Natural Gas and Oil Forecast: WTI and Brent Slide as Saudi Rerouting Eases Supply Risk

Saudi rerouting and restoration of oil shipments have eased immediate supply-shortage concerns, although East-West pipeline repairs are expected to take 4-6 weeks and full normalization may take months. Strait of Hormuz traffic remains severely constrained at four ships on Thursday versus a 10-day average of 16; the waterway had handled about 21% of global oil and gas shipments before the Iran conflict. J.P. Morgan estimates global oil demand is 4.4 million barrels below last year, helping absorb Middle East supply losses, while Shell estimates war-related gas losses of roughly 36 million tons and tight European storage are supporting LNG demand. Despite a moderately bullish fundamental view for oil and gas, near-term technical signals are bearish: WTI is testing $95.42 support, Brent is approaching $103.26 with potential downside toward $100, and natural gas faces resistance at $2.91.

Analysis

The investable signal is not outright crude scarcity but a wider distribution of outcomes: rerouting preserves aggregate barrels while raising voyage length, insurance, and scheduling friction. That favors product and crude tanker owners such as FRO and STNG before it favors upstream beta, while regional crude differentials and prompt freight rates should react more sharply than flat price. A sustained disruption also shifts refinery economics toward Atlantic Basin barrels, benefiting US export-linked logistics rather than Saudi production volumes.

The demand estimate cited is the critical bearish variable and requires independent verification through IEA/EIA balances, OECD inventories, and Asian refinery runs. If demand is genuinely running materially below prior-year levels, the market can absorb disrupted flows for several months and the geopolitical premium should decay; if inventories begin drawing despite that weak demand backdrop, crude’s upside tail becomes nonlinear. The company commentary on lost LNG supply is similarly insufficient on its own: European storage trajectory, JKM-TTF spreads, and Qatar loading data are the better confirmation set.

For SHEL, higher global LNG and trading volatility can offset upstream volume disruption, but the stock is a less clean expression than US LNG exporters because portfolio exposure includes constrained Middle East supply. US LNG names should gain most over 3-12 months if Europe replaces disrupted regional molecules with Atlantic Basin cargoes; NGS is a later-cycle beneficiary only if stronger export demand translates into US drilling and compression activity. Consensus appears too focused on hourly oil technical levels: the more durable transmission mechanism is freight, LNG basis, and European gas optionality, not a directional WTI call.

Key Decisions for Investors

• Initiate a 1-3 month long FRO or STNG basket, sized at 50-75 bps risk, with a 15-20% target return. Validate through rising VLCC/Suezmax spot rates and longer Gulf-to-Europe voyage distances; exit if Strait traffic and tanker day-rates normalize for two consecutive weeks.
• Prefer long LNG over SHEL on a 3-6 month horizon as the cleaner Atlantic Basin LNG replacement trade. Use a 7-10% stop or reassess if European storage rebuilds faster than seasonal norms and JKM-TTF spreads compress materially.
• Use a defined-risk crude structure rather than outright long exposure: buy 2-3 month WTI put spreads financed only partially by far-out upside calls, preserving disruption-tail exposure while expressing the demand/inventory downside case. Do not add bearish exposure if verified OECD inventories begin sustained draws.
• Keep NGS on watch rather than buy immediately; initiate only after US LNG feedgas demand and Haynesville activity improve together for at least a month. The thesis is falsified if Henry Hub remains weak enough to reduce producer capital budgets despite elevated overseas gas prices.