Gas Markets

How the Iran War Is Reshaping Natural Gas, LNG, and Power Prices

By • March 3, 2026 • 5 min read

The U.S.-Israel military campaign against Iran has turned the Strait of Hormuz from a geopolitical talking point into an active supply chokepoint. For energy markets, the consequences are already here: European gas prices have nearly doubled, global LNG supply has lost a fifth of its capacity overnight, and U.S. power markets face indirect but real exposure through natural gas generation costs.

Here is what happened, what the numbers look like, and what it means for natural gas, LNG, and electricity prices going forward.

The Trigger: Hormuz Closure and Qatar Production Halt

Iranian retaliation to U.S. and Israeli strikes has effectively shut down the Strait of Hormuz. Tanker traffic through the strait, which normally carries roughly 20% of the world’s daily oil consumption and a comparable share of global LNG trade, has dropped by approximately 70%. Over 150 vessels are currently anchored outside the strait, refusing to transit.

The immediate casualty was Qatar. Iranian drones struck the Ras Laffan Industrial City and Mesaieed Industrial City on March 1, prompting QatarEnergy to halt all LNG production. Ras Laffan alone accounts for roughly one-fifth of global LNG supply. Goldman Sachs estimates the shutdown removes approximately 19% of near-term global LNG capacity from the market.

On March 3, QatarEnergy extended the halt to downstream products, including urea, polymers, methanol, and aluminum. No restart timeline has been announced. Damage assessments are ongoing.

Natural Gas: Europe Takes the Hit First

European gas benchmarks absorbed the shock immediately. The Dutch Title Transfer Facility (TTF), Europe’s benchmark gas contract, surged 35% on March 2 alone, blowing past 60 euros per megawatt-hour. Intraday moves hit as high as 54%. On a weekly basis, TTF is up roughly 76%.

Goldman Sachs warned that a monthlong halt to Hormuz flows could push TTF toward 74 euros per MWh, the level that triggered demand destruction during the 2022 European energy crisis. If the disruption persists beyond a few weeks, Europe faces a real supply crunch heading into the shoulder season, with limited LNG alternatives available to replace Qatari volumes.

Asian spot LNG prices followed a similar trajectory, jumping nearly 39%. LNG tanker daily freight rates spiked more than 40% on March 2 as available shipping capacity tightened.

Henry Hub: Insulated, But Not Immune

U.S. domestic natural gas tells a different story, at least for now. Henry Hub spot prices are hovering around $3.04/MMBtu, up modestly from the $2.99 close on February 28. The NYMEX front-month contract is at $3.84, up 4.15%.

The U.S. is largely insulated from direct Hormuz disruption because American LNG production and consumption are self-contained within North America’s pipeline network. The Henry Hub benchmark reflects domestic supply-demand fundamentals, which remain relatively balanced as the heating season winds down.

But there are indirect channels that could push prices higher:

Power Markets: Follow the Fuel

Natural gas generates roughly 40% of U.S. electricity. In the Northeast, that number is even higher. NYISO Zone J (New York City / Con Edison territory) day-ahead prices are currently around $65/MWh for off-peak hours, which is unremarkable. But power prices are a lagging indicator of gas prices by nature of how day-ahead markets clear.

If Henry Hub moves meaningfully above $3.50 and stays there, wholesale power prices in gas-dependent regions like New England, New York, and PJM will follow. For every $1/MMBtu increase in natural gas, power prices in these regions typically rise $7-10/MWh, depending on heat rate and congestion.

The real risk isn’t today. It is what happens if this drags into summer, when air conditioning load pushes both gas demand and power demand simultaneously. A sustained gas price above $4.00 would start showing up on commercial and industrial electricity bills within one to two billing cycles.

LNG: A Market With No Spare Capacity

The core problem for global LNG is that there was no slack in the system before this happened. Global LNG demand has been growing steadily, new liquefaction capacity won’t come online in meaningful volumes until 2027-2028, and the market was already tight heading into 2026.

Removing 19% of global supply is not a marginal disruption. It is a structural shock. The only near-term relief valves are demand destruction (which has already started in price-sensitive Asian markets) and substitution toward pipeline gas where available (which largely benefits Russia’s remaining European pipeline customers).

For LNG buyers locked into long-term contracts with Qatari volumes, the question is force majeure. QatarEnergy has not declared it yet, but if the production halt extends beyond days into weeks, contract renegotiations and spot replacement purchases will add further upward pressure to global prices.

Scenarios to Watch

Short disruption (1-2 weeks): Qatar restarts, shipping resumes cautiously. TTF falls back to 45-50 EUR/MWh. Henry Hub stays under $3.50. Power markets see minimal lasting impact. This is the best case.

Extended disruption (1-3 months): Hormuz remains contested, Qatar production stays offline or at reduced capacity. TTF pushes toward 74 EUR/MWh (Goldman’s demand-destruction threshold). Henry Hub drifts to $3.75-4.25 as LNG export pull tightens domestic supply. U.S. power prices in the Northeast rise 10-15%. Summer looks expensive.

Prolonged conflict (3+ months): Full Hormuz blockade with mine deployment or military enforcement. Global LNG trade is fundamentally restructured around non-Gulf routes. TTF approaches 2022 crisis levels. Henry Hub could see $5+ if the injection season is disrupted. U.S. power prices follow in kind. This scenario would likely trigger recession fears in Europe and parts of Asia.

The Bottom Line

The U.S. is in a better position than almost any other major economy to weather this crisis. Domestic production is strong, pipeline infrastructure is mature, and the direct exposure to Hormuz is minimal. But “better positioned” does not mean “unaffected.” The global gas market is interconnected through LNG, and price signals travel fast.

For utilities, ESCOs, and commercial energy buyers, the action items are straightforward: review forward procurement positions, consider locking in near-term supply before the full price impact propagates, and watch Henry Hub front-month futures as the leading indicator of whether this stays a European problem or becomes an American one.

Lena Watts covers energy markets and regulatory developments for EnergyPulseDaily. The analysis above reflects publicly available data as of March 3, 2026.