LNG

An LNG (Liquefied Natural Gas) — natural gas cooled to -162°C to transform it into a liquid for ocean transport — is the mechanism that enables natural gas to be traded globally. Unlike oil, which flows in pipelines and ships, natural gas must be liquefied (shrinking its volume 600x) to be shipped long distances. This constraint makes LNG prices regional and often 2–3x higher than US natural gas prices.

The global gas solution

Natural gas is chemically locked in underground reservoirs and extracted via wells. However, transporting gas via pipeline is economical only over medium distances (500–2,000 miles). For longer distances — transcontinental or transoceanic — liquefaction is required.

Liquefaction involves cooling gas to -162°C, transforming it into a liquid that occupies 1/600th the volume. This liquid is loaded onto specialized cryogenic tanker ships, transported globally, and regasified at destination terminals.

This infrastructure-intensive process — liquefaction plant, tanker ships, regasification terminals — has costs of $2–4 per MMBtu. These costs are why LNG prices are typically $2–5 higher per MMBtu than US natural gas.

Long-term contracts vs. spot market

Historically, LNG was traded entirely via long-term contracts (10–20 years) between producers and importing countries, with prices indexed to crude oil prices. This created stable, predictable pricing but locked in both producer and buyer.

In recent decades, spot markets for LNG have emerged, allowing flexible trading. However, long-term contracts still dominate (60–70% of LNG), with spot and short-term contracts accounting for the remainder.

The emergence of spot markets has allowed LNG to function more like a commodity, with prices responsive to supply-demand shocks. The 2022 Russia energy crisis saw European LNG spot prices spike to $50+ per MMBtu, driven by competition for limited Australian and US LNG cargoes.

Qatar’s dominance and supply concentration

Qatar has long been the world’s largest LNG producer (~25% of global supply), with a combination of cost advantages (abundant gas reserves, cheap labor) and geopolitical leverage.

However, new LNG projects in Australia (Gorgon, Wheatstone) and the US (Sabine Pass, Corpus Christi) have diversified supply. Australia is now roughly co-equal with Qatar. Together, they supply ~50% of global LNG.

Russia’s Baltic LNG project was shut off due to Western sanctions, removing a significant supply source and tightening global supply.

Asia pricing premium

Asian LNG prices (Japan, South Korea, Taiwan, China) typically trade $3–10 per MMBtu above US Henry Hub natural gas prices, reflecting transport costs and regional supply scarcity.

Japan, which imports essentially all its natural gas as LNG, is thus exposed to global LNG price swings. Winter 2021–2022 saw Japanese wholesale electricity prices spike as LNG spot prices soared, creating a crisis for energy-intensive industries.

Europe, historically supplied by Russian pipelines, has begun importing LNG to diversify. European LNG terminal capacity was rapidly expanded in 2022–2023 to accommodate spot purchases, and LNG prices in Europe are now closer to global spot prices than to US Henry Hub.

Liquefaction plant economics

Building an LNG liquefaction plant requires $10–20 billion of capital investment and 5–7 years of construction. The plant must then operate for 20–40 years to recoup costs.

For a liquefaction plant to be economic, it requires:

• Cheap feedstock: Access to low-cost natural gas (either local production or import via pipeline).
• Reliable markets: Long-term contracts or confidence in future LNG demand.
• Stable geopolitics: No risk of sanctions or civil conflict disrupting operations.

This capital intensity explains why LNG is concentrated in a few countries and why new capacity takes years to develop.

Regasification and import terminals

Importing countries require regasification terminals to convert LNG back to gas for pipeline injection. These terminals are also capital-intensive ($1–3 billion each) and require years to construct.

The UK, Netherlands, and other European countries rapidly built LNG terminals in 2022–2023 to substitute for Russian pipeline gas. This terminal-building boom reduced Europe’s LNG import costs (more local liquefaction reduces shipping costs) and diversified supply sources.

Spot trading and commodity exchanges

The LNG spot market is growing, with traders using specialized exchanges to buy and sell cargoes (a “cargo” = one tanker = ~130,000 m³). However, spot trading remains fragmented and less transparent than crude oil or natural gas futures.

Pricing references (from firms like S&P Global, Platts) publish spot price indices based on observed transactions, providing markets with reference prices.

Retail access to LNG trading is minimal; most participation is institutional or hedging-related.

Supply-demand outlook

Global LNG demand is expected to grow 2–3% annually through 2030, driven by:

• Asian electricity demand: China, India, and Southeast Asia building gas-fired power plants.
• European diversification: Moving away from Russian pipelines.
• Energy transition: Natural gas as a bridge fuel to renewables.

New LNG supply is also growing, with projects in Tanzania, Mozambique, and other regions coming online. The supply-demand balance suggests modest price moderation from 2022–2023 highs, though periodic spike risks remain.

Risks and geopolitical

LNG is vulnerable to:

• Geopolitical disruption: Producer-country conflict (Qatar-Saudi rift, Australia-China tensions) disrupts supply.
• Weather and disasters: A typhoon or regasification plant outage creates spot shortages.
• Policy changes: A country’s decision to nationalize LNG resources or restrict exports (like Qatar’s 2005 gas field disputes).

The concentration of supply and long lead times for new capacity mean supply shocks can persist for months or years.

See also