Strait Crisis: Unparalleled Energy Shock

A full closure of the Strait of Hormuz combined with major damage to Gulf oil and LNG infrastructure, while Russian oil and gas remain structurally absent from the European market, is beginning to amount to a compound external supply shock of a scale not seen in Europe for decades. The reason this would be so destabilising is that Europe has reduced dependence on Russia, but it has not escaped hydrocarbon dependence itself; rather, it has restructured it. The EU’s dependency on Russian gas fell from 45% of imports at the start of the war to 12% in 2025, while Russian oil imports fell from 27% to 2%. However, the remaining 35 bcm of Russian gas still being phased out has been replaced only in part by efficiency, renewables, and demand destruction, and in part by greater exposure to global LNG and maritime trade routes. At the same time, the Strait of Hormuz still carries around 20 million barrels per day of oil, or roughly one-fifth of global petroleum liquids consumption, making it the single most dangerous chokepoint for Europe’s external energy position.

The most useful benchmark for assessing macroeconomic damage is the ECB’s March 2026 scenario work, as it explicitly models a Middle East escalation involving disruption of the Strait of Hormuz and damage to energy infrastructure. In the ECB’s adverse scenario, oil peaks around $119 per barrel and European gas around €87/MWh in the second quarter of 2026; in the severe scenario, oil rises to about $145 and gas to about €106/MWh, with inflation materially above baseline and growth materially weaker in both 2026 and 2027. Crucially, the ECB emphasises non-linearity: once a shock becomes large and persistent enough, the pass-through into core prices, wages, and inflation expectations becomes much stronger than in a routine commodity spike. That shock will be further impactful because Europe is no longer dealing with a transitory reopening shock or a mild winter-summer storage cycle; it is facing the risk of a prolonged geopolitical dislocation atop already high strategic uncertainty.

In practical market terms, the first-round impact would be immediate and brutal. Reuters reported on April 2 that Brent was trading above $107 and WTI above $111 after renewed threats of continued attacks on Iran, while another Reuters report said crude had risen to nearly $120 and that OPEC+ was already considering further output increases in response to the supply disruption and the possibility of a future reopening of Hormuz. Reuters also reported record front-month backwardation in U.S. crude, a classic sign that the market is pricing immediate scarcity more aggressively than long-term shortage. In plain terms, traders are only pricing a higher equilibrium price, but they are pricing panic over near-term deliverability. That is exactly the market structure that transmits fastest into refined fuel shortages, diesel premiums, shipping costs, and inflation expectations.

The real danger to Europe is not only oil. It is the simultaneous oil-gas-electricity chain reaction. The IEA’s Gas Market Report for Q1 2026 had already expected global LNG supply growth above 7% in 2026, with North America driving most of the increase and with a somewhat looser market than in 2025. Under normal conditions, that would have helped Europe absorb the final stages of the Russian gas phase-out. But that benign forecast is contingent on normal maritime conditions and the absence of large-scale disruption in the Gulf. If Gulf LNG capacity is damaged or shipments are blocked, Europe loses the flexibility that underpins its post-Russia gas model. The result would be a sharp upward repricing of TTF, intensified competition with Asian buyers, and renewed stress around gas storage refill ahead of winter. Reuters reported in late March that EU gas storage was only 28% full, unusually low for the time of year, which means the bloc is entering the refill season from a weaker starting point than policymakers would prefer.

That gas stress would quickly become an electricity crisis, because Europe may have increased renewable generation substantially, but gas remains the key balancing fuel in many power markets. The Commission says the EU now produces more electricity from wind and solar than from gas. Renewables accounted for 48% of the bloc’s power mix in 2025, yet gas generation still rose as hydro underperformed and system flexibility was needed. This means Europe has improved structural resilience but not eliminated short-run price vulnerability. When gas sets the marginal price, electricity bills for households and industry still rise sharply even if the average generation mix is cleaner than before. The power shock would therefore hit industry first through wholesale prices and then the wider economy through retail pass-through, support packages, and lost competitiveness.

