α (slope) typically 10-15% of crude oil price
- β (constant) represents fixed costs
- Example: If JCC = $80/barrel, LNG ≈ $10-12/MMBtu
Rationale: Historically, oil and gas competed for the same industrial/power markets. As gas markets matured, this linkage weakened.
2026 Status: Still used in ~30% of Asian long-term contracts, down from 70% in 2015.
2. Hub-Based Pricing (Market Model)
Prices determined by supply-demand at regional trading hubs:
- North America: Henry Hub + liquefaction fee + shipping (~$3.50 + $3 + $1.50 = $8.00 FOB)
- Europe: TTF prices reflect pipeline gas competition
- Transparency: Real-time market pricing, no oil linkage
3. Hybrid Indexation
Modern contracts blend oil-indexation with hub prices:
Example: LNG Price = 50% × JCC + 30% × JKM + 20% × Henry Hub
Reduces volatility while maintaining market responsiveness.
Spot vs. Long-Term Contracts
| Contract Type | Duration | Volume Flexibility | Price Basis | Market Share (2026) |
|---|---|---|---|---|
| Long-Term (LT) | 10-25 years | Take-or-Pay (80-95%) | Oil-indexed or hybrid | ~60% |
| Medium-Term (MT) | 2-5 years | Annual Contract Quantity | Hub-based or hybrid | ~15% |
| Spot/Short-Term | Single cargo or <1 year | Fully flexible | JKM, TTF, or bilateral | ~25% |
Take-or-Pay Obligations
Most long-term contracts include Take-or-Pay (TOP) clauses:
- Buyer must pay for minimum annual volume (e.g., 90%) even if not taken
- Provides revenue certainty for liquefaction project financing
- Typical TOP: 85-95% of Annual Contract Quantity (ACQ)
- Unused volumes may be "banked" for future use (makeup provisions)
Destination Flexibility
Modern contracts increasingly allow destination flexibility:
- Restricted (Legacy): Cargo must be delivered to specific country
- Free Destination: Buyer can redirect cargo to highest bidder
- 2026 Trend: ~70% of new contracts have destination flexibility (vs. 40% in 2020)
LNG Delivered Cost Breakdown
Total delivered cost to Asia from US Gulf Coast (illustrative, at October 2026 Henry Hub; shipping and regasification are typical long-run values):
| Component | Cost ($/MMBtu) | Notes |
|---|---|---|
| Henry Hub Gas Price | $3.10 | Feedstock cost |
| Liquefaction Fee | $3.00 | Tolling fee (e.g., Cheniere, Freeport) |
| Shipping (US → Asia) | $1.80 | ~20-day voyage, Q-Max charter ~$100k/day |
| Regasification | $0.50 | Terminal fees in Asia |
| Total Delivered Cost | $8.40 | Far below JKM at ~$30 (Oct 2026) |
Arbitrage Opportunity: In a normal market such as January 2026, when JKM was $13.50, the gross margin on this route was about $4–5/MMBtu. With JKM near $30 in October 2026, the theoretical margin is above $20/MMBtu before financing, risk and any crisis-related freight premiums. This is a crisis spread, not a stable one, and it is why every uncontracted US cargo is currently being bid for.
Regional Price Dynamics (2026)
North America: Shale Gas Abundance
- Henry Hub: ~$3.10/MMBtu in October 2026 (range: $2.80-$5.20 in 2025), largely insulated from the 2026 Gulf disruption
- Driver: Permian Basin associated gas production exceeds pipeline capacity
- Export Economics: US LNG highly competitive globally; netback pricing allows export at HH + $3-4
- Constraint: Liquefaction capacity, not feedstock
Europe: Post-Ukraine Transition
- TTF: ~€85/MWh (~$28/MMBtu) in October 2026, up from €28/MWh in January
- 2022-2023 Crisis: Russian pipeline cuts sent TTF to €200+/MWh
- 2026 Reality: The post-2022 normalization relied on LNG imports (120 MTPA in 2025 vs. 80 pre-crisis). That reliance exposed Europe again when Qatari supply was lost in 2026
- Sources: US (40%), Qatar (25%), Algeria/Nigeria/Norway (35%)
- Storage: The 2026 refill season had to replace missing Qatari cargoes; see Europe’s summer restocking
Asia-Pacific: Demand Moderation
- JKM: ~$29–30/MMBtu in mid-October 2026, up from $13.50 in January and the highest in nearly four years
- China Slowdown: Economic growth 4.5% (2025) vs. 8% pre-pandemic; reduced LNG imports
- Japan/Korea: Stable demand; nuclear restarts in Japan reduce LNG dependence
- Southeast Asia: Growing demand (Thailand, Vietnam, Philippines) offsets Northeast decline
Price Volatility & Risk Management
Historical Volatility
TTF 2022 Crisis Example:
- January 2022: €70/MWh
- August 2022: €220/MWh (peak)
- December 2022: €120/MWh
- January 2026: €28/MWh
- March 2026: ~€46/MWh (Qatar production halt)
- October 2026: ~€85/MWh
The 2022 swing was about 3x within a year, and 2026 produced another 3x move in nine months. Both show how quickly the market reprices when a large share of supply disappears.
Hedging Strategies
Market participants use various tools to manage price risk:
- Financial Swaps: Fix price via OTC derivatives (e.g., JKM swaps cleared via CME)
- Futures Contracts: TTF futures on ICE Endex, Henry Hub on NYMEX
- Portfolio Diversification: Blend oil-indexed and hub-based contracts
- Storage Arbitrage: Buy in summer (low demand), sell in winter (high demand)
Pricing Outlook: 2026-2030
Supply Glut Scenario (Delayed)
This was the consensus base case before March 2026. It has been pushed back rather than cancelled. North Field East’s first LNG has slipped to around early 2027, and the damaged Ras Laffan trains will be out for years. US capacity additions are arriving on schedule.
- New Capacity: ~150 MTPA due 2026-2028 (Qatar North Field, US projects), with the Qatari share now running late
- Expected Impact: JKM falls to $10-12/MMBtu; TTF to $9-10/MMBtu
- Winner: Buyers (lower costs); Asian industrials benefit most
- Loser: High-cost producers (e.g., floating LNG projects with breakeven >$12)
Upside Risks (Tight Market)
- Triggers: Cold winter in Asia/Europe, supply outages, geopolitical disruption
- Potential Spike: JKM to $20-25/MMBtu (2024 levels)
- 2026 outcome: This scenario happened. Geopolitical disruption took JKM to ~$30/MMBtu by October 2026
Long-Term Trajectory (2030+)
- Decarbonization Pressure: Carbon pricing ($50-100/tonne CO₂) adds $1-2/MMBtu
- Competition: Renewables + batteries challenge gas in power generation
- Stabilization: Prices likely converge globally at $10-14/MMBtu as markets mature
Key Takeaways
- Three global benchmarks: Henry Hub (~$3.10), TTF (~€85/~$28), JKM (~$30) in mid-October 2026
- The 2026 Qatar outage split the market: US gas stayed cheap while European and Asian prices more than doubled
- US LNG is cost-competitive globally due to cheap shale gas
- Long-term contracts shifting from oil-indexation to hub-based pricing
- Spot market share growing: 25% in 2026 vs. 15% in 2020
- Delivered US LNG to Asia costs ~$8–9/MMBtu, far below 2026 crisis-level JKM
- 2027-2028: The expected supply glut is delayed, not cancelled, and depends on Qatar’s recovery and on Hormuz shipping
- Destination flexibility now in 70% of new contracts, enabling price arbitrage