Internal Market Brief

CONTANGOCOMMODITY MARKETING INC.

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INTERNAL MARKET BRIEFWEEK OF JUN 8 – JUN 12, 2026

WTI fell $8.62 on the week to $84.38 — and to ~$80 Monday — as a U.S.–Iran deal to reopen the Strait of Hormuz took shape. Western Canadian Select tightened on an oil-sands crunch; AECO and Henry Hub held steady.

Published June 15, 2026Contango Commodity Marketing Inc.

What
matters

WTI fell −$8.62 on the week to $84.38 and to ~$80 Monday as the U.S. and Iran reached an initial deal to reopen Hormuz (MOU signs Friday). The geopolitical premium is unwinding — but the blockade only lifts over 30 days, normalization may take 60–90 days, and Netanyahu has rejected the Lebanon clause. Physical stays tight: a 7th straight U.S. draw, SPR at a 2023 low, OPEC at 16.13 MMb/d, and an oil-sands crunch firming WCS to −$11.40.

Headlines this week

• U.S.–Iran reach an initial peace deal; MOU signs Friday in Switzerland, Hormuz to reopen within 30 days
• WTI −$8.62 on the week to $84.38; ~$80.32 Monday on deal optimism
• OPEC output at a multi-decade low of 16.13 MMb/d; Iran exports a six-year low
• U.S. crude draws 7.2 MMb/d — a 7th straight; SPR lowest since Aug 2023
• Russian Urals flips to a $2–3/bbl discount in Asia as acute tightness eases
• Oil-sands crunch (Cenovus outage + Alberta floods) tightens WCS to −$11.40
• AECO steadies at $1.73; NGTL plans a 62% FT-R capacity cut Jun 16–20
• Henry Hub ~$3.12; U.S. gas storage +108 Bcf to 2,686 Bcf

At a glance

Weekly Snapshot

Settlements for the week ended Friday, June 12, 2026. Prices in USD/bbl; differentials vs dated Brent. Deltas are week-on-week unless noted.

Crude & Structure

WTI / BRENT

WTI (Fri settle)$84.38−$8.62 wk

Brent (Fri settle)$87.33−3.37%

WTI low sinceApr 17

Prompt spread (benchmarks)$1–1.50flattened

Urals vs Brent (Asia)−$2 to −$3from +$7-8

Term structureeasing

Supply & Inventories

OPEC / EIA

OPEC output (May)16.13 MMb/d−1.06 MoM

U.S. crude stocks−7.2 MMb/d7th draw

SPR levelAug-2023 low−79 MMbbl

U.S. crude exports (May)10.5 MMb/d#1 exporter

Refinery utilization95.3%seasonal high

Gulf product exports (Jun)>600 kb/d+~50%

Section 01 · Crude Oil

WTI — Deal Optimism Overrides an Intact Blockade

WTI settled the week at $84.38 USD/bbl on Friday, its lowest since April 17 — a weekly decline of $8.62 — as a sharp late-week reversal reflected confidence that an imminent U.S.–Iran memorandum would end the war and reopen the Strait of Hormuz.

Update
Jun 15

WTI is trading lower at ~$80.32 Monday after the U.S. and Iran reached an initial agreement to end hostilities and reopen Hormuz — a 14-article MOU to be signed Friday in Switzerland (naval blockade lifted within 30 days, Iranian-oil sanctions suspended, Strait reopened within 30 days under Iranian arrangements). Caveats: the nuclear dispute is unresolved, Tehran keeps leverage over the Strait, Netanyahu rejects the Lebanon clause, and full tanker normalization could take 60–90 days.

• Tracked U.S.–Iran headlines all week: Tue sell-off on a reported strike pause; Wed reversal on fresh strikes near Hormuz + a far-larger-than-expected U.S. draw; Fri slide on deal optimism after Washington stood down Thursday.
• Hormuz naval blockade still intact — market in limbo awaiting a resolution.

