Oil Company Profits Diverge as Iran War Reshapes Energy Markets

The first quarter earnings season for the world's oil supermajors has produced a result that few analysts predicted: in a market where crude prices surged 57% following the U.S.-Israeli attack on Iran that began February 28, some of the industry's biggest names reported massive profit declines [1]. The divergence reveals how the structure of a company's operations — not just the price of oil — determines who profits from a supply shock of historic proportions.

The Scorecard: A Tale of Two Industries

Source: Company earnings reports

Data as of May 7, 2026CSV

The numbers tell a fractured story. Shell reported adjusted net income of $6.92 billion for Q1 2026, beating the $6.1 billion analyst consensus and marking a 24% increase over the same quarter last year [2]. BP's performance was even more dramatic: first-quarter profits more than doubled year-over-year, with the company calling its results "exceptional" [3]. TotalEnergies posted a roughly 29% jump in earnings to $5.4 billion [4].

Across the Atlantic, the picture inverted. ExxonMobil reported $4.2 billion in net income, a 45% drop from $7.7 billion in Q1 2025 [1]. Chevron fared only slightly better, with profits tumbling 36% [1]. Both companies beat reduced Wall Street expectations, but the headline numbers represented a sharp reversal from prior years when higher oil prices reliably translated to higher earnings.

Combined, the six largest European supermajors — BP, Shell, TotalEnergies, Eni, Equinor, and Repsol — earned $21.7 billion in the quarter, 43% more than in Q1 2025. According to Global Witness, "these six fossil fuel giants have not collectively generated this much money since Q4 2022" [5].

Why Rising Prices Hurt Exxon and Chevron

The paradox of falling profits amid soaring crude prices has a specific mechanical explanation. When the Strait of Hormuz was effectively closed following Iran's retaliatory attacks on Gulf shipping infrastructure, ExxonMobil and Chevron lost access to roughly 6% of their global production [6]. Exxon disclosed that about 15% of its total production was impacted by the strait's closure, with operations in Qatar and the UAE delivering significantly lower volumes [7].

Exxon warned that if the strait remains closed for all of Q2, its Middle East production would fall by 750,000 barrels per day compared with 2025 levels [7]. CEO Darren Woods cautioned that "the market has not absorbed the full impact" of the disruption [8].

But the production hit was compounded by a financial one. With energy prices depressed through the first two months of the year — before the February 28 attack — both companies had arranged derivative hedges to protect against further price declines. When prices instead spiked, and the physical delivery of oil from the Gulf became impossible, those hedges generated enormous paper losses. Exxon disclosed $4 billion in "unfavorable estimated timing effects" from its derivatives; Chevron reported $2.9 billion in similar losses [1][7]. Both companies emphasized that these timing effects should reverse in future quarters when the underlying products are eventually delivered.

"If you had to reduce the amount of product that you're selling, you're not going to be able to take advantage of the higher prices," one energy finance expert told ABC News [6].

Shell's Profit Machine: More Than Just Oil Prices

Shell's outperformance raises a question: how much of its earnings surge came directly from the Iran supply disruption versus other factors?

The answer lies largely in Shell's trading division. The company's integrated gas and trading operations generated outsized returns as the war created what analysts describe as "significant crude and refined products dislocations" [3]. Volatility — not just high prices — is what trading desks monetize, and the Iran conflict has produced both in abundance. Shell reported that its oil trading results were "significantly higher" in the quarter [9].

Beyond trading, Shell benefited from stronger LNG pricing. The Strait of Hormuz closure affected not only crude oil but also liquefied natural gas shipments from Qatar, the world's largest LNG exporter. Qatar's LNG export capacity dropped 17%, tightening global gas markets and benefiting Shell's position as the world's largest LNG trader [10].

BP's story was similar. James West, managing director at Melius Research, wrote that "the Middle East conflict created significant crude and refined products dislocations that BP's integrated supply chain was positioned to monetize" [3]. BP's expansive oil trading operation gave it a structural advantage that pure upstream producers like Exxon and Chevron lacked.

The Largest Supply Disruption in History

The International Energy Agency's April 2026 Oil Market Report described the situation in blunt terms: this is the biggest energy security threat in its history [11]. Global oil supply fell by 10.1 million barrels per day to 97 million barrels per day in March, dwarfing every prior disruption on record [11].

