Morgan Stanley sees coal demand rising on Middle East tensions By Investing.com

Seaborne thermal coal prices are rising as Middle East tensions around the Strait of Hormuz (handling ~20-30% of global seaborne crude) push Asian utilities to switch from spot LNG to coal. Morgan Stanley estimates Japan, Korea and Taiwan may need an extra 1.5-2.0 mt/month of thermal coal (an 8-10% increase in coal import demand), South Asia could add ~1.0-1.5 mt/month, and China could see incremental volumes equal to ~1.3% of effective thermal supply in extreme cases. Qatar supplies ~60% of South Asia’s LNG and ~15% of Northeast Asia’s, while Australia will tap reserves (36 days petrol, 29 days jet, 32 days diesel) with extended tensions risking diesel supply for coal mining — supporting further seaborne price upside and benefiting Chinese coal producers.

Analysis

Incremental thermal-coal demand driven by an LNG supply shock is a textbook demand shock for seaborne dry-bulk and thermal-coal pricing: tightness will manifest first in spot freight and prompt thermal coal cargoes, then in term coal premiums and port queueing. Expect a 4–8 week window where sellers with available tonnage and flexible port access capture outsized margin; that window determines whether miners can monetise the squeeze or whether logistics and diesel bottlenecks cap delivered volumes.

Second-order beneficiaries include dry-bulk owners with Panamax/Capesize flexibility and coastal transship operators who can arbitrage regional coal flows; conversely, coal-import dependent utilities with constrained fuel storage or logistics are margin-squeezed and face higher credit stress if the outage persists beyond 2–3 months. Operational risk sits with miners in Australia/Indonesia where diesel or workforce disruptions (logistics or sanctions/insurance) can convert a price rally into lost sales and volatile realizations.

Catalysts and reversals are concentrated in three timebands: days–weeks (insurance/tanker-premium and spot freight spikes), 1–3 months (re-routing of global LNG cargoes and alternative supplier fills), and >3–6 months (structural contract re-pricing and regulatory pushback on coal imports). The consensus risk is underestimating mean reversion in freight and coal spot premia once alternative LNG cargoes are reallocated or diplomatic corridors stabilise; trade exposures should therefore be time-boxed and hedged for logistic tail-risk.

Key Decisions for Investors

• Overweight Peabody Energy (BTU) equity for a 3–6 month tactical trade: initiate a 4–6% portfolio position, target +35% on a sustained 10–20% rise in thermal coal seaborne prices, hard stop -20% if coal prices revert or if Australian diesel/logistics outages knock production offline.
• Buy Star Bulk (SBLK) or Golden Ocean (GOGL) for a 1–3 month freight play: 2–4% position to capture Panamax/Capesize day-rate spikes; objective +30–50% if Baltic dry-bulk indices spike, stop -25% if rates normalize within four weeks as LNG re-routing occurs.
• Long Cheniere Energy (LNG) modestly (2% position) as a hedge to coal upside over 3–6 months: LNG sellers benefit from higher spot/short-term cargo pricing and re-contracting, target +25% if JKM/TTF spreads widen, downside capped to -20% if spot liquidity and term protections blunt pass-through.
• Structured pair: Long BTU (3%) / Short a selected Asian utility exposure (size-limited) where possible — timeframe 3–6 months — to capture margin compression at end-users vs producer upside. Use options to cap losses (buy puts on the short leg) if direct shorting of specific utilities is operationally constrained.