WTI Daily Settles — Jun 8–15, 2026

Prompt month, USD/bbl · Fri settle $84.38 (−$8.62 wk) · Mon ~$80.32 on the U.S.–Iran deal

Mon: Hormuz blockade intact; market in limbo awaiting a U.S.–Iran resolution · Tue: reported pause in strikes → sell-off · Wed: fresh strikes near Hormuz + larger-than-expected U.S. crude draw → reversal · Thu: Washington calls off planned strikes late in the session · Fri: deal optimism accelerates losses; settles $84.38, lowest since Apr 17 · Mon (6/15): initial U.S.–Iran deal reached; WTI ~$80.32, MOU to sign Fri in Switzerland

Fig 1WTI daily settles with key catalystsSource: NYMEX settlements, internal compilation

Supply: OPEC at a Multi-Decade Low, Iran Blockaded

• OPEC output −1.06 MMb/d MoM to 16.13 MMb/d — lowest since at least 2000, below the COVID-era trough.
• Iran led the drop; the blockade cut crude + condensate exports to a six-year low.
• ‘Dark transits’ (AIS off) free some trapped barrels but don’t restart shut-in Gulf production.

Fig 2Hormuz transits adjusted for dark-transit estimatesSource: Commodity Context, Kpler

Fig 3OPEC crude output (MMb/d) — multi-decade lowSource: Reuters survey

• Replacement barrels clearing at discounts as the acute tightness eases.
• Russian Urals flipped to a $2–3/bbl discount in Asia (from a $7–8 premium in Apr–May); Saudi cut its Arab Light OSP again.
• Term structure flattened: prompt spreads ~$2–3 → ~$1–1.50/bbl.

Fig 4Russian Urals premium / discount to dated Brent in Asia (USD/bbl)Source: Bloomberg

Domestic: A Seventh Straight Draw, Record Exports

• U.S. commercial crude −7.2 MMb/d (wk Jun 5) — 7th straight draw, lowest since mid-Feb, well beyond the ~4 MM expected.
• With the SPR, stocks −79 MMbbl since late Feb; SPR lowest since Aug 2023.
• Exports 10.5 MMb/d in May — world’s #1 exporter for a 3rd month.
• Product side tight; Gulf refiners running at 95.3% utilization.

Fig 5Weekly U.S. ending crude stocks (ex-SPR) vs. 5-yr range — thousand bblSource: EIA

Total gasoline (thousand bbl)

Distillate fuel oil (thousand bbl)

Fig 6U.S. product stocks vs. 5-yr range — structurally tightSource: EIA

Desk angles

DEAL RISK

Risk Premium Unwind — But Not Overnight

The MOU lifts the blockade over 30 days, but shipowner caution, elevated war-risk insurance and logistics mean tanker traffic likely takes 60–90 days to normalize. Flat price can keep pricing the deal while physical stays tight in the interim.

FRAGILITY

Watch the Lebanon Clause

Netanyahu has already rejected the Lebanon pillar and the nuclear dispute is unresolved — the two cleanest ways for the deal to wobble and snap the premium back. A failed or delayed Friday signing is the key upside tail.

REL-VALUE

Tight Physical vs. Soft Flat Price

A 7th straight U.S. draw, SPR at a 2023 low and WCSB inventories at 2020 lows argue structural tightness even as headlines pull flat price down — favouring WCS basis and time-spreads over outright length here.

STRUCTURE

Term Structure Says the Squeeze Is Easing

Prompt spreads flattened from ~$2–3 to ~$1–1.50/bbl and Urals flipped to an Asian discount — the acute scarcity that defined the conflict’s opening is loosening, consistent with the deal narrative.

Desk
view

The deal is now in hand (Mon ~$80), so the geopolitical premium is unwinding — but it isn’t fully out. Bias: fade rallies into Friday’s signing, but respect the 60–90-day normalization lag and a fragile Lebanon / nuclear backdrop. Levels: $80 Mon low · $84.38 Fri · ~$93 pre-sell-off resistance. Producers: use any deal bounce to add downside protection; the cleaner tightness expression is WCS basis and time-spreads, not flat price. Watch the Friday signing, the Lebanon clause, and Hormuz transit counts.

Risk scenarios — WTI path (post-deal)

Scenario	Trigger	WTI path
Bull / deal unravels	Lebanon clause or nuclear dispute breaks the MOU; blockade persists	$95–110, premium snaps back
Base / slow reopen	MOU signs Fri; flows normalize over 60–90 days; near-term draws persist	$76–84, drifting lower
Bear / clean reopening	Hormuz reopens smoothly; trapped barrels + OPEC restarts flood the market	Sub-$75

Storylines

GEOPOLITICAL

U.S.–Iran Peace Deal

The U.S. and Iran reached an initial agreement to end the war and reopen Hormuz, with a formal MOU to be signed Friday in Switzerland. Trump said the Strait would open toll-free and the naval blockade would end — unwinding the risk premium built over the three-plus months that ~a fifth of global oil and LNG supply was blocked.