The macroeconomic consequences for the euro area would unfold through four channels at once. First, headline inflation would rise through transport fuels, heating, and power. Second, core inflation would begin to drift upward as logistics, fertiliser, food processing, chemicals, metals, and manufactured goods all reprice. Third, real incomes would be squeezed, weakening consumption. Fourth, the external balance would deteriorate as the energy import bill rose. Eurostat says energy products accounted for 22.8% of total EU imports at the 2022 peak, then fell back to 13.2% in 2025 as prices normalised. A renewed surge would therefore reopen the same external vulnerability that damaged the euro area's current account in 2022. The ECB has already documented that the earlier deterioration in the current account was driven largely by higher energy import prices, so a repeat shock would again weaken the euro’s terms of trade and likely put downward pressure on the currency, compounding imported inflation.

On growth, the ECB’s severe scenario is particularly revealing because it assumes not only larger supply losses but also damage to infrastructure and a slower return to normal supply conditions. In that case, real GDP growth is 0.5 percentage points lower in 2026 and 0.4 percentage points lower in 2027 than the baseline, with negative quarterly growth in mid-2026, while HICP inflation runs 1.8 percentage points above the baseline in 2026 and 2.8 percentage points above it in 2027. That is close to stagflationary territory. And because these are no-policy-change scenarios, the implication is that policymakers cannot just “wait out” the shock. If they do, the energy shock risks becoming a broader price-level and competitiveness shock. The ECB’s own framing is that the question is no longer whether energy shocks matter, but when their scale and duration make second-round effects likely.

For the European industry, the distributional effect would be highly uneven. Export-heavy, energy-intensive economies such as Germany, Italy, the Netherlands, Belgium, Slovakia and parts of Central Europe would bear the heaviest industrial impact because gas, electricity, and chemicals feed directly into production costs. Fertiliser output would likely be one of the first sectors hit, repeating the post-2022 pattern. That would, in turn, affect agriculture and food inflation. Chemicals, aluminium, glass, ceramics, cement, and paper would also be vulnerable. By contrast, economies with high shares of hydro, nuclear, or domestic low-cost renewables would still suffer, but their relative position inside the single market could improve. One likely consequence is an intensification of intra-EU political tension over state aid, because richer member states would want to shield domestic industry more aggressively than poorer ones. The Commission’s 2025 affordable energy action plan was designed in part to address structurally high energy costs, with projected savings of €45 billion in 2025, rising to €130 billion annually by 2030. Still, a wartime supply shock would overwhelm those savings in the short run and force renewed emergency intervention.

The fiscal dimension is therefore central. Europe already learned in 2022-2023 that energy shocks are not just inflation shocks; they are budget shocks. Emergency support, tax reductions, household transfers, business compensation, and industrial aid can be politically unavoidable. The Commission’s crisis architecture already includes gas storage obligations, the joint energy platform, voluntary demand reduction, and precedents for capping or redistributing excess energy rents. Those tools now need to be understood not as optional legacy measures but as the operating manual for the next shock. In a severe Hormuz scenario, the urgent measures member states should take are: immediate coordinated releases of strategic petroleum reserves; an accelerated, centrally coordinated EU gas purchasing programme; mandatory rather than voluntary demand reduction if TTF spikes and storage refill lags; temporary state aid flexibility for critical industrial sectors; targeted cash support for vulnerable households rather than blanket untargeted subsidies; and fast-track permitting for grid, storage, renewables, and LNG contingency infrastructure.

Future market predictions need to be framed as scenarios, not forecasts. The short-term oil market outlook for spring and summer 2026 is likely to remain highly risk-driven. If Hormuz remains functionally blocked and Gulf infrastructure damage persists, front-end crude prices could remain above $110 and intermittently test the ECB severe-scenario range closer to $145, especially if inventory drawdowns accelerate and OPEC+ spare capacity outside disrupted routes proves insufficient. If maritime security improves and some Gulf exports reroute successfully, prices could settle back toward the low-$90s to low-$100s range by late 2026. There are indications that OPEC+ producers are considering output increases. Still, it also notes that the effect would be limited while the Strait of Hormuz remains closed and that only a subset of producers can materially increase supply. So, the key price determinant is not nominal spare capacity, but deliverable spare capacity.

