Brent Crude Settles at $73.44 on Last Day of H1 2026 With Morgan Stanley Cutting to $75 and EIA Forecast $21 Higher

WTI crude settled at $69.50 per barrel on Tuesday's CME close, down $1.25 or 1.77% on the day, while Brent settled at $73.44 on Tuesday's ICE close, down $0.47 or 0.64%, per OilPrice.com end-of-day data. Both benchmarks closed the first half of 2026 below the levels major forecasters projected at the start of June. The Strait of Hormuz has begun reopening ahead of the EIA's Q3 2026 target, pulling prices well below the agency's $95 Brent baseline.

A $21 Gap Between the EIA Baseline and Tuesday's Market

The EIA's June 9 Short-Term Energy Outlook forecast Brent crude at an average of $95 per barrel for 2026. That forecast rested on an explicit assumption that the Strait of Hormuz would remain "effectively closed in the near term," with shipping resuming only in Q3 2026. Morgan Stanley has already moved past that assumption, cutting its Brent price target to $75 per barrel for the next 18 months and citing Hormuz supply availability as the primary catalyst. With Tuesday's Brent settlement at $73.44, the market has moved $1.56 below even Morgan Stanley's revised target and $21.56 below the EIA's June baseline.

The Brent benchmark faces simultaneous structural pressure from a separate direction. As Oil Authority reported, no Brent crude cargoes are scheduled to load in August 2026, the first time in recorded history that the original North Sea Brent field has gone a month without a loading. That North Sea supply squeeze applies upward structural pressure on Brent pricing, yet the Hormuz-driven supply surplus is overriding it at Tuesday's close.

Middle East Supply Return Overwhelms the API Inventory Draw

The EIA's June STEO noted that Middle Eastern crude production fell by more than 11 million barrels per day compared to pre-conflict levels, equivalent to roughly 10% of global daily supply. The American Petroleum Institute reported U.S. crude inventories fell 6.072 million barrels for the week ending June 26, a signal that would normally support prices. At a 10% recovery rate for offline Middle Eastern production, however, 1.1 million barrels per day of new supply re-enters the market, a volume sufficient to offset the entire API weekly draw in fewer than six days.

Libya added supply pressure independent of the Hormuz dynamic. Output reached a 13-year high near 1.5 million barrels per day, with the National Oil Corporation targeting 2.1 million barrels per day within three to five years, a potential 600,000-barrel-per-day addition to global supply. Libya operates outside strict OPEC+ quota enforcement, making its production additions structurally persistent rather than subject to the compliance mechanisms governing Gulf producers.

Dallas Fed Survey Captures Producer Anxiety

The Dallas Fed Energy Survey for Q2 2026, published Tuesday, captured the mood of Texas basin producers. One exploration and production company executive stated that "markets can price risk, but they can't price a tweet," a reference to the geopolitical volatility that has defined 2026 crude trading. Rapid policy shifts in U.S.-Iran relations drove the Hormuz crisis and its resolution within a single quarter, leaving producers unable to calibrate capital spending to prices that move on diplomatic signals.

Natural Gas Diverges From Crude Benchmarks

Natural gas moved counter to crude on Tuesday. Henry Hub settled up $0.094 or 2.96% at $3.275 per MMBtu on Tuesday's CME close. The EIA's June STEO projected an average Henry Hub price of $3.60 per MMBtu for full-year 2026, placing the gas market meaningfully closer to agency projections than crude, which has settled $21.56 below the EIA's 2026 baseline.

WCS Discount and Alberta Operator Margins

Western Canadian Select crude was last quoted at $58.40 per barrel per OilPrice.com, though that figure carries an approximately 16-hour reporting lag. At the implied WCS-WTI differential of roughly $11.10 per barrel, Canadian oil sands operators face compounding pressure from lower absolute prices and a persistent heavy crude discount. Trans Mountain Pipeline expansion, which entered service in 2024, has held the WCS-WTI spread tighter than the $20-plus differentials common in 2023, providing structural but partial relief. At current levels, major oil sands producers including Suncor Energy and Canadian Natural Resources retain positive operating cash flow on most projects, though softer crude prices compress margins when CAD-denominated operating costs remain fixed.