Global LNG Prices Spike While Henry Hub Stays Low: U.S. Electricity Risk After Hormuz Closure
Current Answer
EIA reports global LNG prices rose sharply after the February 28 Strait of Hormuz closure, with TTF up 35% and JKM up 51% by the week ending April 24. U.S. Henry Hub, however, fell 9%, so domestic electricity risk remains a monitored pass-through risk, not a confirmed rate spike.
Impact on C&I End-Users
- →Wholesale Exposure: Facilities on index electricity products should watch whether the global LNG shock reaches domestic Henry Hub, regional basis, or gas-on-margin power prices. EIA's April 28 read does not show that U.S. gas spike yet.
- →Contract Renewals: Suppliers may still price geopolitical optionality into forward offers, but buyers should ask whether that premium is tied to actual U.S. gas/basis data or only broad international LNG headlines.
What Changed Since the Original February Alert
The February version of this analysis described a plausible LNG-contagion path. EIA's April 28 Today in Energy update now gives that path hard international price evidence, while also adding an important U.S. caveat: global LNG prices rose, but U.S. Henry Hub did not rise with them through late April.
EIA reported that no laden LNG vessels were known to have crossed the Strait of Hormuz between March 1 and April 24, affecting more than 10 Bcf/d of global LNG supplies. The commercial buyer question is now narrower and more useful: when does international LNG stress become U.S. domestic gas or electricity pass-through?
Mechanism 1: The Strait of Hormuz and the Qatari LNG Chokepoint
The immediate threat in this conflict is the potential disruption of shipping through the Strait of Hormuz or retaliatory strikes against Gulf energy infrastructure. While oil dominates the headlines, Qatar is one of the world’s top LNG exporters, and its shipments must pass through the Strait.
EIA now frames the affected supply as more than 10 Bcf/d, or about 20% of global LNG. By the week ending April 24, EIA reported TTF at $14.80/MMBtu and JKM at $16.02/MMBtu, up 35% and 51% respectively since the closure.
Mechanism 2: The U.S. LNG Export "Pull" Effect
Because the U.S. is a leading LNG exporter, domestic gas markets are more globally connected than they were a decade ago. But EIA's April 28 update shows the limit of that link: U.S. LNG terminals were already running near high utilization, so the U.S. could only replace a small share of the missing Qatari volumes in the near term.
That matters for U.S. buyers. EIA reported Henry Hub futures were down 9% since the week ending February 27 as winter demand faded and domestic storage remained ample. The current risk is not "global LNG is up, therefore U.S. power bills immediately spike." The current risk is "watch for the moment international LNG stress breaks through into U.S. gas, basis, or power forwards."
Mechanism 3: The Natural Gas "Clearing Price" in Power Markets
Why does a spike in natural gas matter for a hospital or data center running on electricity? Because natural gas is the primary fuel for U.S. electricity generation, accounting for roughly 40% of all utility-scale power produced.
More importantly, in most U.S. deregulated wholesale electricity markets, natural gas "on the margin" frequently sets the clearing price for power. If Henry Hub, Waha, Transco Zone 6, Algonquin, or other relevant basis points begin repricing, commercial electricity index products can respond quickly. If those domestic prices remain soft, the pass-through stays muted.
Regional Nuances in the U.S.
The severity of the price impact will vary significantly by geography based on generation mix and infrastructure:
High Monitoring Priority: ERCOT, PJM, ISO-NE, Florida
Regions with heavy gas-on-margin exposure, Gulf Coast gas links, or winter pipeline constraints remain the first places to monitor for pass-through. The key trigger is movement in domestic gas and basis prices, not international LNG alone.
Moderate Monitoring Priority: NYISO Zone J
Congested load centers like New York City, which face existing capacity shortfalls and rely heavily on in-basin gas generation, could experience direct price transmission during peak demand periods.
Lower But Not Zero: CAISO, Pacific Northwest
Regions with high penetrations of zero-fuel-cost renewables (solar/wind in California) or massive hydroelectric resources (Washington/Oregon) will be partially insulated from the natural gas price shocks, though they are not entirely immune to broader grid pricing trends during the evening ramp.
Actionable Takeaways for Energy Managers
For energy procurement managers and industrial operators, the immediate focus should be evidence-based monitoring rather than panic hedging.
If international LNG stress begins showing up in Henry Hub, regional gas basis, or gas-on-margin power forwards, C&I consumers on variable index rates should evaluate temporary fixed-price blocks. If U.S. gas remains soft, buyers should challenge broad geopolitical premiums that are not backed by domestic market data.
Operations with demand-response capability, dispatchable backup, thermal storage, or batteries should prepare peak-avoidance plans now. These are useful even if the LNG shock never fully reaches Henry Hub, because the same assets protect against summer scarcity, capacity-cost events, and local basis blowouts.
Source: EIA Today in Energy, EIA Open Data API, EIA Weekly Natural Gas Storage Report, and KilowattLogic procurement analysis.