Natural Gas: Henry Hub, TTF and Seasonality

Why Gas Is Regional When Oil Is Global

Crude oil can be loaded onto a tanker and shipped almost anywhere on Earth within weeks. Natural gas, in its raw form, cannot — it's a gas, so it needs either a pipeline or an expensive conversion process to move long distances. This physical reality makes natural gas markets far more regional than crude oil markets.

Pipelines are the traditional solution. A pipeline connects a production field to homes, power plants, and factories in a fixed corridor. If supply and demand fall out of balance somewhere along that corridor, the price there moves independently of what's happening in Asia or South America. There's no quick way to reroute molecules the way a shipping company reroutes a tanker.

The result is that the world has several largely separate natural gas markets, each with its own benchmark price. Two dominate the headlines: Henry Hub in the United States and TTF in Europe.

Henry Hub: The US Benchmark

Henry Hub is a pipeline interchange in Erath, Louisiana, where multiple major pipelines converge. It became the standard delivery point for the US natural gas futures contract traded on the CME Group exchange. When you see a US natural gas price, it almost certainly refers to the price at Henry Hub.

The unit matters enormously here. Henry Hub is quoted in dollars per MMBtu. MMBtu stands for one million British thermal units — a BTU is the amount of energy needed to raise one pound of water by one degree Fahrenheit, and a million of them is a practical energy quantity for trading gas. Suppose a contract shows a price of $3.00: that means $3.00 for one MMBtu of gas delivered at Henry Hub. A single CME futures contract covers 10,000 MMBtu, so even small price moves translate into meaningful dollar swings per contract.

Henry Hub reflects the US market's unique supply picture. The shale revolution — horizontal drilling and hydraulic fracturing — unlocked vast reserves of natural gas in formations like the Marcellus and Permian Basin. US production surged from the 2010s onward, which historically kept Henry Hub prices lower than European equivalents for extended periods.

TTF: The European Benchmark

TTF stands for Title Transfer Facility, a virtual trading point operated by the Dutch grid operator in the Netherlands. Think of it not as a physical location but as a legal point where ownership of gas changes hands within the Dutch network. It has become the dominant benchmark for European gas markets.

TTF is quoted in euros per megawatt-hour (MWh). A megawatt-hour measures electrical or thermal energy — one megawatt of power sustained for one hour. This is a different unit from the US MMBtu, which is one reason the two prices look so different numerically even when the underlying energy value is similar. To compare the two meaningfully, you'd need to convert: one MMBtu is roughly 0.293 MWh, though traders use precise conversion factors depending on the gas's exact energy content.

Europe historically sourced much of its pipeline gas from Russia, Norway, and North Africa. Unlike the US, it doesn't have a single dominant domestic production source, which makes it more exposed to geopolitical disruptions and international price swings.

The Storage Cycle: Inject in Summer, Draw in Winter

Seasonality is more powerful in natural gas than in almost any other commodity. Demand for heating spikes every winter in the Northern Hemisphere, while production runs at a steadier pace year-round. To bridge that gap, operators use underground storage facilities — depleted gas fields, salt caverns, and aquifer reservoirs that can hold large volumes of gas.

The annual cycle works like this:

• Injection season (roughly April through October): Demand is lower, so gas produced beyond immediate needs is pumped into storage. Prices tend to reflect current supply-demand conditions plus the cost of storing gas for later.
• Withdrawal season (roughly November through March): Demand for heating rises sharply, and operators draw gas out of storage. If storage levels entering winter are low, or if a cold snap hits unexpectedly, prices can spike quickly.

Storage reports are published regularly by government agencies and grid operators — in the US, the Energy Information Administration releases weekly storage data. Traders and analysts watch storage levels closely relative to historical averages. If storage is well below the five-year average heading into winter, markets typically interpret that as a tighter supply cushion. You can track upcoming storage releases on the economic calendar.

Weather forecasting is therefore a real input into gas market analysis. An unexpectedly cold winter in Europe or a hotter-than-normal summer in the US (which drives air-conditioning demand and therefore gas-fired power generation) can shift the storage balance quickly. What moves commodity prices in gas markets is often as simple as a ten-day weather forecast being revised.

LNG: The Bridge Between Regional Markets

Liquefied Natural Gas, or LNG, is what happens when you cool natural gas to roughly minus 160 degrees Celsius: it shrinks to about one six-hundredth of its original volume and becomes a liquid that can be loaded onto specialized tankers. LNG is the technology that has started to connect previously isolated regional gas markets.

An LNG export terminal takes pipeline gas, liquefies it, and loads it onto a tanker. At the destination, a regasification terminal converts it back into gas for the pipeline network. This process is expensive — the infrastructure alone costs billions of dollars — but it allows gas to travel across oceans where pipelines cannot go.

LNG has introduced a degree of price arbitrage between regions. Arbitrage here means that if European TTF prices are significantly higher than US Henry Hub prices, exporters have a financial incentive to send more LNG cargoes toward Europe. This extra supply eventually pushes European prices down and US prices up, narrowing the gap — though shipping costs, terminal capacity, and long-term contracts mean the gap never closes perfectly or instantly.

The 2021–22 European Energy Crisis: A Case Study in Divergence

The most dramatic illustration of how regional gas markets can decouple happened in 2021 and 2022. A combination of factors — a colder-than-normal winter that left European storage unusually low, reduced Russian pipeline supplies amid geopolitical tensions ahead of and during the invasion of Ukraine, and strong Asian LNG demand competing for the same cargoes — sent TTF prices to historic extremes.

At the same time, US Henry Hub prices rose too, but by far less on a relative basis. The gap between TTF and Henry Hub widened to levels that would have seemed impossible a decade earlier, when LNG trade was smaller and the two markets were even more isolated from each other. European governments introduced emergency measures, industries curtailed gas-intensive production, and the crisis accelerated policy discussions around energy independence and the role of renewable energy.

The episode illustrated several durable lessons that economists and energy analysts draw on today. First, pipeline dependency concentrates geopolitical risk. Second, LNG can partially compensate for lost pipeline supply, but terminals take years to build and global LNG capacity has limits. Third, storage levels at the start of winter matter enormously — a market entering the cold season with thin storage has very little buffer against surprises. These themes connect directly to the longer-term energy transition debate, where gas occupies an uncertain middle position between fossil fuels and renewables.

Reading Natural Gas Market Data

When you look at natural gas data on a site like this, a few things are worth keeping straight:

The percentage-change columns — day, week, month, year-to-date, and year-on-year — are often more useful than the raw price level, especially because the two benchmarks use different units and cannot be compared directly as numbers. A guide to interpreting those columns is available at Day, Week, YTD, YoY: Reading Percentage Moves.

Natural gas is also notably volatile — percentage swings that would be alarming in crude oil are relatively routine in gas, particularly around storage report releases and during periods of extreme weather. Understanding volatility as a concept helps put those swings in context without overreacting to any single day's move.

Traders also pay close attention to the futures curve — the pattern of prices across contracts expiring in different months. A curve that shows higher prices for winter months than summer months (reflecting expected heating demand) is normal in gas markets. Large deviations from that typical seasonal shape can signal unusual supply or demand conditions. The concepts of contango and backwardation apply here just as they do in oil markets.