HORMUZ

Shipowners Eye Hormuz Reopening

With a deal reportedly near, tanker owners are split between caution and a demand surge; ~127 tankers sit inside the Gulf with more waiting outside. Estimates of current "dark" flows vary widely — ~4 MMb/d to Energy Secretary Wright's 7 MMb/d — against a pre-war norm near 20 MMb/d.

RUSSIA

Urals Flips to Asian Discount

Russian Urals has flipped to a discount to dated Brent at Indian and Chinese ports as Asian refiner demand falls. July/August cargoes to India traded $2–3/bbl below dated Brent, down from a $7–8 premium in April–May; some Chinese buyers refused June cargoes outright.

U.S. SUPPLY

U.S. Crude Draw Surprises

U.S. crude inventories fell 7.2 million barrels in the week ended June 5, far beyond the ~4 million expected, as refiners ran at 95.3% to fill product gaps. Including the SPR, crude stocks have dropped 79 million barrels since the conflict began — the lowest strategic-reserve level since August 2023.

DEMAND

China Taps Strategic Reserves

China began drawing on its oil stockpiles in May — estimated at 1.2–1.3 billion barrels pre-war — and is expected to pull ~1 MMb/d from reserves rather than chase prompt cargoes. Crude imports fell to their lowest since October 2017, prompting Beijing to ease a directive forcing independents to run hard.

OPEC

OPEC Output Hits Multi-Decade Low

A Reuters survey found OPEC output fell 1.06 MMb/d in May to 16.13 MMb/d, the lowest since at least 2000, as the U.S. blockade and Hormuz closure cut Gulf exports. Iran posted the steepest drop, with crude and condensate exports at a six-year low.

PRODUCTS

Gulf Fuel Exports Rebound

Gulf refined-fuel exports rebounded as more tankers slipped through Hormuz, easing a squeeze on Europe and Asia. Saudi, UAE and Kuwaiti product shipments averaged more than 600,000 bpd in June per Vortexa — up ~50% from April/May, but still a fraction of the ~4 MMb/d shipped pre-war.

Section 02 · Western Canada

Canadian Differentials — Oil-Sands Crunch Splits the Complex

Oil-sands disruptions and water issues defined the week — splitting the condensate complex while tightening heavies and synthetic crude.

• Flooding in northern Alberta + a Cenovus power outage (Foster Creek/Christina Lake) curtailed oil-sands output — ~10% of Cenovus offline.
• Diluent C5s (PCE NAM, FSPL, CRW) loosened on weaker diluent demand and returned volumes.
• C5-PEM and SYN tightened — PEM lifted as a blend substitute for constrained synthetic supply.
• Heavies firmed: WCS tightened to −$11.40 (from ~−$16 earlier in June); WCSB inventories lowest since 2020.
• SYN July the standout — up to +$4.50, ending at/above the +$4.30 index strip.

Fig 7WCS trading — June vs. July weighted-average diff (USD/bbl)Source: Contango Commodity Marketing

July indicative index — Western Canadian grades (USD/bbl vs WTI)

Grade	July diff	Note
SYN (synthetic)	+$4.30	standout; upgrader supply constrained
C5-PEM (sweet)	−$1.30	tightened as SYN blend substitute
C5-PCE (sweet)	−$1.40	recovered into Friday
PSO / CAL (med sour)	−$3.50 / −$3.80	tightened on the week
C5-PCE NAM (diluent)	−$7.70	diluent demand soft
WCS / CHV (heavy)	−$11.40 / −$11.60	tighter than ~−$11.70 index

Tbl 1July indicative indexSource: Contango Commodity Marketing

Storylines

OIL SANDS

Canadian Oil-Sands Supply Crunch

Heavy rain in northern Alberta and a Cenovus power outage at Foster Creek and Christina Lake curtailed oil-sands output — ~10% of Cenovus offline. Western Canadian crude inventories fell to their lowest since 2020, tightening supply to Cushing and narrowing the WCS–WTI differential.

