Cross-Commodity Spillovers: Coal, Aluminum, Sulfur And Sulfuric Acid
Sources: 1 • Confidence: Medium • Updated: 2026-03-18 14:30
Key takeaways
- Aluminum is a key commodity to watch because the Middle East processes significant volumes and regional cheap-energy smelting exposure is being repriced.
- Oil and gas producers largely set budgets based on the oil price at the start of the year rather than on tariff impacts.
- An LNG facility typically takes about four years to build, and there is effectively no meaningful spare LNG export capacity.
- Iran struck the UAE’s Shah gas field and the field was on fire as of the recording date.
- There is no strong evidence that the rise in LNG exports from about 10% to 20% has meaningfully raised domestic Henry Hub prices so far.
Sections
Cross-Commodity Spillovers: Coal, Aluminum, Sulfur And Sulfuric Acid
- Aluminum is a key commodity to watch because the Middle East processes significant volumes and regional cheap-energy smelting exposure is being repriced.
- Copper smelters produce sulfur (and sulfuric acid) as a byproduct because many copper concentrates are sulfides that release sulfur during smelting.
- When LNG is scarce, buyers substitute toward thermal coal for power generation, and thermal coal prices had risen about 30% year-to-date in this context.
- The Shah sour-gas stream is about 25% H2S.
- Sulfur is generally abundant globally and not structurally scarce, with large visible stockpiles at sites like Kazakhstan’s Tengiz field.
- Because sulfuric acid is a saleable byproduct, smelters can treat it as a meaningful revenue stream when primary processing economics are weak.
Policy And Macro Constraints: Tariffs, Producer Budgeting, And Supply-Chain Duplication
- Oil and gas producers largely set budgets based on the oil price at the start of the year rather than on tariff impacts.
- Military escalation against Iran is a policy stance that supports higher oil prices.
- With oil prices around $60, U.S. shale output remained resilient and did not decline much, while OPEC added barrels amid tepid demand.
- U.S. energy has been somewhat exempt from tariffs, while tariffs on aluminum and steel exist and the threat of copper tariffs is distorting copper prices.
- There is a structural tension between a political desire for low gasoline prices and a pro-oil-industry stance because producers earn acceptable returns only at reasonably high oil prices, suggested mid-cycle around $75–$80.
- Improved permitting clarity may help at the margin, but drilling activity is primarily driven by expected returns rather than by permitting or tariff considerations.
Lng Market Structure: Pricing, Contracts, And Physical Bottlenecks
- An LNG facility typically takes about four years to build, and there is effectively no meaningful spare LNG export capacity.
- Global regasification capacity exceeds liquefaction capacity because regas terminals are far cheaper to build, which makes liquefaction the bottleneck and rations scarce LNG cargoes via price competition among buyers.
- Natural gas lacks a single global price because transportation and liquefaction/regasification costs dominate delivered cost more than for oil.
- Asian LNG contracts were historically often oil-indexed, while U.S. LNG introduced hub-linked pricing such as Henry Hub and increased spot/merchant arbitrage activity.
- Qatar, the U.S., and Australia are the three LNG “powerhouses”, and Qatar’s low-cost gas is effectively subsidized by condensate and typically sold via long-term contracts heavily into Asia.
- Increasing LNG trade and Qatar’s ability to serve both Atlantic and Pacific basins should link European and Asian seaborne gas prices more tightly over time.
Geopolitical Disruption Channels And Chokepoints
- Iran struck the UAE’s Shah gas field and the field was on fire as of the recording date.
- If conflict persists long enough to materially disrupt Qatar, roughly 20% of global LNG supply could be knocked out, requiring large-scale coal substitution or demand destruction.
- Disruption to gas markets depends on both shipping constraints through the Strait of Hormuz and the extent/duration of direct production-infrastructure damage.
- European gas prices were below post-Ukraine-invasion peaks partly because the market was in shoulder season and Europe had more non-Russian options than before.
- The Qatar North Field extends into Iranian territory, and Gulf LNG (except Oman) must transit west-to-east through the Strait of Hormuz.
U.S. Gas Dynamics: Associated Gas, Exports, And Supply Discipline
- There is no strong evidence that the rise in LNG exports from about 10% to 20% has meaningfully raised domestic Henry Hub prices so far.
- U.S. Henry Hub natural gas was around $3 per MCF and described as “unloved” despite multiple underlying U.S. demand drivers.
- U.S. LNG exports rose from roughly 10% of the U.S. gas supply-demand balance a few years ago to close to about 20% today, making exports the fastest-growing component of U.S. gas demand.
- Associated gas from shale oil drilling can keep U.S. gas supply flowing even when gas prices are low because it is effectively a byproduct of oil drilling.
- The Haynesville shale is showing greater supply discipline than before.
Watchlist
- Pakistan has roughly a month of natural-gas supply and is heavily dependent on gas from the region.
- Aluminum is a key commodity to watch because the Middle East processes significant volumes and regional cheap-energy smelting exposure is being repriced.
Unknowns
- Was the Shah gas field actually struck, what is the verified operational status (fire containment, production shut-ins), and how long will any outage persist?
- What are the actual constraints on LNG shipping through the Strait of Hormuz (insurance costs, routing changes, delays) versus direct upstream damage, and which channel dominates?
- What is Pakistan’s true gas import coverage and contingency plan (tender activity, ability to fuel-switch, fiscal capacity), and are there early signs of rationing?
- Is there, in fact, no meaningful spare global LNG export capacity, and what debottlenecking or utilization uplift is realistically available over the next 6–18 months?
- Is the anticipated 2026–2027 LNG glut still expected by major forecasters and market participants after incorporating conflict risk, delays, and outages?