For gas, the medium-term picture is slightly more favourable than for oil, but only beyond the immediate crisis horizon. The IEA expects 2026 LNG supply growth to be the fastest since 2019, led overwhelmingly by North America, Canada, and Mexico, which means the structural gas balance should improve into 2027 if shipping routes remain open and new liquefaction ramps on schedule. That suggests Europe’s gas market could remain extremely volatile in 2026, but ease materially in 2027 if the Gulf disruption is temporary and Atlantic Basin LNG offsets the Russian phase-out. In other words, oil faces a sharper immediate scarcity problem, while gas faces a sharper short-run logistics and refill problem but a somewhat better medium-term supply story. Europe’s policy mistake would be to treat these as identical markets. They are not.

Building on prior strategic risk foresight regarding the security dynamics and conflict characteristics of the Gulf region, the likelihood of further escalation and additional destruction of oil and gas infrastructure remains high. Continued attacks, combined with explicit threats and further retaliation against refineries, storage facilities, export terminals, pipelines, and tankers, significantly increase the probability of sustained disruption to global energy supply. This risk is compounded by the reduced effectiveness of countering Iranian missile and drone capabilities, which heightens the vulnerability of fixed energy assets across the region. Repeated strikes on silos, ports, and processing facilities would reinforce a worst-case scenario for the energy sector, in which markets price in not only immediate supply losses but also persistent uncertainty, driving sharp, volatile price shocks.

Russia’s strategic posture further complicates this scenario. Moscow is unlikely to remain passive and is pursuing contingencies that reduce energy exports, particularly to remaining European recipients, while deliberately constraining flows and redirecting them toward alternative buyers, keeping prices high and profits maximised to fund its war in Ukraine. Simultaneously, Asian economies, highly dependent on Gulf energy, would accelerate their purchases to secure supply, creating a parallel surge in demand. This combined effect would produce a simultaneous run on available cargoes, tightening global supply and amplifying price volatility. The resulting feedback loop between constrained supply and precautionary demand would further intensify pressure across the oil, gas, and refined-product markets in Europe.

The conflict itself also carries a high probability of escalation. Increased strikes designed to pressure Iran into negotiations, then trigger retaliatory attacks against Gulf Cooperation Council infrastructure, further degrading export capacity. The stakes rise even further if ground operations become plausible, such as attempts to seize critical energy nodes like Kharg Island, a vital Iranian export hub. Any amphibious seizure or defensive bombardment would likely significantly damage infrastructure, whether through assault operations or subsequent counterattacks. Expansion of hostilities into mainland coastal areas or strikes on inland nuclear-related sites could prolong the conflict, transforming it into a broader regional war of attrition.

In such a scenario, multiple non-state and aligned actors across the region could target vulnerable energy assets. This could include strikes on Saudi facilities from Yemen, on Iraqi oil fields by the PMU, and shipping lanes by the IRGC, as well as disruptions originating from Hezbollah or other elements. These cascading attacks would compound the damage to infrastructure and prolong supply disruptions. The economic implications directly mirror these strategic risks: sustained loss of supply, intensified competition for remaining energy, and persistent market volatility. Consequently, both the strategic and economic outlooks converge toward a severe scenario characterised by price shocks, supply deviation, and systemic disruption across global energy markets.

Ireland deserves separate attention because it is unusually exposed to imported energy risk despite progress in renewables. Gas Networks Ireland says roughly 80% of Ireland’s natural gas comes via Great Britain, and that Ireland is the only European country with no domestic gas storage, no long-term indigenous supplies, and no alternative supply routes. SEAI reports that in 2023, 44.3% of Ireland’s gross electricity supply came from natural gas, 33.7% from wind, and 9.5% from net imports, while the CSO says oil accounted for 51% of Ireland’s energy use. In 2024, SEAI still recorded fossil fuels at 81.4% of Ireland’s total primary energy requirement and import dependency at nearly 80%. This means Ireland would face a dual shock: higher oil prices hitting transport and household costs, and higher UK-linked gas costs feeding directly into electricity prices.

