The Other Energy Shock: Why the Iran War Is Coming for America’s Electricity & Grocery Bills

The implications for oil and gasoline prices have dominated the headlines surrounding the conflict in the Middle East. Natural gas has received far less attention from the general media. However, those who closely follow the world’s energy and commodity chemicals markets will appreciate that this conflict may have an even greater and longer-lasting impact on the global natural gas market than on the oil market. The heavy damage caused to two Qatari LNG liquefaction trains by Iran could end up negatively affecting what America pays for electricity and food long after the current conflict ends, and in a manner that may be more difficult to mitigate than will be the case with oil.

The scale of the damage is now clear. On March 18, 2026, Iranian missiles struck Qatar’s Ras Laffan Industrial City. This facility is home to the world’s largest LNG export facility. The following day, QatarEnergy CEO Saad al-Kaabi confirmed that LNG trains S4 and S6, (both partially owned by ExxonMobil), along with one of Qatar’s two gas-to-liquids facilities, had been damaged. The damage amounts to 17% of Qatar’s total LNG export capacity or ~12.8 million tons per year. Repairs to bring this capacity back online are expected to take anywhere from three to five years and this attack has already seen Qatar declare force majeure on long-term LNG contracts supplying Italy, Belgium, South Korea, and China. 

The significant damage to trains S4 and S6 followed the earlier shutdown of production at Ras Laffan by Qatar, which occurred following Iranian drone strikes targeting the facility in the early days of the conflict. At that point, satellite analysis suggested limited physical damage, and the shutdown appeared largely precautionary. However, the March 18 strikes have changed the picture entirely. What was a temporary supply disruption is now a structural reduction in global natural gas supply that will persist for years, regardless of when or how this conflict ends.

The impacts of this on the markets are already being felt. By March 23, European benchmark gas prices had doubled from pre-conflict levels. With Qatar entirely offline, global LNG supply has contracted by roughly 20%, and global gas supply disruption already exceeds that following Russia’s invasion of Ukraine, with ~140 billion cubic meters per year of supply lost, compared with 75 billion during the 2022 crisis. 

This piece explains why this matters for two things that every American consumer deals with every day: their electricity bills and their grocery costs. Though many don’t realize it, these core household expenses are highly sensitive to natural gas prices. And American natural gas prices are now much more closely linked to global gas prices than ever before.

The Price of Natural Gas Sets the Price of Power

People often assume that their electricity price reflects the blended cost of all the power plants on the grid. It does not. In most U.S. power markets, electricity prices are set via marginal pricing. What that means is that the cost of the last unit of electricity that had to be generated to meet demand in any given hour is the cost of all the power generated that hour. In most hours, across most of the country, that last unit comes from a natural gas-fired power plant.

The EIA stated this explicitly in early 2026: natural gas prices ​“set the marginal price of electricity during most hours in most regional markets.” Gas-fired generation accounts for more than 40% of U.S. electricity production, but critically, it sets the marginal price for much more of the overall production. The result is pervasive structural coupling between gas and electricity prices across most regions of the country. When gas prices rise, wholesale electricity prices rise almost in lockstep. Now, for consumers, it can take some time for higher costs to flow through to retail bills, sometimes within weeks, sometimes over months, but they always flow through.

How Global Gas Prices Meet American Gas Prices – The LNG Netback

If the United States is the world’s largest natural gas producer and largest LNG exporter, why should the destruction of Qatari infrastructure affect what Americans pay?

The answer is what is known as the LNG netback. The netback is the price gas fetches in a destination market, such as Europe or Asia, minus the costs incurred to get it there: liquefaction, shipping, and regasification. When international gas prices spike, the netback to the U.S. Gulf Coast widens dramatically, creating powerful incentives for exporters to maximize cargoes from American terminals. Naturally, this tightens domestic supply, and ultimately, this pushes domestic prices upward.

