Overview of War in Iran Is Redrawing the Map for Natural Gas
This Odd Lots episode (Bloomberg) — hosts Joe Weisenthal and Tracy Alloway — interviews Bob Brackett (Managing Director & Senior Research Analyst, Bernstein Research) on how the escalating conflict in and around Iran is reshaping global natural gas and related commodity markets. The conversation covers immediate disruptions (Strait of Hormuz, damage to fields), the structure of the gas/LNG markets, implications for prices and supply chains (including fertilizer/sulfur, aluminium, zinc), and why natural gas behaves very differently from oil.
Guest & context
- Guest: Bob Brackett, Bernstein Research — veteran energy/commodities analyst covering oil & gas and metals/mining.
- Recorded March 17 (hosts note the situation may evolve).
- Triggering events discussed: strikes on the Shah (often transcribed as “Shaw”) gas field in the UAE and heightened risks to Gulf production and shipping via the Strait of Hormuz.
- Clarification: the big shared gas structure discussed is the North Field (Qatar) which geologically extends into Iranian territory.
Main themes and takeaways
- Natural gas ≠ one global market: unlike oil (where shipping cost is a small share of value), most of gas’s cost is movement (pipeline, liquefaction, shipping, regas). That makes gas a collection of regional markets with spot and contract spreads driven by distance and logistics.
- “Forgotten molecule”: U.S. Henry Hub gas has been unloved (around $3/MMBtu when recorded) despite structural demand drivers in the U.S. — Brackett argues it was an underappreciated long idea.
- No quick fix for LNG tightness: LNG liquefaction plants take ~4 years to build (vs. a few quarters for a shale well). There is little spare global liquefaction capacity; shortfalls cause sustained tightness and price pressure.
- Infrastructure vs. shipping chokepoint risk: there are two separate disruption risks — immediate shipping (Strait of Hormuz) and damage to production/liquefaction infrastructure (which can create longer, multi-month/quarter effects).
- Energy substitution and knock-on effects: tight gas/LNG can push buyers to burn coal or fuel oil (electricity needs often trump marginal fuel cost), affecting coal/thermal markets and increasing emissions and fertilizer availability concerns.
- Commodities beyond gas matter: Sulfur/sulfuric acid (fertilizer inputs), aluminium and zinc (energy-intensive smelters in the Gulf region) can be impacted by Gulf energy disruptions.
Key data, unit conversions & quick reference numbers
- Global seaborne LNG ≈ 500 million tonnes per annum (units vary in industry: cargoes often measured in Bcf on the seller side, tons on the vessel side).
- Typical LNG vessel cargoes: medium ≈ 4 Bcf; Q‑Max ≈ 6 Bcf.
- 1 Tcf ≈ ~250 LNG cargoes (order‑of‑magnitude used by Brackett).
- A strong Haynesville/Marcellus well might produce ~20 Bcf over life (~4–5 LNG cargoes).
- U.S. gas supply-demand ≈ 120 Bcf/day; LNG exports have risen from ~10% of U.S. gas demand to nearly ~20% (a rapidly growing demand wedge).
- Typical costs quoted (order of magnitude): moving gas to Henry Hub < $1; liquefaction ≈ $2.5; shipping/regas add another ~$1–1.5 — so movement/liquefaction/shipping make up most of seaborne gas cost.
- Capital intensity: liquefaction capacity costs roughly $1,000/ton of nameplate capacity. Regas terminals are ~1/10th the cost (so there are more regas options than liquefaction options).
Notable insights & quotes
- “The forgotten molecule” — Henry Hub gas was unloved at the time, presenting an overlooked opportunity.
- “With gas, it’s all a game of distance and markets” — movement costs dominate gas pricing, unlike oil.
- “There is no spare capacity in LNG” — immediate shocks can’t be quickly remediated by constructed supply.
- Sulfur: despite headlines, sulfur as an element is abundant (fifth most abundant in the crust); shortages are more about processing and sulfuric acid availability (important for fertilizers and some industrial processes).
- Smelters (aluminium, zinc) are energy‑sensitive: Gulf smelters running off local gas can amplify regional impacts.
What to watch next (actionable signals)
- Discrete infrastructure news: outages at major Gulf gas fields (e.g., Shah) and damage to liquefaction terminals — these drive multi‑month supply impacts.
- Strait of Hormuz status — shipping chokepoint reopening/closure will affect short‑term cargo flows and insurance/shipping costs.
- Henry Hub price moves & U.S. LNG loading rates — rising U.S. exports reduce domestic surplus but haven’t yet permanently re‑priced U.S. gas (as of recording).
- European benchmarks (TTF) and JKM (Asia) spreads — watch how Qatar’s export strategy and ability to redirect cargoes links Pacific/Atlantic LNG prices.
- Coal and fuel‑oil prices — increases signal substitution away from LNG and stress on electricity markets.
- Fertilizer / sulfuric acid supply and prices — risk to agricultural inputs (urea ammonium sulfate, etc.) with knock‑on food security implications.
- New liquefaction projects (e.g., Golden Pass startup) and timelines — monitor nameplate additions vs. demand growth.
Broader implications & context
- Structural shift toward a more correlated seaborne gas market: rising LNG volumes (Qatar, U.S., Australia) are increasing interconnection between regional prices, but the law of one global gas price is still weak because movement costs remain high.
- Energy security & deglobalization trends: the past six years (COVID, trade tensions, Russia–Ukraine, now Iran) have accelerated thinking about on‑shoring and redundant capacity; building new regional processing/smelting/fuel infrastructure is capital‑intensive and inflationary if pursued at scale.
- Policy & politics: domestic policy changes (tariffs, permitting) have had limited immediate effect on production; geopolitical events can be a de facto “pro‑oil price” policy by tightening supply.
Quick glossary
- Henry Hub: U.S. natural gas benchmark (price quoted in $/MMBtu).
- Bcf (billion cubic feet): common volume unit for gas and LNG cargo sizing.
- Tcf (trillion cubic feet): very large gas volumes (1 Tcf = 1,000 Bcf).
- JKM: benchmark LNG price for the Japan–Korea market (Asia).
- TTF / NBP: European gas price benchmarks.
- Liquefaction/regas: processes to convert gas to/from liquid for shipping.
Bottom line
- Natural gas markets are highly regional and logistics‑sensitive; the Iran‑Gulf conflict threatens both shipping and production, so effects can be fast (shipping shocks) and persistent (damaged fields/liquefaction capacity).
- There’s limited short‑term spare LNG liquefaction capacity; meaningful new supply requires multi‑year project timelines.
- Watch price signals (Henry Hub, TTF/JKM spreads), infrastructure outage news, substitution into coal/fuel oil, and fertilizer/sulfuric acid availability — these indicators will show whether the current disruption becomes a short blip or a longer structural shock.