86% of crude imports come from Kuwait. 87% transit the Strait of Hormuz. Strategic reserves cover only ~20 days - a quarter of the IEA standard. Domestic production is falling 6% a year, and the country's largest refinery was purpose-built for a single crude grade. When Hormuz closed from March to June 2026, the entire energy-security architecture was exposed. By July 2026, Brent had fallen back to pre-war levels and domestic pump prices had reversed downward - but the structure that produced the shock hasn't changed. This is the technical anatomy of that machine - and why it's hard to fix in the short run.
Scope: This piece maps Vietnam's oil architecture across three layers - supply (domestic + imported), refining capacity (Nghi Son, Dung Quat), and the risk buffer (reserves, substitution scenarios). Figures are drawn from EIA Vietnam, IEA Oil Security, S&P Global Commodity Insights, MUFG Research (03/2026), Argus Media, Vietnam Customs (Tổng cục Hải quan), the Ministry of Industry and Trade, and APERC Update on Oil & Gas Security in Viet Nam (2024).
Note: The "20-day" reserve figure is an effective estimate (national reserves plus mandatory holdings at distribution enterprises) and fluctuates month to month. The 86% Kuwait share applies to imported crude oil, not total fuel demand - Vietnam still produces ~170–180K b/d domestically and imports additional refined products. The "~600K b/d" consumption figure follows the Energy Institute Statistical Review of World Energy (602K for 2023); preliminary 2024 estimates range 600–710K b/d depending on the source (EI vs. CEIC/Statista).
July 2026 update: The original piece was published on 20 April 2026, mid-crisis. The narrative and price sections have been updated through 10 July 2026 - after the Islamabad MOU (17 June) reopened Hormuz and Vietnam's domestic price adjustment of 9 July 2026.
The Big Picture - In Numbers
Vietnam ranks 25th in the world for proven reserves (EIA: ~4.4 billion barrels). But consumption is 3+ times production. The gap keeps widening - the fields are aging, while economic growth never stops.
The flagship fields - Bach Ho, Rong, Dai Hung - have been in production since the 1980s. Bach Ho's peak output in the early 2000s was estimated at ~265K b/d; today it's down to a few tens of thousands (Offshore Technology / Vietsovpetro). The physics is unforgiving: as reservoir pressure drops, water/gas injection is needed to push oil up - marginal costs rise while marginal output falls. No field anywhere is exempt from this.
The 348K b/d combined capacity of the two refineries, Nghi Son and Dung Quat, covers only ~58% of fuel demand - the rest must be imported as refined product from Singapore, South Korea, and Malaysia (the-shiv / Energy Institute). In other words, Vietnam is exposed on both crude oil inputs and refined product outputs - two layers of risk stacked on top of each other.
The Oil Flow - Three Sources, Two Refineries
Vietnam's oil flow is three sources feeding into two refineries - and the residual shortfall still has to be plugged with imported refined product. Each layer carries its own risk, and no layer can fully cover for another.
Output of ~167–180K b/d (2024), down from ~260K (2018) - EIA monthly. Reserves of ~4.4 billion barrels, but aging fields mean marginal cost of $40–60/barrel - unprofitable when Brent falls below $50.
Worth $8.1 billion (Vietnam Customs, 2024). 86% from Kuwait, transiting Hormuz. Up ~16-fold over 10 years as fuel demand doubled.
~$6.8 billion (2025). Singapore 34%, South Korea 27%, Malaysia 15%, China 15% (the-shiv 2025). More diversified than crude - but still dependent on regional supply chains.
Nghi Son vs. Dung Quat - Two Design Philosophies
Two refineries, two configurations, two risk profiles. Nghi Son is contractually locked to a single crude grade; Dung Quat was designed for multi-grade flexibility. This is the pivot point of every crisis scenario.
NSRP is a joint venture - Kuwait Petroleum Corp. is both a shareholder and the crude supplier. The refinery was purpose-built for Kuwait Export Crude (~30–31° API, ~2.5–2.7% sulfur - medium sour). This isn't a "supply choice" - it's a structural constraint, embedded in a 20+ year offtake contract (NSRP). Switching crude grades means lower throughput efficiency and potential breach of the shareholder agreement.
Reserves - The Thinnest in Asia
The IEA (International Energy Agency) standard recommends net-importing countries hold 90 days of consumption - a buffer wide enough to negotiate calmly during a supply crisis. Advanced economies all sit well above this level; Vietnam sits at the bottom.