The EIA’s March 10 forecast argued that U.S. gas prices would be ​“relatively unaffected” because US LNG export terminals were already running near capacity. That forecast was published nine days before the Iranian missiles destroyed trains S4 and S6 at Ras Laffan, and, as such, it does not reflect the new reality of a global gas market whose supply/​demand equilibrium has been structurally dislocated.

Four things have changed that undermine the EIA’s forecast.

First, the damage to trains S4 and S6 is structural, not temporary. The global LNG market has lost 12.8 million tons per year of supply for at least the next three years. European and Asian buyers whose long-term Qatari contracts are now under force majeure will need replacement cargoes. The U.S. Gulf Coast is the obvious marginal supplier. The American Gas Association acknowledged as much in its March 5 market report, noting that the Qatar shutdown has reinforced the U.S. role as ​“a critical marginal supplier to both Europe and Asia.”

Second, netbacks transmit price signals without requiring additional physical exports. When European benchmarks double, as they have since February 28, every existing U.S. cargo becomes far more valuable. Offtakers with portfolio flexibility will look to maximize Gulf Coast liftings. Companies with uncontracted volumes, such as Venture Global, will be able to command higher global spot prices. This will tighten the economics of domestic gas procurement even before a single additional molecule leaves the country.

Third, U.S. LNG export capacity is growing into the crisis. Golden Pass LNG is coming online. Plaquemines LNG and Corpus Christi Stage 3 are ramping. Venture Global sanctioned the second phase of CP2 in March 2026. Each new train that comes online during record-high international prices will create the incremental export pull and upward pressure on local prices.

Finally, LNG exports were already the fastest-growing source of U.S. gas demand before the war. They accounted for more than 14% of domestic consumption in 2025. That is more demand than from either the residential or commercial sectors. Chatham House has projected that U.S. LNG exports will grow 50% between 2024 and 2027. The Iranian conflict is accelerating and strengthening a coupling between US domestic and global natural gas prices that was already well underway, and that coupling is not going to disappear when the shooting stops.

The 2022 Preview and Why This Time it Could Be Worse

A recent example of the coupling of US prices to global benchmarks occurred after Russia’s invasion of Ukraine. Then, European gas prices surged, and in response, U.S. LNG exporters redirected cargoes to that market. Henry Hub pricing nearly doubled from $4.50 in early 2022 to $8.81 by August. The Center for American Progress documented that average U.S. electricity prices jumped 13% over the same period. The critical lesson from the Ukrainian crisis is that the impact on domestic gas prices was delayed. European prices spiked immediately. Henry Hub followed for months. The same pattern may be unfolding now. As of March 23, 2026, Henry Hub was trading at roughly $3/​MMBtu, up only modestly from pre-war levels, while European and Asian benchmarks have surged 50 – 100%. The gap is wide and the question is whether it closes. Certainly, savvy LNG traders will be trying to close it.

There are reasons to think the eventual impact could be larger this time. In 2022, U.S. LNG export capacity average was approximately 11 – 12 Bcf/​d. Today, it is on track to reach 19 Bcf/​d, with more coming online. The pipeline connecting domestic prices to global markets is significantly wider. Moreover, the 2022 shock was driven by the loss of Russian pipeline gas, which U.S. LNG was never going to fully replace. This shock involves the structural loss of Qatari LNG cargoes, which will require direct replacement from other exporters. U.S. Gulf Coast terminals are the natural candidate.

Natural Gas to Your Kitchen Table – The Fertilizer Linkage

The scale of coupling between the global natural gas market and US electricity pricing is one of the key non-oil-related economic vectors through which the American household might feel economic pain from the Iranian conflict. The second is the role natural gas plays in fertilizer, as this may prove even more consequential for household budgets.

Modern agriculture is built on a synthetic nitrogen fertilizer foundation. It is central to realizing modern crop yields, and is manufactured from natural gas via the Haber-Bosch process. Approximately one-third of globally traded nitrogen fertilizer must pass through the Strait of Hormuz, and nearly 45% of global urea shipments originate from Persian Gulf facilities. Qatar alone accounts for roughly 11% of global urea exports. When natural gas prices rise and Gulf export routes close simultaneously, the impact on the global fertilizer supply is immediate and severe.

