Iran War Energy Shock Drives Renewed Demand for Coal

The year 2025 was supposed to mark peak global coal demand. The International Energy Agency projected consumption would flatten near 8.8 billion tons before beginning a steady decline toward 2030 [1]. Instead, five weeks into the effective closure of the Strait of Hormuz — the narrow waterway through which roughly 20% of the world's oil and liquefied natural gas flows — governments across Asia and Europe are scrambling to bring coal-fired power plants back online [2].

The speed of the reversal is striking. Thailand is restarting two coal plants decommissioned last year. South Korea has removed its 80% operating cap on coal-fired generation. Japan, on March 27, confirmed it would lift caps on coal power generation, allowing older and less-efficient plants to operate at full capacity for up to a year starting in April [2][3]. India is burning more coal to meet peak summer electricity demand of 270 gigawatts — nearly twice Spain's total capacity [4]. Indonesia is prioritizing domestic coal supply over exports, while Vietnam, the Philippines, and Thailand are all boosting coal-fired output [4].

The Price Signal

Newcastle thermal coal, the benchmark for Asian buyers, sat at roughly $101 per ton at the start of 2026. By March 28, it had surged to $146 — a 45% increase in under three months [5].

Source: Trading Economics / Investing.com

Data as of Mar 31, 2026CSV

The trajectory echoes the 2022 post-Ukraine energy shock, when Newcastle coal briefly topped $400 per ton. The current spike is smaller in absolute terms but follows a different pattern: rather than a single price explosion driven by European gas panic-buying, this crisis reflects sustained structural damage to LNG supply infrastructure. A main LNG export facility in Qatar was damaged in the conflict, taking 17% of Qatar's production offline, with repairs estimated to take three to five years [6]. Analysts estimate the attacks have removed 12.8 million tonnes per annum from the market — approximately 2.5% of global LNG supply [6]. Bloomberg Intelligence estimates thermal coal prices could rise another 46% if the war continues for months [6].

Meanwhile, WTI crude oil has climbed from $55.44 in December 2025 to $98.71 at its March peak — a 78% swing — before settling around $89 [7]. Brent crude briefly surpassed $126 per barrel on March 8, its highest level in four years [8].

Source: FRED / EIA

Data as of Mar 23, 2026CSV

Who Is Most Exposed

The countries most vulnerable to a Strait of Hormuz disruption are those that depend on Persian Gulf suppliers for the bulk of their energy imports. Pakistan sources 99% of its LNG imports from Qatar and the UAE. Sri Lanka imports nearly 90% of its oil and gas through the strait. Bangladesh depends on the corridor for 72% of its LNG, and India for 53% [8][9].

Source: CNBC / UNCTAD

Data as of Mar 15, 2026CSV

South Korea, which relies on the strait for approximately 45% of its LNG supply, spent $120.1 billion on fuel imports in 2024 alone and has committed $127 billion to fossil fuel infrastructure over 11 years — 13 times its renewable energy spending [4]. Japan, with roughly 35% LNG exposure to the Gulf, has responded by opening oil stockpiles and rolling out emergency gasoline subsidies in addition to lifting coal generation caps [3].

The IEA requires member countries to hold emergency oil stocks equivalent to at least 90 days of net imports [10]. In March 2026, the agency's 32 member countries unanimously agreed to release 400 million barrels from emergency reserves — the largest coordinated stockpile release in IEA history [10]. India reports coal stockpiles sufficient for approximately three months of consumption [4]. But for nations like Pakistan and Bangladesh, which lack both deep strategic reserves and procurement flexibility, the crisis is immediate and acute [9].

Up to 30% of internationally traded fertilizers also normally transit the Strait of Hormuz, and unlike oil, the fertilizer sector has no coordinated strategic reserves — compounding the economic pressure on agricultural economies throughout South Asia [8].

Country-by-Country: The Phase-Out Reversals

Before the conflict, coal phase-out plans were proceeding — unevenly but directionally — across Europe and parts of Asia. The Iran war has disrupted that trajectory country by country.

