LNG pricing mechanisms: oil-linked, gas-on-gas, and hybrid
LNG pricing has evolved from a simple oil-derivative system to a sophisticated multi-mechanism structure reflecting regional markets, contract innovations, and shifting risk management practices. Here's what actually happens inside the formulas.
The three fundamental models
Oil-linked (the traditional model)
The canonical formula for an Asian long-term contract looks like this:
LNG price = (Brent crude price × slope coefficient) + constant
Slope is typically 11–15% of the crude price, expressed as a decimal (0.11 to 0.15). The constant covers base costs not captured in the oil linkage — typically USD 0.50–3.00 per MMBtu. Both the slope and the constant are negotiated at contract signing and remain fixed for the life of the agreement, subject to periodic review clauses.
The Brent figure itself is rarely today's spot price. Most contracts use a three-month arithmetic average of Dated Brent (Platts DTD), calculated over months n-1, n-2, and n-3 where n is the delivery month. This smoothing dampens volatility but introduces a timing offset against current spot gas markets — something worth examining if you're structuring a new agreement.
Worked example
A 12.65% slope contract with a USD 0.50/MMBtu constant, priced at Brent = USD 80/bbl:
P = (0.1265 × 80) + 0.50 = USD 10.62/MMBtu
At Brent = USD 70/bbl, the same formula gives USD 9.36/MMBtu. Oil-linked contracts move with crude — for better or worse, depending on which side of the deal you sit.
Gas-on-gas (market-based)
Gas-on-gas pricing links LNG directly to natural gas market benchmarks rather than crude oil.
- Henry Hub (US): HH price + liquefaction cost + shipping. The standard for US exports.
- TTF (Europe): Title Transfer Facility spot or futures. Dominant for European delivery.
- JKM (Asia): Japan–Korea Marker assessments. The Asian spot benchmark.
Gas-on-gas pricing is typical for short-term and spot contracts, and increasingly for newer long-term deals where buyers want exposure to actual gas market fundamentals rather than an oil proxy.
Hybrid models
Most post-2020 contracts blend the two. A typical structure is (Oil component × weight) + (Gas component × weight) — for example, 70% JKM plus 30% oil-linked. The idea is to balance price stability (oil) with market exposure (gas), giving both sides some protection against divergence between the two price worlds.
Contract architecture
Beyond the price formula, a few structural mechanisms shape how the contract behaves over time:
- Reopener clauses — periodic review, typically every 3–5 years, allowing either side to request renegotiation of the formula if market conditions shift materially
- S-curve protection — price caps and floors that flatten the formula at extreme ends of the oil price range
- Take-or-pay — minimum volume commitments with defined flexibility mechanisms for buyer-requested under-lifting
Delivery terms matter
Three terms dominate LNG trade:
- DES (Delivered Ex-Ship): price includes shipping to the destination port. Risk transfers on discharge.
- FOB (Free On Board): price at the loading port only. Buyer bears shipping and delivery risk.
- CIF (Cost, Insurance, Freight): comprehensive delivered price.
The delivery term affects what's actually inside the slope. A DES cargo with a 12.65% slope and USD 0.50 constant is economically quite different from a FOB cargo with the same headline numbers — because in the DES case, shipping is recovered through the slope, while FOB puts that burden on the buyer.
Regional patterns
Asia: traditional oil linkage (Brent 13–15% slope) remains common but JKM adoption is growing. Hybrid structures are now the mainstream for new deals.
Europe: TTF-based pricing dominates. Hub-based, spot-market liquid, and diverse in source (pipeline gas plus multiple LNG origins).
Americas: Henry Hub basis plus costs. Export model is FOB with a cost-plus structure. The competitive reference point is pipeline gas economics.
What's changed recently
From roughly 2000 to 2015, oil-linked pricing accounted for over 90% of contracted LNG volumes. Between 2015 and 2025, gas-on-gas pricing expanded to around 30–40% of the market. From 2025 onwards, hybrid models have become the dominant new-deal structure, with the spot market reaching approximately 35% of global trade.
Regional price disparities are narrowing but persistent. Flexibility — shorter contracts, destination swaps, volume adjustments — is increasingly demanded on both sides of new agreements.
Risk management in practice
For price risk: hedging instruments (futures, options, swaps), contract-level flexibility (volume adjustments, destination swaps), and portfolio diversification across pricing mechanisms. For counterparty risk: credit enhancements (guarantees, letters of credit), advanced payment terms, and contractual remedies linked to termination rights.
None of these are a substitute for structural discipline in the underlying contract. A good price formula with weak review mechanisms is still weak. A fair formula with strong reopener clauses and a practical force majeure regime tends to survive longer without disputes.
The practical takeaway
If you're reviewing a long-term SPA today, the most important numbers aren't the slope and constant — they're the review cadence, the volume flexibility, and the destination clause. The formula determines what you pay on day one. The other three determine whether you can still live with the deal in year seven.