Energy Chokepoint Risk: Hormuz vs Malacca vs Bab el-Mandeb

The Strait of Malacca carried more petroleum and liquids than Hormuz in the first half of 2025. Hormuz may still be harder to replace.

That apparent contradiction gets to the heart of energy chokepoint risk. A strait’s importance isn’t determined by barrels per day alone. The more useful question is operational:

If this route closes tomorrow, can the specific cargo still reach the buyer within the required time and at an acceptable cost?

For Gulf crude and LNG, the answer is often worse around Hormuz than around Malacca. Malacca carries more traffic and sees frequent low-level security incidents, but its flows come from a broader range of suppliers and serve multiple Asian markets. Hormuz concentrates exports from Gulf producers, while LNG buyers face tight constraints on liquefaction, ships, terminals and replacement supply.

Bab el-Mandeb creates a different problem: ships can often avoid the danger zone, but the longer route around the Cape of Good Hope can sharply increase freight, insurance and delivery times.

Volume is only the starting point

EIA estimates for the first half of 2025 put petroleum and liquids flows through the main corridors at the following levels:

These are flow estimates, not counts of unique cargoes or measures of disruption severity. On this basis, Malacca carried roughly 11% more petroleum and liquids than Hormuz. Yet much of Malacca’s traffic is transit trade connecting several producers with several destinations. Hormuz links a concentrated export base to buyers that may have few immediate alternatives.

That difference is best described as replacement exposure.

A useful screening model is:

Risk = cargo dependence × substitution difficulty × disruption duration × infrastructure concentration

Those variables need to be weighted for the cargo and market being assessed. The expression is a decision framework, not a predictive equation. It isn’t additive, and it won’t generate reliable probabilities or loss estimates without calibrated historical data.

Hormuz: the difficult case for Gulf energy

For crude oil, Hormuz has substitutes—but not enough to replace every barrel quickly.

Some Gulf exporters can use bypass pipelines or terminals outside the strait. Saudi Arabia has Red Sea export capacity, and the United Arab Emirates can load crude at Fujairah. Strategic inventories, longer tanker routes and refinery-grade substitution can also soften the shock.

The constraint is spare capacity. An alternative pipeline on a map doesn’t mean it can absorb several million additional barrels per day. Export terminals need available berths and storage, tankers must be positioned, and the receiving refinery must be able to process the substitute grade.

LNG is less flexible still. A Qatar-to-Asia cargo depends on a complete chain:

1. Gas production and liquefaction capacity
2. An available LNG carrier
3. A safe maritime route
4. A receiving terminal and regasification slot
5. Sufficient downstream inventory or replacement supply

Changing the vessel’s route addresses only one part of that chain.

EIA estimates put global LNG trade at about 56.3 billion cubic feet per day in 2025, with the United States, Qatar and Australia accounting for roughly 63% of exports. That is a diversified supply base by comparison with a single producer, but it doesn’t mean replacement cargoes are immediately available. Other exporters may be fully committed, carriers may be scarce, and an affected buyer may lack spare regasification capacity.

For crude, a 30-day disruption may be manageable if inventories and alternative infrastructure are available. For LNG, the same period can become a physical supply problem rather than merely a freight problem.

Malacca: more traffic, broader options

The Malacca and Singapore straits form one of the world’s busiest energy corridors. Their exposure comes from traffic density, Asian demand and the limited ability to reroute large numbers of vessels without creating new bottlenecks.

Possible alternatives include the Sunda Strait, the Lombok-Makassar route and longer voyages around Indonesia. Buyers can also seek different suppliers or draw down storage. None is a perfect substitute. Rerouting adds sailing time and fuel consumption, and a fleet-wide diversion can consume tanker capacity even if the alternative sea lanes remain open.

Security data needs careful interpretation. ReCAAP’s 2025 reporting recorded 132 incidents in Asia, including 108 in the Straits of Malacca and Singapore. That is a high incident count, but many cases involved theft, unauthorized boarding or stolen stores—not attacks capable of halting regional energy trade.

Incident frequency and strategic severity are different measures. A corridor can experience many low-level crimes while presenting less systemic supply risk than a single conflict-driven closure.

Bab el-Mandeb: when the route stays open but stops making sense

Bab el-Mandeb connects the Red Sea with the Gulf of Aden and, through Suez, the Mediterranean. Its petroleum and liquids flow is much smaller than Hormuz or Malacca, but its commercial influence extends through the entire Suez system.

When operators avoid the Red Sea, vessels may sail around the Cape of Good Hope. Depending on the origin and destination, that can add thousands of nautical miles and days or weeks to a voyage. The costs include:

• Higher bunker consumption
• Fewer effective vessel-days
• Increased war-risk insurance
• Schedule unreliability
• Port congestion and equipment imbalance
• Higher working-capital and inventory costs

This is a soft closure: the waterway remains physically navigable, but insurers, crews and shipowners decide that the normal route is no longer commercially acceptable.