Italy delivered the most dramatic reversal. On March 27, Italy's parliament voted to delay its coal phase-out from 2026 to 2038 — a postponement of more than 12 years [11]. The country operates four coal-fired power stations, two of which on the mainland had already lost their coal-burning authorization in January. Two Sardinian plants were scheduled for closure in 2028-2029 once a submarine cable connects the island to the mainland grid [11]. Climate think tank ECCO called the postponement "symbolically damaging, but low-impact in practice — at least for now," noting that Italy's coal generation in 2025 was approximately 2,975 GWh, less than 1% of national electricity output [11]. Reactivating dormant plants would require new permits, a process that could take years [11]. Only Germany, Poland, and Bulgaria share phase-out timelines as unambitious as Italy's revised 2038 target [11].

Japan is suspending its cap on coal plant utilization for one year from April 1, 2026, with the stated goal of cutting LNG consumption by about 500,000 metric tons [3][12]. The government wants older, less-efficient plants to operate at full capacity — a reversal of the efficiency-based restrictions that had gradually reduced coal's share of the generation mix.

South Korea removed its 80% operating cap on coal-fired generation and has pledged to retire most coal plants by 2040, but the immediate policy direction runs counter to that commitment [2][4]. The country requires about 8 GW of new wind capacity annually to meet its net-zero goals — a pace it has never achieved [4].

Thailand, the Philippines, and Vietnam are all boosting coal-fired output, with Vietnam considering imports from the United States and Laos because Indonesian supply — previously its primary source — is being redirected for domestic use [4].

In the United States, the Trump administration has used emergency powers to keep aging coal plants operating, a move that predates the Iran conflict but that the energy crisis has reinforced [13].

The Emissions Arithmetic

Global energy-related CO2 emissions stood at approximately 33 gigatons in 2019, with coal responsible for roughly 14.4 Gt of that total [14]. After a pandemic-driven dip in 2020, coal emissions rebounded to 14.8 Gt by 2021 — 0.4% above 2019 levels — driven almost entirely by Asian demand [15].

Asia already accounts for over 10 Gt of annual coal-related emissions, with coal supplying more than 50% of energy use across the continent [14]. If coal consumption in Europe and East Asia were to return to sustained 2019 levels for a two-year period, the IEA's own modeling from the 2021 rebound suggests an additional 400-640 Mt of annual CO2 emissions above what current trajectories project [15]. That would effectively erase one to two years of progress toward the emissions reductions needed to hold warming to 1.5°C under the Paris Agreement.

The timing compounds the damage. The U.S. withdrawal from the Paris Agreement took effect on January 27, 2026 [16]. With the world's largest historical emitter formally outside the agreement and its current largest emitter — China — stating in its latest five-year plan that it will continue to use coal for energy security, the crisis arrives at a moment when the international climate framework is at its weakest [16].

Financial Mechanisms and Public Costs

The emergency measures enabling coal's return take several forms. Japan's approach is regulatory — suspending utilization caps rather than writing checks for coal generation directly, while simultaneously deploying $1.34 billion in clean energy subsidies over five years to offset the contradiction [12]. The government has also raised fuel subsidies to cushion consumers.

Malaysia offers a cautionary tale about subsidy costs: the country's fuel-subsidy bill surged from 700 million Malaysian ringgit ($174 million) to more than 3.2 billion ringgit ($797 million) — a fourfold increase driven by rising import costs [2].

Indonesia, where coal power operating costs rose 48% between 2020 and 2024, has seen utility subsidies increase 24% to $11 billion, consuming 5% of the national budget [4].

In the United States, the policy mechanism is different: the administration has invoked emergency powers to prevent coal plant retirements, effectively socializing the cost of uneconomic plants through higher electricity bills rather than direct fiscal outlays [13].

The EU's carbon pricing system creates an additional wrinkle for European coal. Even with Italy's phase-out delay, coal remains uncompetitive against gas under EU Emissions Trading System carbon prices, meaning operators have little financial incentive to restart unless emergency capacity payments or temporary ETS exemptions are granted [11].

