The Price That Shocked a Continent
In late 2005, natural gas prices at the Henry Hub benchmark spiked to nearly $15 per million British thermal units, roughly five times what consumers had paid just a few years earlier. Hurricanes Katrina and Rita had torn through the Gulf of Mexico, knocking out production platforms and pipelines. Heating bills soared. Industrial users scrambled. The episode was a reminder that natural gas, for all its reputation as a stable domestic fuel, can behave like a volatile commodity when supply is disrupted. That single spike tells you something important: natural gas markets are deeply sensitive to short-term shocks, even when long-run fundamentals look steady.
The Shale Revolution Changes Everything
The most dramatic structural shift in the dataset is not a spike but a collapse. Between 2008 and 2012, US natural gas prices fell from around $13 per MMBtu to under $2, and they have never fully recovered to pre-shale levels. The reason is hydraulic fracturing combined with horizontal drilling, which unlocked enormous reserves in formations like the Marcellus, Haynesville, and Permian Basin. Producers flooded the market with supply faster than demand could absorb it. Utilities, manufacturers, and power generators all benefited from cheap gas, but exploration companies that had borrowed heavily to drill found themselves caught in a painful squeeze.
The shale era also fundamentally changed the relationship between natural gas and oil prices. Before 2009, the two commodities tracked each other fairly closely on an energy-equivalent basis. After 2009, they diverged sharply: oil stayed expensive while gas remained cheap. That divergence created new industrial opportunities, including a boom in petrochemicals and fertilizer production that brought manufacturing investment back to the United States.
How US Prices Compare Globally
Henry Hub is the most widely cited benchmark, but it is not the only one. European and Asian buyers have historically paid far more for natural gas, partly because their markets were tied to long-term oil-indexed contracts and partly because they lacked the pipeline infrastructure to arbitrage regional price differences. The gap between US prices and international prices became so wide after the shale boom that it created the economic case for building liquefied natural gas export terminals along the US Gulf Coast. Cheniere Energy's Sabine Pass facility, which began exports in 2016, was a direct consequence of the price data you see in this chart.
Why This Data Still Matters Today
Natural gas now generates more electricity in the United States than coal and nuclear combined. It heats roughly half of American homes. It is the primary feedstock for ammonia-based fertilizers that underpin global food production. When prices move, the effects ripple through electricity bills, grocery prices, and industrial competitiveness. The 2022 surge, driven by the war in Ukraine and the scramble by European buyers to replace Russian pipeline gas, pushed Henry Hub prices back above $8 for the first time since 2008. It was a brief but sharp reminder that the low-price era of the early 2010s was not guaranteed to last forever.
Understanding these price cycles is not just an academic exercise. Utilities make thirty-year infrastructure decisions based on gas price expectations. Farmers lock in input costs based on fertilizer markets tied to gas. Policymakers weighing carbon taxes or renewable energy mandates need to know what the counterfactual fossil fuel price looks like. The historical record in this dataset, stretching back to 1997, provides the clearest available picture of how volatile and consequential this single commodity has been. You can explore the full dataset, download the underlying data, and embed these charts in your own projects at https://datahub.io/core/natural-gas.