Section 03 · NGLs

Fort Saskatchewan Fractionation Build-Out

A wave of fractionation expansion is set to add 145 Mb/d of new capacity at Fort Saskatchewan by 2029 — lifting installed capacity from 391 to ~536 Mb/d.

• CSV Midstream — new 35 Mb/d plant (FID early 2027, startup 2029).
• Pembina Redwater 4 +55 Mb/d and Keyera FS II debottleneck +8 Mb/d — online this month.
• Keyera FS III +47 Mb/d — mid-2028.
• Combined +145 Mb/d by 2029, taking capacity 391 → ~536 Mb/d.

Fort Saskatchewan planned fractionation expansions

Project	Start-up	Mb/d
Pembina — Redwater 4 (RFS4)	Q2 2026	55
Keyera — Fort Saskatchewan II debottleneck	Jun 2026	8
Keyera — Fort Saskatchewan III	Mid-2028	47
CSV — Fort Saskatchewan	2029	35
Total announced		145

Tbl 2Announced fractionation capacitySource: RBN Energy

Section 04 · Natural Gas — WCSB

AECO Steadies as NGTL Recovers

AECO ended the week at $1.7327 CAD/GJ (−$0.10 wk) in a tight $0.07 range as NGTL field receipts recovered and linepack finally moved above target.

• NGTL field receipts +~1 BCF/d; linepack finally above target.
• Westcoast Alberta-East outage ended — ~0.2 BCF/d restored at Gordondale.
• ~0.7 BCF/d still off for turnarounds, set to return this week.
• Storage flipped to injections (~0.5 BCF/d); West Gate +0.6 BCF/d.

Watch

NGTL maintenance: a cut to 62% FT-R capacity (no IT) on Segments 2, 5 and partial 9 runs Jun 16–20 — one of the largest on the system; operators may see higher-than-normal pressures.

Fig 8NGTL field receipts (MMcf/d) — back to mid-5-yr levelsSource: Contango Commodity Marketing

Fig 9Willow Valley interconnect (MMcf/d) — erratic pullsSource: Contango Commodity Marketing

Storylines

WEATHER

Canada Weather Pattern Shifts

An upper-level trough stalls over northern Ontario and western Quebec — cooler, unsettled weather in the east while heat builds across the west; B.C. warmer and drier into early next week.

LNG

Ksi Lisims Gains Interest

Germany’s Uniper signed a letter of interest for 2 Mtpa from the proposed 12-Mtpa Ksi Lisims floating LNG project (deliveries as early as 2032), following a recent 20-year deal with SEFE.

Section 05 · Natural Gas — U.S.

Henry Hub Steady at $3.12 as Storage Builds

Henry Hub held in a ~10-cent range and settled near $3.12 USD/MMBtu as a +108 Bcf injection lifted working gas to 2,686 Bcf.

• Storage +108 Bcf to 2,686 Bcf — 151 Bcf (6%) above the 5-yr average, 5 Bcf below last year.
• Injections led by Midwest (+37), East (+34), South Central (+28).
• Lower-48 production eased in June; LNG feedgas down on maintenance.
• Developing El Niño a volatility wildcard for cooling demand and crops.

Fig 10U.S. working gas in storage (Bcf) vs. 5-yr averageSource: EIA

Storylines

STORAGE

Storage Injection Builds

U.S. working gas rose 108 Bcf for the week ended June 5 to 2,686 Bcf — slightly below last year but 151 Bcf above the five-year average and within the historical range.

U.S. LNG

Delfin FLNG Approved

Regulators approved Delfin Midstream’s floating LNG terminal off Louisiana — the first of its kind in U.S. waters. FID came in early June with output expected 2029–2030, most of the first vessel already contracted.

ASIA

Asian LNG Demand Recovers

Asian LNG demand is rebounding after the loss of Qatari supply, with June arrivals set for a five-month high — China back in the spot market, Japan lifting imports, and India sourcing from Angola, Nigeria and the U.S.

Contango Commodity Marketing Inc.
Unit 201 – 805 1st Street SW
Calgary, Alberta  T2P 1N1
info@contangomarketing.ca

Prices, balances and differentials are sourced from Contango Commodity Marketing Inc., the EIA, Kpler, Vortexa, Bloomberg, Commodity Context and Reuters. While care is taken to ensure accuracy, figures are indicative and subject to revision. This brief is provided for information only and does not constitute trading, hedging or investment advice.