20 days means: if Hormuz closes entirely and no substitute crude arrives in time, all of Vietnam's industrial, transport, and aviation fuel begins running out after three weeks. Tankers from the US need 35–45 days. From West Africa, ~33 days. The gap between "running out" and "arrival" is exactly where emergency measures - price stabilization funds, mandatory consumption cuts - have to be triggered.
Why Can't Vietnam Simply Produce More at Home?
A natural question: why not raise domestic production to cut import dependence? The answer - as both IEA and EIA have noted - is that field geology doesn't allow it. Output has fallen from ~260K b/d (2018) to ~180K (2024). Four reasons, none reversible in the short term.
Bach Ho, Rong, and Dai Hung have been producing since 1980–90. After 30–40 years, reservoir pressure falls → oil no longer flows on its own → water/gas injection is required. This is oil-field physics; there is no exception.
PVN keeps exploring, but no large oil discovery has been made since the 2000s. Recent major finds (Ca Voi Xanh, Ken Bau) are mainly natural gas, not crude oil.
Aging fields require deeper drilling → marginal cost of $40–60/barrel. When Brent fell to $30–40 (2020), production became unprofitable → PVN cut investment → output fell further. A classic downward spiral.
Before 2009, Vietnam exported crude oil (having no refinery of its own). Once Dung Quat (2009) and Nghi Son (2018) came online, domestic crude was consumed internally, and Vietnam still had to import >280K b/d of crude as feedstock.
Vietnam cannot "raise domestic supply" its way out of this risk. Its oil fields are structurally in the late stage of their production life - a geological reality, not a governance failure. The only available buffers are strategic reserves and import diversification - exactly the two things currently in short supply.
The 2026 Hormuz Crisis - A Real-World Stress Test
Every risk model is only theoretical until it's tested. From March to June 2026, Vietnam got that real test - and the outcome laid bare every weakness analyzed above, before the situation cooled from mid-June.
'26 Strait of Hormuz Crisis Middle East · began 28 Feb 2026 Impact absorbed
Following a wave of US–Israel airstrikes on Iran (Feb 28), the IRGC declared Hormuz closed (Mar 2) - a strait carrying ~20.7 million barrels/day (~27% of globally seaborne oil - EIA). Traffic dropped to ~6 vessels/day, down from a normal ~135 (Bloomberg, 03/2026). Brent broke $100/barrel on March 8 - the first time in four years - and eventually peaked around $126/barrel; March 2026 recorded the largest-ever monthly increase in oil prices (Reuters).
- Fuel import tariffs cut to 0% (all MFN duties suspended)
- Price stabilization fund tapped: VND 4,000–5,000/liter - sustainable for 15–30 days
- PVN ordered to halt crude exports, prioritizing Dung Quat
- Encouraged remote work to cut consumption (a Tier-3 measure under the APERC framework)
- Mobilized 4 million barrels from diplomatic partners - roughly 6 days of consumption
- Requested Japan supply additional crude and Jet A-1 from commercial SPR
- Nghi Son ran its first-ever test of non-Kuwaiti crude - a blend of WTI (US) and Das Blend (UAE)
- Dung Quat activated its SOCAR (Azerbaijan) contract for 2M barrels/month, signed in 2025
Domestic RON95 gasoline rose +21% in one month, peaking around VND 29,950/liter in late March - and would have hit ~VND 33,000/liter without the stabilization fund paying out VND 3,000–4,000/liter; diesel came close to a record above VND 41,000/liter (MOIT, March 26). Decision 482/QD-TTg added cuts to the environmental tax, VAT, and special consumption tax on fuel. MUFG Research cut its 2026 GDP forecast from 8.2% to <7% if oil stayed above $120. The stabilization fund could only subsidize prices for 15–30 days - after that, market pricing, no more buffer.
'26 OFAC Waiver & Iran Option US issues GL 134 · 03/12/2026, expires 04/11 Narrow Window
In March 2026, OFAC issued two emergency licenses - GL 133/134 (Mar 5 for India; Mar 12 globally) - permitting the purchase of ~125–140 million barrels of Russian oil "stranded at sea" due to shadow-fleet sanctions. In March 2026, OFAC also issued General License U for Iranian oil (through Apr 19). For the first time, US documents explicitly named Vietnam and Thailand as potential buyers (CNBC, 03/2026).