The Strategic Case for Coal

The steelman argument for the coal revival rests on three premises: the duration of the conflict, the limitations of alternatives, and the cost of inaction.

First, the structural damage to LNG supply is not a transient disruption. With Qatar's largest export facility requiring three to five years of repairs and 12.8 million tonnes per annum removed from the market, the supply gap persists regardless of whether the Strait of Hormuz reopens [6]. Second, renewables — while cheaper per megawatt-hour in new-build costs — cannot be deployed fast enough to replace the missing gas volumes in the 12- to 24-month window that the crisis demands. South Korea, which needs 8 GW of new wind capacity annually to meet climate targets, has never installed at that pace [4]. Third, the alternative to coal in many Asian economies is not clean energy but energy poverty. When Indonesia's coal power costs rose 48% and utility subsidies consumed 5% of the national budget, the tradeoff was not coal versus solar — it was coal versus blackouts [4].

Advocates of this position point out that dispatchable solar in Asia is now available at less than $80/MWh with no fuel cost risk, but that deploying it at the scale needed to replace LNG takes years of permitting, grid construction, and manufacturing ramp-up that cannot be compressed into months [17].

Winners and Losers

Coal mining companies have responded immediately. Peabody Energy shares rallied 7.8% on March 24 alone, with analysts noting that the company's Australian mining operations are positioned as "one of the main beneficiaries" of surging Asian demand [6]. Peabody's stock has gained 175% over the past year, outperforming peers by 138 percentage points [18]. Glencore shares have climbed 26% since early January, buoyed by both coal price gains and resumed merger talks with Rio Tinto that would create the world's largest mining company [19].

On the other side of the ledger, clean energy developers face compounding headwinds. In the United States, the One Big Beautiful Bill Act shortened qualification windows for wind and solar tax credits, requiring projects to commence construction by July 4, 2026, or be placed in service by December 31, 2027 [20]. Wind and solar investments in the first half of 2025 had already fallen 18% to $35 billion compared to the same period in 2024, before the Iran crisis added geopolitical uncertainty to the regulatory obstacles [20]. Annual solar, wind, and storage additions between 2026 and 2030 could fall to 30-66 GW, down from a pre-legislation trajectory of 54-85 GW [20].

For coal-dependent communities — in Appalachia, Australia's Hunter Valley, Indonesia's Kalimantan, and India's Jharkhand — the crisis provides a reprieve that previous market signals suggested was ending. Whether that reprieve becomes a structural extension depends on what happens next.

The Lock-In Risk

The central question is whether "temporary" measures become permanent. Historical precedent offers mixed signals.

The 1970s oil embargo prompted lasting shifts: American consumers moved to fuel-efficient Japanese cars and never fully returned to Detroit's gas-guzzlers [21]. But the same crisis also prompted massive investment in coal-fired power that defined the U.S. electricity system for decades. After the 2022 Ukraine energy shock, Europe temporarily increased coal generation but returned to its phase-out trajectory within 18 months as gas supplies stabilized [22].

The current crisis differs in a critical respect: the physical destruction of LNG export infrastructure means the supply gap is measured in years, not months. This creates pressure for long-term contracts, reopened mines, and revised national energy legislation that cannot be easily reversed. Italy's 12-year extension of its coal phase-out deadline was enacted through parliamentary legislation, not executive emergency order [11]. Japan's one-year suspension of coal caps includes no automatic sunset mechanism beyond the stated timeline [3].

Research on energy transitions has found that once coal plants are brought back online, sunk costs and the political economy of energy pricing make them difficult to shut down again [2][21]. The risk is not that governments choose coal over renewables permanently, but that crisis-driven decisions create institutional facts — contracts signed, permits granted, workforces rehired — that slow the transition by years even after the immediate emergency passes.

The 2026 energy shock has forced a choice that energy policymakers had hoped to avoid: between the speed of coal and the long-term economics of renewables. The answer most governments have reached, under duress, is both — and the consequences of that compromise will outlast the war that prompted it.