Key Takeaways
- Total Hormuz bypass capacity: ~3.5 million b/d across all existing alternative routes, versus approximately 20 million b/d that normally transits the Strait
- Saudi East-West Pipeline (Petroline): 5 million b/d nameplate capacity but operating at roughly 2 million b/d — mothballed sections and maintenance backlogs limit throughput
- UAE Habshan-Fujairah Pipeline: 1.5 million b/d capacity, operating near full — the most functional bypass currently active
- Iraq’s IPSA pipeline: dormant — theoretical 1.65 million b/d capacity through Saudi Arabia to the Red Sea, but mothballed since the 1990 Gulf War and not operable without multi-year rehabilitation
- The infrastructure investment gap is a decade-long problem — upgrading Petroline to full capacity alone would cost $8–12 billion and take 3–5 years; a meaningful new bypass pipeline would cost $40–80 billion
Every time the Strait of Hormuz becomes a geopolitical flashpoint, the conversation immediately turns to alternative pipelines. Can Saudi Arabia and the UAE just route their oil around the Strait? The answer, examined in detail, is deeply sobering: existing bypass infrastructure can handle about 17.5% of normal Hormuz traffic. The other 82.5% has nowhere to go. This is not a short-term problem — it is a decade-long infrastructure deficit that represents one of the most significant and underappreciated vulnerabilities in global energy security.
For US investors, the infrastructure gap is also a long-dated investment thesis: whoever finances, builds, and operates expanded Gulf bypass capacity is looking at multi-decade, government-contracted cash flows in a strategically critical asset class. Understanding the current capacity picture — and what it would take to change it — is essential context for both the immediate supply crisis and the long-term energy infrastructure investment opportunity.
The Baseline: How Much Oil Flows Through Hormuz?
The Strait of Hormuz is, without exaggeration, the world’s most critical energy chokepoint. In 2025, approximately 20–21 million barrels per day transited Hormuz — roughly 20% of global petroleum liquids consumption. This includes crude oil from Saudi Arabia (approximately 6–7 million b/d exports), UAE (approximately 2.5–3 million b/d), Kuwait (approximately 2 million b/d), Iraq (approximately 3.5 million b/d), Iran (approximately 1.5–2 million b/d on sanctioned basis), and Qatar’s condensate and LNG-associated liquids.
The Strait itself is only 21 miles wide at its narrowest point, with navigable shipping channels of approximately 2 miles in each direction. The vulnerability is geometric: a relatively small number of mines, missile strikes on supertankers, or physical blockade operations could effectively close the world’s most important energy corridor. See our detailed analysis of Hormuz shipping disruption impacts for the supply chain mechanics.
Route 1: Saudi Arabia’s East-West Pipeline (Petroline) — The Biggest Disappointment
The Saudi East-West Crude Oil Pipeline — known as Petroline — is the most discussed Hormuz bypass and the biggest disappointment when examined in detail. Built in two phases in the 1980s specifically as a Hormuz contingency, it runs approximately 1,200 kilometers from Abqaiq (Saudi Arabia’s main oil processing hub in the Eastern Province) to the Red Sea terminal at Yanbu.
Nameplate capacity: 5 million barrels per day. Actual operating throughput in 2025–2026: approximately 2 million b/d, or 40% of nameplate. The gap between nameplate and actual capacity is the result of decades of underinvestment, deliberate mothballing of pump stations to reduce maintenance costs during periods of low Hormuz threat, and the diversion of domestic refinery capacity to Yanbu’s industrial complex which competes for pipeline throughput.
Saudi Aramco has stated that restoring Petroline to its full 5 million b/d capacity would require approximately $4–6 billion in investment and a timeframe of 18–36 months to recommission mothballed pump stations, upgrade metering systems, and repair sections that have deteriorated. Even if Aramco began the commissioning process on March 19, Petroline would not reach full capacity before mid-2027 at the earliest. Under an emergency crash program, incremental capacity of perhaps 500,000–800,000 b/d above the current 2 million could be available within 6–9 months. This is meaningful at the margin but does not solve the fundamental bypass shortfall.
The Red Sea terminal at Yanbu also has constraints. Super-tanker loading capacity at Yanbu is approximately 3.5 million b/d, meaning that even if Petroline were fully operational at 5 million b/d, the terminal could not export that volume without significant infrastructure expansion at the Red Sea end — another 12–24 month project. For context on Saudi Arabia’s broader infrastructure investment agenda, see our coverage of Vision 2030 progress in 2026.