Technical Compatibility - Iran Heavy ≈ Kuwait Export Crude
GL 134 is valid for only 30 days (through 04/11/2026), and the EU has objected publicly - von der Leyen: "this is not the time to ease up." The S.1241 (Sanctioning Russia Act 2025) bill, backed by 80+ senators, proposes tariffs of up to 500% on goods from countries buying Russian energy. Vietnam has been a US Comprehensive Strategic Partner since 2023, and the US is its #1 export market (~$120 billion). This isn't a purely technical problem - it's a geopolitical balancing act.
Why Russian oil isn't Plan B
Russia exports ~5M b/d of crude. China buys ~2.2M, India ~1.76M (up from ~50K in 2020 - nearly 35-fold in four years), Turkey/Eastern Europe ~0.5M (Reuters 2024). That leaves ~0.5M b/d for the rest of the world combined. Vietnam needs ~0.28M b/d of imported crude. In other words, even without sanctions, Vietnam would struggle to replace Kuwait with Russia - the physical supply pool is thin, and it must compete on price with every buyer outside China and India.
'26 Islamabad MOU & Hormuz Reopening Signed 17 Jun 2026 · updated through 10 Jul De-escalation
On June 17, the US and Iran signed the Islamabad MOU ending the war: the strait reopens toll-free for 60 days, Iran clears mines within 30 days, and the US proportionally lifts its naval blockade of Iranian ports alongside sanctions relief. Within the first week, 20+ tankers had crossed the strait; Kpler estimated traffic could reach ~50% of prewar levels within 30 days, with ~118 tankers stuck in the Gulf gradually exiting (CNBC, Jun 19). Brent fell back to the $70–73/barrel range - pre-war levels (Al Jazeera, Jun 25), and in early July touched its lowest since the war began (Al Jazeera, Jul 2).
Domestically, pump prices fell with each pricing cycle - one adjustment cut RON95-III by as much as VND 5,625/liter, the steepest in months. By the July 9, 2026 cycle, E10 RON95-III was down to VND 20,000/liter (−410 VND) and E5 RON92 to VND 19,190/liter - giving back nearly the entire +50% shock of March and returning to roughly the pre-crisis baseline.
On June 20, Iran declared the strait closed again, citing Israeli ceasefire violations in Lebanon; on June 27 the US opened a widened transit corridor through Omani waters (CNBC, Jun 22). Early July still saw flare-ups that sent Brent up ~4–5% in a session toward $78 before easing. Hormuz traffic remains below prewar levels, and every MOU milestone (full blockade lift by July 19, the 60-day nuclear negotiation window) can still slip. Prices have turned - the risk structure hasn't.
Alternative Sources - How Much Can They Really Cover?
If Kuwait's supply is cut off entirely (a prolonged Hormuz closure), can the sum of all plausible alternative sources cover the gap? The blunt answer: only 30–40% of the lost volume - leaving a net shortfall of ~50–60% (without Iran) or 15–30% (if the US fully lifts Iran sanctions).
A 15–30% shortfall equals cutting 90–180K b/d - on the order of the diesel demand of the entire agriculture-fishing sector, or the jet fuel demand of the whole aviation industry. This is why the 90-day reserve target isn't a "nice to have" - it's a normal-operations requirement for an import-dependent economy.
Case Study - If Hormuz Closed Entirely, How Much Oil Would Vietnam Lack?
The previous section gave a share-based range for the shortfall. This case converts it into actual barrels: how much is missing per day, how it accumulates over time, and how far the existing buffer (SPR ~20 days, stabilization fund 15–30 days) can absorb the shock before market pricing bleeds into the wider economy.
Scenario assumptions: Hormuz cuts 100% of flow for N days · the US does not lift Iran sanctions · Russia cannot cover a meaningful share (China + India already absorb ~80%) · Asian refiners (Singapore, Korea, Malaysia) continue exporting refined product to Vietnam but cut ~30% of throughput since they themselves are 40–55% dependent on Hormuz.
The actual March–June 2026 crisis was the partial-squeeze version: flow never went to zero, and it ended after ~3.5 months with the Islamabad MOU. The case below is kept as an upper-bound counterfactual - a yardstick for how thin the current buffer is, not a forecast.