Source: IEA, EIA historical data

Data as of May 7, 2026CSV

For comparison, the September 2019 drone attack on Saudi Aramco's Abqaiq processing facility — previously the single largest supply disruption event — temporarily removed about 5.7 million barrels per day. The 2022 disruption from Russian exports following the Ukraine invasion peaked at roughly 3 million barrels per day of lost supply. The 2026 Hormuz crisis has nearly doubled the Abqaiq record [11].

Iran's own production bore the brunt initially. Goldman Sachs estimated that Iran had curtailed as much as 2.5 million barrels per day of crude output by late April, with the prospect of an additional 1.5 million barrels per day in shut-ins by mid-May [12]. Iranian crude exports, which averaged 1.85 million barrels per day in March, fell to roughly 567,000 barrels per day under a U.S. naval blockade [12].

But the disruption extended well beyond Iran. Total OPEC+ supply fell by 9.4 million barrels per day month-over-month, with Saudi Arabia's output dropping from 10.4 million barrels per day in February to 7.25 million in March as attacks on energy infrastructure spread across the Persian Gulf region [11].

Source: FRED / EIA

Data as of May 4, 2026CSV

WTI crude, which had been trading below $60 per barrel in late 2025, crossed $100 in early March and peaked at $126 per barrel. As of early May, WTI sits around $110, up 87.6% year-over-year [13].

Where the Money Went: Buybacks vs. Reinvestment

The three largest European supermajors — BP, Shell, and TotalEnergies — returned a combined $10 billion to shareholders in Q1 2026 through dividends and buybacks [5]. This came as European majors' cumulative profits since Russia's 2022 invasion of Ukraine reached $252 billion [5].

Source: Global Witness

Data as of May 7, 2026CSV

The pattern mirrors — and in some cases exceeds — the shareholder return priorities seen during the 2022 energy price spike. ExxonMobil's management guided to another $20 billion in buybacks for full-year 2026 while maintaining its 43-year streak of annual dividend increases [14]. Suncor boosted planned 2026 share repurchases by over 30% to nearly $4 billion [15]. ConocoPhillips signaled that if elevated oil prices keep free cash flow high, the priority would be "returning more cash to shareholders through buybacks and dividend growth" [16].

California Resources Corporation disclosed a sub-40% reinvestment rate on its exploration and production operations [17]. The industry-wide pattern — described by CNBC as Big Oil having "transformed into shareholder-friendly cash machines" — suggests that the windfall is flowing overwhelmingly to investors rather than to new production capacity or energy transition investments [14].

This capital allocation split stands in contrast to arguments that high oil profits serve a macroeconomic function by funding supply expansion. If companies are returning 60% or more of cash flow to shareholders rather than drilling new wells, the case that windfall profits reduce long-term price volatility through increased production grows weaker.

The Windfall Tax Debate Returns

The profit surge has revived political pressure on both sides of the Atlantic. In the United States, Senator Sheldon Whitehouse and Representative Ro Khanna reintroduced the Big Oil Windfall Profits Tax Act, which would impose a 50% excise tax on the difference between the current price per barrel and the prior year's average [18]. Lawmakers estimate the measure could generate approximately $33 billion annually if oil prices remain at $100 per barrel, with revenue returned to consumers through quarterly rebates [18].

In Europe, finance ministers from Austria, Germany, Italy, Portugal, and Spain have formally asked the European Commission to tax excess profits, echoing the EU's 2022 solidarity contribution — a temporary windfall levy that raised approximately €28 billion from fossil fuel companies [4][19]. Advocacy organizations including Oxfam and the World Wildlife Federation have backed these calls [19].

Russia, meanwhile, has also seen its oil tax revenues climb. Bloomberg reported that the Iran war boosted Russia's April oil tax revenue to a six-month high, an ironic windfall for a country whose own energy exports faced sanctions just four years earlier [20].

The counterargument, advanced by industry groups and free-market economists, holds that windfall taxes discourage the very investment needed to bring prices back down. If producers anticipate that governments will capture upside profits, the incentive to deploy capital for new supply diminishes. The American Petroleum Institute has argued that tax stability is a precondition for the long-cycle investments needed to expand domestic production capacity [18].