Route 2: UAE’s Habshan-Fujairah Pipeline — The Most Functional Bypass
The Abu Dhabi Crude Oil Pipeline — running from the Habshan processing center in Abu Dhabi’s interior to the Port of Fujairah on the Gulf of Oman coast — is the most operationally viable Hormuz bypass currently in existence. Commissioned in 2012 specifically to provide Hormuz-independent export capability, it has a design capacity of 1.5 million barrels per day and runs approximately 400 kilometers.
Critically, Fujairah sits on the Arabian Sea side of the UAE’s coastline, entirely outside the Strait of Hormuz. Tankers loading at Fujairah do not transit Hormuz. As of March 2026, the pipeline is reportedly operating at approximately 1.3–1.4 million b/d — near its operational ceiling. ADNOC has been routing as much Abu Dhabi crude as possible through Fujairah since the conflict began, and the terminal has expanded its supertanker berth capacity over the past three years in anticipation of exactly this scenario.
Fujairah also serves as the world’s third-largest bunkering port and has significant oil storage capacity (~14 million barrels). The terminal’s infrastructure is modern and well-maintained — a deliberate strategic investment by Abu Dhabi precisely because Hormuz risk has always been central to UAE energy security planning. The UAE understands its geography better than most, which is why Habshan-Fujairah was built and why Hormuz bypass planning has been a long-term Abu Dhabi priority.
Route 3: Iraq’s IPSA Pipeline — The Dormant Giant
The Iraq-Saudi Arabia Pipeline (IPSA) is the most tantalizing bypass option on paper and the most useless in practice. Built in the 1980s during the Iran-Iraq War, IPSA runs approximately 1,000 kilometers from southern Iraq’s Basra oil fields through Saudi Arabia to the Red Sea terminal at Muajjiz, near Yanbu. Design capacity: 1.65 million barrels per day.
The reality: IPSA has been completely dormant since the 1990 Gulf War, when Saudi Arabia closed the pipeline in response to Iraq’s invasion of Kuwait. The infrastructure has not been maintained for over 35 years. Saudi Arabia repurposed the Saudi section of the pipeline for domestic natural gas distribution in 2001. Restoring IPSA to operational status would require not only massive physical rehabilitation — estimated at $15–25 billion — but also a bilateral agreement between Iraq and Saudi Arabia on transit fees, security guarantees, and operational control. The political complexity alone makes IPSA a 5–10 year project minimum, not a crisis response option.
Route 4: Oman’s Natural Bypass Advantage
Oman is not traditionally included in Hormuz bypass discussions because it does not require one — most of Oman’s crude production naturally exits via Arabian Sea ports that never touch the Strait. The Port of Mina al-Fahal (near Muscat) and the Port of Salalah handle Omani exports directly to open ocean. Oman produces approximately 1 million b/d, and this volume is entirely Hormuz-independent.
However, Oman cannot serve as a transit hub for Saudi or Kuwaiti crude without a new cross-country pipeline — a project that has been discussed for decades but never advanced beyond feasibility studies due to cost (estimated $20–35 billion) and the obvious political complexity of routing Iraqi or Saudi crude through Omani territory.
The Cape Route: Oil’s Last Resort Alternative
If Hormuz is closed and pipelines cannot absorb the volume, the only remaining option is the Cape of Good Hope route — sailing tankers around the southern tip of Africa instead of through the Suez Canal and Red Sea approach. This adds approximately 10–14 days of sailing time per voyage (each way), effectively tying up 25–30% more tanker capacity to deliver the same volume of oil.
The global supertanker fleet has a total capacity of approximately 600 million barrels of crude oil at any given time in transport. A 25–30% capacity reduction due to longer routing would translate to an effective reduction in global crude supply available at any moment — driving spot prices higher. This is part of why oil analysts are modeling Brent at $120–140 if Hormuz remains disrupted beyond 60 days. The Cape route is not a solution; it is an extremely expensive and supply-reducing workaround. See our Iran war economic cost analysis for modeling on sustained Hormuz closure.
The Math: An 82% Bottleneck
Adding up all viable bypass capacity as of March 2026:
- Saudi Petroline (current actual capacity): 2.0 million b/d
- UAE Habshan-Fujairah: 1.4 million b/d (near operational ceiling)
- Oman natural bypass (own production only, not transit): ~0.1 million b/d additional theoretical capacity
- IPSA: 0 b/d (dormant)
- Total functional bypass: ~3.5 million b/d
Against approximately 20 million b/d of normal Hormuz traffic, that is 17.5% bypass capability — or an 82.5% bottleneck. Even under an aggressive emergency scenario where Saudi Arabia brings Petroline to 3 million b/d within 9 months (adding 1 million b/d above current levels), total bypass capacity would reach 4.5 million b/d — still only 22.5% of normal Hormuz traffic. The math is brutal and does not change quickly.