Ireland’s policy response should therefore be more security-focused than that of some continental states. Dublin should accelerate the Strategic Gas Emergency Reserve at Shannon, which the government approved as an FSRU-based project and which Gas Networks Ireland describes as a temporary state-led emergency facility. It should also expand strategic oil product planning, protect vulnerable households through targeted income supports rather than broad subsidy leakage, and fast-track offshore wind, grid reinforcement, and flexible backup generation. The single most important Irish policy truth is that the country cannot assume that “the UK route” is diversification. It is a transmission corridor, not an indigenous security asset. If Britain itself is under price and supply pressure, Irish vulnerability is amplified rather than reduced.

Further complicating the situation is the practical reality of strategic energy reserves and whether Ireland possesses sufficient buffers to cushion a shock emerging from the Gulf that could rapidly transmit through global markets. Ireland maintains strategic oil stocks in line with EU obligations, but these reserves are designed primarily for short-term supply disruptions rather than prolonged price spikes. They can moderate immediate shortages, yet they offer limited protection against sustained global price inflation, which would still be passed through to Irish consumers and businesses. Ireland’s heavy reliance on imported oil and gas, combined with the absence of domestic gas storage and dependence on interconnection via the United Kingdom, heightens vulnerability. In this context, the question becomes whether the state is prepared to take urgent pre-emptive policy measures to weather such a storm. Temporary relief on carbon-related energy taxes should be considered to cushion the socio-economic impact on households already strained by the cost-of-living crisis, while targeted support for small and medium enterprises could prevent closures and layoffs. In a severe energy shock comparable to the 1970s oil crisis, the COVID-19 economic disruption, or the immediate fallout from the war in Ukraine, the economic security of households and the survival of businesses become the overriding priority. Swift fiscal intervention, fuel cost mitigation, and emergency income supports would therefore be essential to stabilise consumption, maintain employment, and prevent a broader contraction in the Irish economy.

Further pressure points are reflected in Irish strategic reserves and in the growing need to pre-plan for the worst-case scenario, particularly given the specific energy vulnerability of Irish strategic supplies. If the Gulf crisis deepens and significantly disrupts global oil flows, Ireland’s exposure is heightened not only by import dependence but also by the structure of its strategic reserves. Although Ireland holds approximately ninety days of oil stocks, a portion of these are stored outside the country under bilateral agreements. In a severe, system-wide supply shock affecting multiple European states simultaneously, there is a non-negligible risk that countries holding Irish stocks could prioritise domestic needs or face logistical delays in releasing fuel. This does not necessarily mean supplies would be withheld, but the potential for constrained access effectively shortens Ireland’s usable buffer. Under such conditions, the timeline compresses further. In the first week, commercial supply chains would continue, but prices would surge. By week two, precautionary buying and tightening imports would increase pressure on domestic inventories. By weeks three to four, Ireland would likely begin controlled releases of domestic reserves while conserving stocks held abroad. If access to overseas holdings were delayed or uncertain, authorities would move more quickly toward prioritisation measures for essential services. By weeks four to six, allocation controls could be introduced, particularly for diesel. If disruption persisted, formal fuel rationing could realistically emerge within four to six weeks, rather than six to eight, due to the reduced immediately accessible buffer and the need to preserve minimum emergency levels.

The deepest strategic conclusion is that Europe’s energy market is entering a new era in which security, not only decarbonisation, is the central pricing variable. The Commission’s own framing now connects lower energy costs, preparedness, and the completion of the energy union. Christine Lagarde’s March 2026 speech makes the same point from a monetary angle: large and persistent energy shocks cannot be treated as isolated commodity events once they begin to propagate across wages, expectations, and core prices. So the future European energy market is likely to be defined by three simultaneous trends: structurally higher geopolitical risk premia for oil and gas than markets assumed in the late 2010s; faster investment in renewables, storage, interconnection and flexible capacity as security assets rather than just climate assets; and a permanent policy premium on resilience, including storage, strategic reserves, and backup import routes. Europe is not returning to the old normal. It is moving into a more resilient system, but first through a period that will probably be more volatile, more politicised, and more expensive.