Crude can sometimes absorb the extra voyage if prices rise enough. A refined-product cargo headed to a low-inventory market may not. LNG, LPG and other time-sensitive cargoes face their own constraints around vessel availability and terminal scheduling.

A 30-day Hormuz disruption: LNG versus crude

Consider two shipments affected by the same 30-day disruption.

Qatar-to-Asia LNG cargo

A Japanese or South Korean buyer may have several options: draw down inventory, buy spot LNG, seek cargoes from the United States or Australia, or ask another supplier to divert a scheduled shipment.

The options are real but narrow. Atlantic cargoes may require longer voyages and available LNG carriers. A replacement supplier may have no uncommitted production. The buyer’s terminal may have limited spare slots, and the cargo may arrive after the immediate demand peak. If storage cover is only 10 to 15 days, the buyer must begin competing for replacement volumes before the disruption is halfway through.

A different route for a Qatari ship cannot solve a shortage of Qatari export capacity or a lack of receiving capacity at the destination. The cargo is geographically reroutable only if the entire supply chain remains available.

Gulf crude shipment

A refinery receiving Gulf crude may have more tools. It can draw on inventories, buy a different grade, source barrels from West Africa or the Americas, use a non-Hormuz export route where capacity exists, or accept a longer voyage.

Those choices still carry costs. The replacement crude may yield less product, require blending or alter refinery margins. Pipeline and terminal capacity may already be committed. But compared with LNG, the crude market generally offers more ways to assemble a workable substitute over 30 days.

The practical conclusion is not that crude is safe and LNG is fragile. It is that the same disruption produces different failure points. LNG is more likely to encounter a hard capacity constraint; crude is more likely to encounter a price, quality or logistics penalty.

A practical three-layer assessment

1. Define the cargo and dependency

Start with the origin-destination pair, not the map. Separate crude, refined products, LNG and LPG. Record supplier concentration, refinery compatibility, destination terminals and current inventory cover.

A barrel isn’t interchangeable if the refinery cannot process its grade. An LNG cargo isn’t useful if the buyer lacks a regasification slot.

2. Map physical and commercial substitutes

For each cargo, assess:

This is the difference between bypassability and substitutability. A vessel may avoid a strait while the buyer still cannot obtain an equivalent cargo.

3. Monitor behavior and cost signals

AIS data can show route deviations, speed changes, destination switches, anchorage queues and unusual transponder gaps. Satellite imagery can help confirm terminal congestion, berth use and vessel clustering, particularly when AIS coverage is incomplete.

Neither source proves a supply disruption on its own. A stronger signal combines a broad route change with longer voyage times, altered port calls and rising freight or insurance costs.

Delivered cost = commodity price + freight + insurance + war-risk premium + delay cost + inventory cost

That final line is where many assessments go wrong. They identify an alternate strait or pipeline but ignore spare loading arms, storage tanks, LNG carriers, regasification slots and insurance capacity.

For disruptions lasting days, inventory and voyage delays usually dominate. Over weeks or months, spare pipelines, terminals and vessels become binding constraints. A structural disruption requires new suppliers, new infrastructure or reduced demand.

The most useful chokepoint assessment is therefore a substitution ledger. For each cargo, record what can replace it, through which infrastructure, at what cost and for how long. That answer is more actionable than any global ranking based on barrels alone.

Frequently Asked Questions

Which energy chokepoint is hardest to replace?

For Gulf LNG and some Gulf crude, Hormuz is generally the hardest to replace because supply and export infrastructure are concentrated. Malacca may be more consequential for certain Asian trade flows, while Bab el-Mandeb can impose the largest economic penalty when Cape rerouting disrupts schedules and raises insurance costs.

Can pipelines replace Strait of Hormuz oil?

Only partially. Bypass pipelines and alternative terminals can move selected volumes, but spare capacity, destination access and crude-grade compatibility limit their usefulness.

Can LNG shipments bypass Hormuz?

Some cargoes can be replaced by other suppliers or redirected through alternative commercial arrangements. A different sea route alone cannot solve a shortage of liquefaction, ships, regasification capacity or available export supply.

How should companies measure chokepoint risk?

Score each cargo against supplier concentration, route dependence, alternative infrastructure, voyage penalty, vessel availability, receiving capacity, inventory cover and insurance. Use AIS, satellite imagery, port calls, freight rates and war-risk premiums together; no single indicator is proof of a disruption.

Source note: Flow figures are EIA estimates for the first half of 2025. LNG trade and exporter shares are 2025 estimates reported by the EIA. Asian incident figures are from ReCAAP ISC’s 2025 reporting; incident counts indicate frequency, not equivalent security severity.