There is some evidence for this position: U.S. shale production grew rapidly between 2010 and 2019 in a period of relatively favorable tax treatment, and the resulting supply growth was a key factor in moderating global oil prices. However, the current data on capital allocation — with the majority of cash flow going to buybacks rather than new drilling — complicates this argument. Companies are choosing to return cash to investors rather than reinvest even without a windfall tax in place.

Second-Order Damage: Airlines, Food, and Emerging Markets

The consequences of $100-plus oil extend well beyond the energy sector. Jet fuel prices in North America have spiked 95% since the war began, prompting multiple airlines to raise checked baggage fees and triggering a 176% week-over-week surge in Asia-Europe airfares in mid-March [10][21]. Middle Eastern carriers that suspended operations removed more than 10% of daily international capacity [10].

Fertilizer markets face particular stress. Up to 42% of globally traded urea and 27% of ammonia normally transit the Strait of Hormuz [10]. Since the conflict began, nitrogen fertilizer benchmarks have risen 25 to 50% depending on the product and region [21]. Because fertilizer is a major input cost for corn and wheat production, the U.N. World Food Programme estimates that 45 million additional people — the majority in Asia and Africa — could tip into hunger if the war does not ease by mid-2026 [21].

Shipping costs have compounded these pressures. War-risk insurance premiums for vessels transiting the region spiked from 0.25% to as high as 10% of vessel value [10]. J.P. Morgan analyst Alexia Dogani warned that "freight rates could potentially increase a further 30%, meaning a rise of 65% from February levels" [10].

The semiconductor supply chain faces a less immediate but potentially severe risk. Taiwan depends on Middle Eastern LNG — particularly from Qatar — for power generation. With Qatar's LNG export capacity down 17%, power rationing could disrupt chip manufacturing if the conflict extends into August or September [10].

The World Economic Forum has characterized the broader macroeconomic picture as showing "early stagflationary signals," with reduced business output expectations, lower consumer confidence, and higher near-term inflation expectations across major economies [22]. For oil-importing emerging markets, the combination of higher energy costs and tighter global financial conditions poses risks to GDP growth that could take years to fully materialize.

The Case For and Against Oil Windfall Benefits

Defenders of elevated oil profits make several arguments. First, high prices signal scarcity and should, in theory, incentivize new production that brings markets back into balance. Second, profitable oil companies can fund energy transition projects — several majors have renewable energy and carbon capture divisions that require upstream cash flow to sustain. Third, shareholder returns from oil companies flow into pension funds and retirement accounts that benefit millions of ordinary savers.

The evidence for these claims is mixed. On production investment, the data from Q1 2026 shows companies prioritizing returns to shareholders over new drilling, undermining the supply-expansion argument [14][16]. On energy transition funding, Global Witness has noted that the European majors' cumulative spending on renewable energy remains a single-digit percentage of their total capital expenditure [5]. And while pension fund returns are real, the distributional impact is concentrated: the benefits of higher oil company share prices flow disproportionately to wealthier households with larger investment portfolios.

The strongest version of the pro-profit argument may be a negative one: that windfall taxes create policy uncertainty that deters long-term investment more than the current profit cycle accelerates it. The UK's experience with its Energy Profits Levy, introduced in 2022, offers a partial test case. While the levy raised significant revenue, several companies — including Shell and Equinor — cited it as a factor in reducing North Sea investment commitments [19].

What Comes Next

The Iran conflict's duration remains the dominant variable. If the Strait of Hormuz reopens, prices will likely fall rapidly and the current profit divergence will narrow as Exxon and Chevron recover stranded production and their hedging losses reverse. If the closure persists, the disparities deepen: trading-heavy European majors continue to profit from volatility, while production-heavy American companies face continued volume losses.

Exxon CEO Woods's warning — "there's more to come if the strait remains closed" — applies not just to his company but to the global economy [8]. The 10.1 million barrels per day supply gap is too large for spare capacity elsewhere to fill. Every month of continued disruption compounds the downstream damage to agriculture, transportation, and manufacturing while feeding political momentum for windfall taxation that could reshape the industry's regulatory environment for years.

The oil industry's Q1 2026 results are a stress test revealing which business models thrive in crisis and which falter. The answer — that trading and diversification matter more than production scale when supply chains fracture — carries implications that extend well beyond the current conflict.