Step 1 - Daily supply after maxing out alternative sources
Under normal conditions, Vietnam's daily fuel balance consists of three supply layers: domestic crude → the two refineries, imported crude → the two refineries, and directly imported refined product. When Hormuz closes, the middle layer nearly vanishes - and the third layer shrinks too, since Asian refiners are themselves exposed to Hormuz.
244K b/d is the raw crude volume lost at the port. But (i) PVN halts an additional ~30K of exports, (ii) non-Hormuz sources ramp up ~30K, and (iii) Asian refiners still export part of their refined product → the net hit to demand ends up around ~190K b/d. This is the best-realistic case; if Asian refiners panic and cut deeper, the deficit could jump to 250–280K (40–46%). That's the "50–60% shortfall" range flagged in the previous section.
Step 2 - Accumulation over time: when does the buffer run out?
Vietnam holds ~20 days of effective reserves (national SPR + mandatory holdings at distribution enterprises) ≈ ~12 million barrels at a consumption rate of 600K b/d. The price stabilization fund absorbs another 15–30 days of price impact. Once the ~190K b/d deficit compounds, this buffer disappears fast.
Vietnam's SPR at ~20 days = ~12M barrels sounds substantial. But against a Hormuz deficit of ~5.7M barrels/month, it only buys about 63 days before the economy faces a physical shortage. The target under Decision 861/QD-TTg (75–80 days by 2030) would raise the buffer to ~45M barrels - enough for 7–8 months of a prolonged Hormuz closure. This isn't a "nice to have" figure - it's the difference between negotiating from a position of strength and improvising from a position of weakness.
What Is Oil Used For - And Does Losing Oil Mean Losing Power?
Total imports of crude oil, refined product, and LPG combined amount to roughly $17 billion USD/year (EIA, Ministry of Industry and Trade). Breaking this down by sector shows exactly where the vulnerability sits if supply is cut.
Vietnam's 2024 power generation mix (~316 TWh, source Ember / EVN): coal ~48–50%, hydropower ~30%, solar ~8%, gas ~7%, wind ~4%, oil <0.1% (mostly backup diesel for offshore islands). Losing oil doesn't directly cause power outages.
Ships carrying imported coal (~65 million tonnes/year) need oil to run. Trucks hauling coal from Quang Ninh need diesel. Backup generators at hospitals and data centers need diesel. A prolonged oil shortage disrupts the coal supply chain and power-sector logistics → indirect pressure on the grid. Oil is the circulating blood, not the pump itself - but a body low on blood still has a weakened heartbeat.
The Macro View - The Price of a Shortcut
After 2009 and 2018, when Dung Quat and then Nghi Son came online, Vietnam entered a new chapter: it could refine ~58% of domestic fuel demand itself. In exchange: a major joint venture with Kuwait Petroleum Corp. for Nghi Son - carrying a commitment to buy a single crude grade, through a single strait, backed by strategic reserves only a quarter of the IEA standard.
This isn't a verdict - it's the nature of the trade-off. Nghi Son contributes 33% of fuel demand, creates thousands of jobs, and generates significant budget revenue. But when Hormuz seized up in March 2026 - and Nghi Son had, for the first time, tested non-Kuwaiti crude (Das Blend from the UAE) just two months earlier, in January of the same year - the question surfaced: what is the real cost of this shortcut, and who bears it next time?
By July 2026, the loop has half-closed: the Islamabad MOU reopened the strait, Brent gave back its entire rally ($126 → the $70s), domestic pump prices returned to around VND 20,000/liter, and Nghi Son proved it can run non-Kuwaiti crude when pushed to the wall - real gains that shouldn't be dismissed. But the structural layer hasn't moved: Kuwait remains the dominant crude source, reserves still cover ~20 days, and the strait itself was declared "closed again" in late June before tensions eased.
Both the IEA and the EIA have noted that net-importing countries cannot escape their exposed position in the short term. The only tool available is a buffer - reserves, source diversification, and flexible capacity. Decision 861/QD-TTg targets 75–80 days by 2030 and 90 days by 2050, requiring ~$11.4 billion USD in investment. The 2026 test showed: the question is no longer "if" but "when" Hormuz seizes up again - and this time, the post-MOU window of cheap oil is precisely the moment to buy the barrels that the 90-day target is waiting for.
03 Discussion
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