Opinion: Shell's LNG Forecast Is Right in the Long Run, and Wrong Right Now

Shell's LNG Forecast Is Right in the Long Run, and Wrong Right Now On June 30, Shell published its annual liquefied natural gas market outlook, projecting that global demand would reach nearly 700 million tons annually by 2050, a 65 percent increase from the 422 million tons traded last year. The timing was almost theatrical. The report arrived four months into the Hormuz crisis, with ICE Endex TTF front-month gas having just surged 7.25 percent to €45.19 on Friday, JKM Asian LNG sitting at $16.07 per million British thermal units, and European storage at 49.2 percent of capacity, well behind seasonal norms, after the worst supply disruption in decades. Shell's numbers look prescient against that backdrop. The demand-security argument underpinning the 65 percent growth case is on display in real time: countries that relied on Qatari supply through Hormuz spent the spring competing for Atlantic Basin cargoes from Corpus Christi and Sabine Pass. European utilities, scrambling to fill a storage deficit that reached 31.4 percentage points below the five-year average as of February, pushed TTF above JKM's dollar equivalent, an unusual inversion in which European buyers outbid Northeast Asian importers for the same swing supply. The geopolitical case for LNG as security of supply, long a theoretical talking point in Shell's annual reports, played out in contract rates and shipping lanes. The problem is what this crisis has done to the supply side of Shell's equation. New LNG terminals require 20-year offtake agreements before they reach a final investment decision. A buyer who watched JKM spike above $25 per million British thermal units in late March 2026, following damage to Qatari export infrastructure and the Hormuz blockade, is not going to sign a long-term contract at anything resembling a crisis price. The rational response to a supply shock, from a buyer's perspective, is to wait for normalization. The forward curve says that is exactly what the market expects: TTF Calendar-2027 settled on Friday at €34.80, a 23 percent discount to the spot print of €45.19. The market has already priced the Hormuz premium as temporary. This creates a specific problem for project developers. The crisis has generated sustained spot prices that make a 20-year offtake agreement look attractive in absolute dollar terms, $10 to $12 per MMBtu above Henry Hub's current $3.25 would produce returns that justify new capacity. But no sophisticated buyer signs a 20-year commitment at a crisis price. They sign when they believe the long-run equilibrium, what gas costs when supply chains have adjusted and Hormuz is open, justifies the commitment. With the forward curve in steep backwardation, the market is telling developers that the equilibrium is materially below current spot. The crisis validates the demand thesis. The same crisis is making buyers unwilling to price that thesis into long-term agreements. A second constraint sits beneath Shell's regional growth assumptions. Southeast Asia is the engine of the 65 percent forecast. Power demand from data centers, industrial parks, and electric vehicles across the region is forecast to grow by more than 100 terawatt-hours over the next three to four years. Bain & Company and Standard Chartered estimated an $18 billion annual shortfall in grid investment across the region through 2035. A cargo of LNG cannot generate power if there is no transmission line to carry that power from the regasification terminal to the consumers Shell is counting on. ASEAN subsea cables require booking deposits two or more years before construction begins, which means infrastructure needed by 2030 requires capital commitment decisions now. Shell is forecasting end-use demand; the 65 percent depends on final investment decisions in LNG terminals and the transmission grids that connect them. None of this means the 2050 forecast is directionally wrong. The structural case rests on energy poverty reduction, coal-to-gas switching, and industrial electrification across South and Southeast Asia, forces that continue regardless of what happens in the Persian Gulf. EU storage is still being rebuilt. Germany sat at 42 percent full on Friday, the Netherlands at just 26 percent. Australia increased gas exploration expenditure by 46 percent year-on-year in the 12 months to March 2026, drawn by the same demand signals Shell documents. The physical case is real. But the supply response to Shell's demand thesis depends on a chain of commercial decisions that the Hormuz crisis has disrupted in sequence. Buyers need to believe in price normalization before they will sign long-term offtake at rates that pencil out for developers. Developers need those agreements before they can commit capital. That chain runs on confidence in the long-run price equilibrium. The forward curve, €34.80 for TTF a year out, nearly €10.40 below spot, reflects a market that expects Hormuz to normalize and European storage deficits to close. If that read is correct, then the crisis price that appears to vindicate Shell is also a temporary distortion that delays the supply investments the 65 percent growth case requires. Shell's annual report is a document about the world as it should be, measured in decades. The Hormuz crisis is a document about the world as it is in mid-2026. The gap between the two is priced, with reasonable precision, in the €10.39 backwardation between TTF spot and TTF Cal+1. That spread is not a contradiction of Shell's thesis. It is a timetable for when the industry will be ready to act on it.