Energy Chokepoint Bypass Capacity: Hormuz vs Malacca vs Red Sea

The hardest energy chokepoint to bypass isn’t necessarily the busiest one. Bypass capacity depends on how much traffic can move through alternative pipelines, straits, terminals and shipping lanes—and whether those options remain safe, legal and commercially workable during a crisis.

That distinction separates the Strait of Hormuz from the Strait of Malacca and the Red Sea. Malacca carries the largest reported flow in this comparison, but it has more physical substitutes. Hormuz carries less than its earlier baseline, yet its alternatives are narrower. The Red Sea presents a third case: cargo can usually go around the Cape of Good Hope, but only by consuming more fuel, vessels, time and insurance capacity.

Key takeaways

• Hormuz has the weakest bypass profile. The supplied EIA Q2 2026 estimate puts oil and petroleum-liquid flows at 4.9 million barrels per day, down from 21.6 million in Q4 2025. LNG fell from 10.5 to 0.8 Bcf per day.
• Malacca has the greatest volume exposure but more route substitution. Sunda and Lombok provide alternatives, although draft limits, congestion and extra distance reduce their practical value.
• The Red Sea is commercially bypassable, not disruption-free. A Cape diversion can add roughly 3,500–4,000 nautical miles and 10–14 sailing days to many Asia–Europe services.
• The useful metric is residual exposure: normal flow minus commercially usable bypass capacity.

A chokepoint is a system, not a line on a map

For procurement teams, shipowners and energy traders, “open” and “closed” are inadequate descriptions.

A route may be legally open but commercially unusable because war-risk insurance has surged, crews reject the voyage, naval advisories have changed or charterers have imposed restrictions. A pipeline may technically bypass a strait but lack spare capacity, storage, compatible crude handling or export-terminal throughput.

A practical assessment asks four questions:

1. Physical: Can the vessel or pipeline move the cargo?
2. Legal: Is the route accessible under maritime law and sanctions rules?
3. Security: Can operators accept the risk of attack, seizure, mines or interference?
4. Commercial: Will insurers, crews, ports, charterers and buyers support the movement?

The answer can differ for every cargo. A crude tanker, an LNG carrier and a container ship do not face the same constraints.

Three chokepoints, three kinds of exposure

The table uses the supplied Q2 2026 figures attributed to the U.S. Energy Information Administration. They should be treated as reported or modeled chokepoint estimates—not as continuous metering of every cargo. The sharp Hormuz changes are especially important to frame: they may reflect a disruption window, scenario or methodology change rather than a new normal baseline.

Hormuz stands out because of the size of the reported change. Oil and petroleum-liquid flows fell from 21.6 million barrels per day in Q4 2025 to 4.9 million in Q2 2026—about a 77% decline. LNG fell roughly 92%, from 10.5 Bcf per day to 0.8 Bcf per day.

Those numbers should not be read as a simple quarterly trend without checking the underlying EIA release and its measurement window. They do, however, illustrate the strategic problem. LNG is particularly difficult to reroute because it requires specialized vessels, liquefaction plants, regasification terminals and tightly scheduled receiving infrastructure. A crude cargo has more substitution options than a stranded LNG train.

Hormuz also has a limited pipeline safety valve. Saudi Arabia’s East–West Petroline can move roughly 5 million barrels per day toward Yanbu on the Red Sea, while the UAE’s Habshan–Fujairah pipeline has a design capacity of about 1.5 million barrels per day. Actual spare capacity varies with maintenance, domestic use, crude grade, terminal operations and security conditions. These systems serve Saudi and Emirati exports; they cannot provide a universal bypass for every Gulf producer. Qatar’s LNG exports, for example, remain highly dependent on maritime access.

Malacca carries more than three times the reported oil flow of Hormuz in this comparison. That creates substantial exposure for Asian refineries and trading networks, but the geography offers more choices. The Sunda Strait provides a western alternative, while Lombok is deeper and better suited to some larger vessels. Pipelines, stock draws and alternative suppliers can also absorb part of the disruption.

Those routes are not interchangeable. Sunda’s depth, traffic and navigational constraints can limit its use by large tankers. Lombok is more accommodating for deep-draft ships, but its eastern position adds distance. A VLCC carrying Persian Gulf crude to Japan, for instance, may use Lombok, but the route is longer and cannot replace Malacca for every origin-destination pair. A vessel bound from the Persian Gulf to Singapore has fewer useful geographic alternatives than one bound farther east.

Bab el-Mandeb is not the Suez Canal

The Red Sea requires a separate distinction.

Bab el-Mandeb is the access point into the Red Sea. If attacks or naval threats make that strait unacceptable, ships generally avoid the entire Suez route and sail around the Cape of Good Hope.

The Suez Canal is a canal transit constraint. A blockage, draft restriction or operational closure there affects ships that may still be able to reach the Red Sea safely. In either case, the commercial workaround is usually the Cape, but the trigger and operational response differ.

A Cape diversion can preserve the movement of cargo. It does not preserve the economics of the original voyage. The bill may include:

• additional fuel;
• 10–14 extra sailing days on many Asia–Europe services;
• more vessel days and tighter charter markets;
• higher insurance and freight rates;
• delayed inventory replenishment;
• additional emissions.