The price dynamics since the conflict began serve to reinforce this point. Urea prices at the port of New Orleans surged from $457 per ton on February 28 to $683 per ton by March 6 — a roughly 50% increase in under a week. Phosphate prices jumped approximately $30 per ton over the same period. Anhydrous ammonia and UAN prices also rose. Global fertilizer markets were already tight before the conflict, with China restricting exports to ensure domestic supply and European producers cutting output due to high energy costs.

The timing is critical. Northern Hemisphere farmers are entering the spring planting season. If fertilizer supplies do not reach the Corn Belt in time, there is the potential that farmers may shift acreage from corn to soybeans, which would tighten grain supplies later in the year. India, which sources more than 40% of its urea and phosphatic fertilizer imports from the Middle East, faces acute exposure, and unlike oil, there is no strategic fertilizer reserve to release. 

The coupling dynamics here are straightforward. Higher natural gas prices raise the cost of manufacturing nitrogen fertilizer. Disrupted Gulf shipping routes reduce the physical supply of finished fertilizer. Both forces hit simultaneously. The result flows through to crop input costs, which flow through to food prices at the grocery store with a lag of months, arriving just as this year’s crops are planted and harvested. The American Farm Bureau Federation warned the administration in a March letter that the U.S. ​“risks a shortfall in crops” and that production shocks could ​“contribute to inflationary pressures across the U.S. economy.” For American families already contending with elevated grocery costs, this will be another blow, and one likely to have a long tail.

Who Gets Hit Hardest

US electricity prices were already rising before this conflict began. The EIA projected wholesale power prices averaging $51/​MWh in 2026, up 8.5% from 2025. Retail prices rose nearly 7% nationally in 2025, double the rate of inflation. In PJM, the largest coordinated US power market serving 65 million people across 13 states, the 2024 capacity auction saw capacity pricing surge 833%, driven by expected growth in data center demand. Those higher costs are already hitting customers’ bills. A sustained increase in natural gas prices would only compound price pressure.

Regional exposure to these dynamics will be uneven. New England and New York customers who are heavily dependent on gas-fired generation and are constrained by limited pipeline capacity from Appalachian fields are perennially the most vulnerable. The ERCOT system, which operates with thin reserve margins and is absorbing rapid growth in data center and industrial loads, is another region where higher gas prices will translate directly into retail electricity price increases. Across the country, utilities that did not fully hedge their 2026 fuel costs could face margin compression that might ultimately be passed to ratepayers. 

The burden, as always, will fall disproportionately. Rural America is most exposed. Farmers face a squeeze from both sides: fertilizer input costs surging 40% or more, while crop prices remain uncertain. If nitrogen costs force a shift from corn to soybeans, as analysts have warned, farmers will be moving into a crop where their largest historic export market, China, has been steadily diversifying toward Brazilian supply. Rural households and small businesses, already more dependent on propane and diesel, have no hedge against a $100-plus barrel of oil. The average family cannot hedge electricity costs or fertilizer input prices. Small businesses cannot sign long-term power purchase agreements. They receive a bill, and they must pay it.

The Vulnerability This Reveals

Let’s step back and trace the chain. Iranian missiles significantly damage Qatari LNG trains. Global LNG spot prices double. The netback to the U.S. Gulf Coast widens. Henry Hub rises, albeit over the course of months. Gas-fired power plants bid higher into wholesale electricity markets. Retail electricity bills increase over the course of months. Simultaneously, nitrogen fertilizer supply contracts and input costs surge, with grocery prices likely to follow.

Every link in this chain exists because natural gas has become the dominant fuel in American power generation and a critical feedstock for American agriculture. That dominance has come about for good reasons: natural gas is flexible, it is efficient, and it was cheap for years. The shale revolution made it the rational choice for utilities retiring coal fleets. But dominance is not the same as resilience.