What This Means for US Investors
The 82% Hormuz bottleneck is a structural, decade-long investment thesis — not just a crisis trade. The infrastructure gap will be filled eventually, and the capital required is staggering: full Petroline restoration ($4–6B), new Saudi Red Sea terminal expansion ($3–5B), potential new UAE pipeline capacity ($8–15B), and speculative new cross-Gulf projects could total $50–100 billion over a decade. The primary investment vehicle today is through energy infrastructure funds — Brookfield Infrastructure Partners (BIP), Kinder Morgan (KMI) has no direct Gulf exposure but benefits from US pipeline demand increases, and midstream MLP vehicles. The more direct play is through the oil price itself: the structural bypass deficit means that any future Hormuz tension event — regardless of how this one resolves — will reprice oil markets sharply, making long-dated energy exposure via options or commodity ETFs a portfolio hedge worth considering.
What Would It Actually Take to Solve the Bypass Problem?
To reduce Hormuz dependency from 82% to a manageable 40–50% would require building approximately 10 million b/d of new bypass capacity — an engineering and financial undertaking of historic scale. For context, the Trans-Alaskan Pipeline (800 miles, 2.1 million b/d capacity) cost approximately $8 billion to build in 1977 dollars — equivalent to roughly $40 billion today. A comparable Gulf bypass network would be multiple times larger, in more complex terrain, crossing sovereign borders, and requiring marine terminal infrastructure at both ends.
Realistic cost estimates from energy infrastructure analysts at Wood Mackenzie and IHS Markit put a meaningful Gulf bypass expansion at $80–120 billion over 10–15 years. This is precisely the kind of long-dated, government-backed infrastructure investment that sovereign wealth funds and infrastructure equity funds are structured to finance. The political will — driven by the current crisis — is now present in both Saudi Arabia and the UAE in a way it has not been since the 1980s. The current disruption may paradoxically be the event that finally catalyzes the investment the region should have made decades ago. For the broader implications for Gulf economic diversification, see our GCC countries analysis and the Gulf food prices and Hormuz crisis coverage.
Frequently Asked Questions
Why hasn’t Saudi Arabia already restored Petroline to its full 5 million b/d capacity?
Two reasons: cost and complacency. Restoring Petroline to full capacity costs $4–6 billion and requires sustained operational commitment. During periods of low Hormuz tension (most of the past 30 years), the investment was hard to justify economically. Additionally, Saudi Arabia’s domestic refinery expansion at Yanbu means some pipeline throughput competes with domestic processing rather than export — reducing the economic incentive to maximize export capacity through the Red Sea.
Could the UAE expand the Habshan-Fujairah pipeline capacity?
Yes, but not quickly. ADNOC has studied a second parallel pipeline (Habshan-Fujairah 2) with an additional 1.5 million b/d capacity. Estimated cost: $4–5 billion, construction time 3–4 years. The current crisis has almost certainly accelerated the decision timeline — a formal project announcement could come in Q2–Q3 2026. But the physical capacity addition is still years away from availability.
What would it cost to make the Gulf truly Hormuz-independent?
Full Hormuz independence — meaning the ability to export 100% of GCC production without transiting the Strait — would require approximately 16–17 million b/d of new pipeline capacity (current export volume minus existing bypass). At $10,000–15,000 per barrel-per-day of pipeline capacity (a standard industry metric), that represents $160–255 billion in pipeline investment alone, plus terminal and storage infrastructure. A realistic 20-year program to achieve 80% Hormuz independence would cost $80–120 billion. This is achievable but requires sustained political commitment across multiple governments.
Does Iraq have any Hormuz-independent export capacity?
Very limited. Iraq exports approximately 3.5 million b/d, almost entirely through the Basra Oil Terminal and Khor al-Amaya terminal in the Persian Gulf — both of which require Hormuz transit. Iraq’s Ceyhan export terminal via the Iraq-Turkey Pipeline (ITP) is the only Hormuz-independent Iraqi export route, but capacity is approximately 600,000–700,000 b/d and the pipeline has been plagued by attacks, maintenance issues, and transit disputes with Turkey. Iraq is arguably the most Hormuz-exposed major producer after Kuwait.
Why is the Cape of Good Hope route not a practical long-term solution?
Economics and vessel capacity. Adding 10–14 days each way to a supertanker voyage increases shipping costs from approximately $2–3/barrel to $6–9/barrel on major Asian routes. More importantly, it ties up tanker capacity — the same number of ships deliver significantly less oil per year when each voyage is 25–30% longer. With the global supertanker fleet already operating at high utilization, the Cape route is a bridge solution that worsens the supply shock rather than solving it.