UNCTAD reported that rerouting increased global maritime ton-miles by 6% in 2024. That is a useful reminder that a route can remain physically available while its capacity becomes expensive and scarce.

The fleet effect is easy to miss. If a round trip takes two weeks longer, operators need more ships to maintain the same sailing frequency. A disruption can therefore tighten freight markets even when oil production and cargo demand have not changed.

Measure usable capacity, not infrastructure on a map

The practical metric is the amount of energy that can move through an alternative within a defined period.

Effective Bypass Ratio: usable alternative capacity ÷ normal chokepoint-dependent flow

Usable capacity should be discounted for:

• existing contracts and committed throughput;
• maintenance and technical limits;
• sanctions or export controls;
• incompatible crude grades;
• insufficient tank storage;
• restricted terminal loading;
• tanker availability;
• security exposure along the substitute route.

A related measure shows what remains vulnerable:

Residual Exposure: normal flow − commercially usable bypass capacity

That figure matters during a supply shock. A route carrying 16.6 million barrels per day may leave less stranded volume than a smaller route if its alternatives are genuinely available. Conversely, 4.9 million barrels per day through Hormuz can create an outsized shock if exporters lack usable outlets.

Distance must be modeled alongside capacity.

Added sailing time: (alternative distance − normal distance) ÷ average vessel speed

At 15 knots, an extra 3,600 nautical miles represents about 10 sailing days in one direction before port waiting, weather, bunkering or congestion are added.

A proposed resilience score

The following framework is illustrative, not a universal industry standard. An oil importer might increase the weight on source concentration and crude compatibility. An LNG buyer could give more weight to terminal flexibility and vessel availability. A shipowner might emphasize rerouting time and security, while an insurer could assign greater weight to incident frequency, war-risk pricing and legal uncertainty.

The score should be recalculated for the decision at hand rather than treated as a permanent ranking. A shipowner’s “resilient” route may be a poor choice for a refinery with no compatible crude slate, and an insurer’s risk view may differ from a trader’s view of acceptable delay.

What AIS and satellites can—and can’t—tell you

AIS is the starting point for measuring maritime exposure. Analysts can track vessel type, draught, speed, destination, port calls, loitering and route deviation. A sudden fall in tanker traffic may indicate avoidance, but it does not prove that cargo has disappeared. Ships may be waiting offshore, changing destinations or transmitting AIS selectively.

Satellite imagery helps close those gaps. Synthetic-aperture radar can detect vessels through clouds and at night, while optical imagery can show terminal activity, anchorage congestion and construction. The most reliable workflow combines AIS tracks, satellite detections, port-call data, pipeline and terminal constraints, freight rates, insurance signals and incident reports.

Confidence should be stated plainly. An AIS track confirmed by satellite is strong evidence. A vessel inferred only from port calls or third-party reporting is weaker. In contested waters, missing AIS data is not proof that no traffic is present.

Security datasets also need careful separation. Piracy, missile attacks, naval harassment, mine threats and GPS spoofing produce different operational responses. Combining them into one incident count can make a route look more or less dangerous than it is for a particular vessel type.

Geography still decides what can move

Resource geography and maritime security meet in places such as the South China Sea and Eastern Mediterranean. An offshore discovery becomes strategically useful only when a state can license it, protect drilling vessels, build export infrastructure, insure the project and reach customers.

A database should distinguish between legal claims, maritime delimitation, licensing authority, physical enforcement, commercial activity and international recognition. UNCLOS provides the basic reference points—a territorial sea up to 12 nautical miles, a contiguous zone up to 24 nautical miles and an exclusive economic zone generally extending to 200 nautical miles—but an EEZ does not erase navigation rights or settle every boundary dispute.

The same test applies to bypass infrastructure. Geography may provide a route, but pipelines, storage, terminals, law and insurance determine whether that route can actually carry energy during a crisis.

Frequently asked questions

Which is more vulnerable, Hormuz or Malacca?

Hormuz is generally more vulnerable on a bypass-capacity basis, particularly for LNG. Malacca carries more oil and LNG in absolute terms, but Sunda, Lombok, alternative suppliers and inventory adjustments provide more substitution.

How much oil can bypass Hormuz?

There is no single permanent number. Saudi Arabia’s East–West Petroline and the UAE’s Habshan–Fujairah pipeline provide meaningful outlets, but available capacity depends on maintenance, contracts, crude compatibility, storage, terminal throughput and security. Their existence does not mean all Gulf exports can be rerouted.

What is the main alternative to the Red Sea?

Routing around the Cape of Good Hope is the principal option. It keeps cargo moving but increases voyage time, fuel consumption, vessel demand, insurance costs and emissions.

How should operators use this analysis?

Set a disruption window—30 or 90 days—then estimate normal flow, usable bypass capacity, tanker availability, inventory and added freight. For a short event, prioritize cargo already at sea, floating storage and war-risk premiums. For a longer event, add refinery substitution, strategic reserves, terminal congestion and new chartering.

The best route is not the one that merely looks open on a map. It is the one with enough usable capacity, acceptable risk and workable economics for the specific cargo.