When a single fuel sets the marginal price of electricity in most hours across most markets, the power system becomes a vector for that fuel’s price volatility. As that fuel becomes increasingly priced in global markets through an expanding LNG export infrastructure, the insulation that domestic production once provided erodes with every new terminal.

This is where the debate around renewables and other alternative sources of generation is important. Every kilowatt-hour generated by a technology not linked to globally traded commodities like wind, solar, nuclear, hydro, or geothermal is a kilowatt-hour of energy that is insulated from this chain. Those electrons are indifferent to whether Qatar is exporting LNG or whether European gas futures are at €30 or €60. Their fuel cost is near zero and the cost of that power is locked in at construction for the life of the asset. The International Renewable Energy Agency reported in 2025 that more than 91% of new renewable projects globally were cost-competitive with fossil fuel alternatives at pre-crisis gas prices. At current levels, the competitiveness of these sources is stronger still. 

The Response This Unfolding Energy Crisis Demands

To be crystal clear, I am not arguing against the extensive use of natural gas. Gas-fired generation provides indispensable flexibility and reliability to the American power system and the broader economy. American gas production is a strategic asset of enormous value. Domestic producers and LNG exporters play a critical role in the economy and in allied energy security. Indeed, they are power levers for balancing trade and exerting geopolitical influence. 

What I am asserting, though, is that the damage done to trains S4 and S6 at Ras Laffan, and the broader devastation of Gulf energy infrastructure, should serve as a clarifying moment. These events highlight how risk can become concentrated and how it can collide with geopolitical reality. The risk is not theoretical. It operates through identifiable market structures, including netbacks, marginal pricing, and the fertilizer supply chain. 

Recent US energy policy has moved toward fossil fuels and away from clean energy. Tax credits for renewables have been cut, offshore wind permitting has been frozen, and new barriers to the development of renewables on federal lands have been put in place. On March 23, 2026, while European gas prices hit a 90% increase compared to pre-conflict levels and the IEA was calling this the greatest threat to global energy security in history, the Department of the Interior announced it would pay $928 million of taxpayer money to TotalEnergies to cancel its offshore wind leases off New York and North Carolina. The company pledged to redirect the funds into LNG export infrastructure in Texas. Put simply, the government paid nearly $1 billion to cancel over 4 gigawatts of fuel-free generation capacity and redirect it into the very LNG export infrastructure that is coupling American gas prices to the global volatility described in this article. This crisis playing out right now demands that harder questions be answered. Is it prudent to put in place policy focused on building an electricity system in which the dominant fuel is increasingly priced on global markets and heavily exposed to geopolitical disruption? Perhaps instead we ought to seek a better balance between the benefits that fuels like natural gas provide and the risks that a dependence on them entails. Perhaps we should proactively recognize that our energy system would benefit from including resources that entail few such risks?

The most resilient energy systems are the most diversified. The United States built the LNG export infrastructure that made it the dominant player in global gas markets. That was a strategic achievement. But true energy dominance is not just about being the biggest producer. It is about building a system that is dominant, flexible, and resilient. A system that gives America more power and leverage globally while protecting American consumers and our economic competitiveness at home. An electricity grid powered by a balanced portfolio of gas, nuclear, wind, solar, hydro, geothermal, and storage would deliver that: less volatility, less exposure to foreign supply shocks, and lower costs for consumers over time. Every fuel-free megawatt reduces the system’s sensitivity to the marginal gas molecule and thereby reduces the ability of a conflict 7,000 miles away to reach your electricity bill and your grocery receipt. That is not a concession to the other side of the political aisle. It is the America First energy strategy.

The Iran conflict certainly did not create America’s dependence on a single fuel for electricity pricing or on a single feedstock for fertilizer. But it is and will continue to expose the costs of such a dependency. The impacts on electricity markets, on fertilizer prices, and ultimately at the dinner table will become difficult to ignore. Policymakers should reflect on this moment and look to put in place a more secure, resilient, and cost-effective American energy system.