Jack Middleton: Qatar’s LNG crisis proves Canada must build now

Severe disruption has removed ~17% of Qatar’s LNG export capacity (about 12.8 MTPA) for up to five years, a shock Baringa says will keep LNG prices elevated through 2031. Canada currently exports ~14 MTPA (LNG Canada Phase 1) and could materially close the gap if LNG Canada Phase 2 and other projects proceed — NRCAN projects up to 47.5 MTPA of Canadian capacity by 2029. The author urges accelerating resource and mining development (mining revenue forecast $191M in 2026-27; B.C. mining potential ~$90B economic activity) as a strategic move to secure supply chains and allies in the face of geopolitical risk.

Analysis

A persistent premium on low-geopolitical‑risk gas supply will revalue assets that can deliver on multi‑decade contracts out of stable jurisdictions. That revaluation is non-linear: markets pay not just for volume but for certainty, so near‑complete projects, take‑or‑pay tolling structures and shipping capacity with flexible charter coverage will trade at a meaningful multiple premium to greenfield proposals.

Second‑order winners extend beyond liquefaction owners to contractors, specialized LNG shipping owners and midstream operators that can route incremental feedgas into export trunks; conversely, commodity processors with large thermal gas inputs (fertilizer, methanol, petrochemicals) face margin pressure, which will cascade into end‑product spreads and inventories. Base‑metals and critical‑minerals producers also gain optionality as policy and capex redirect toward secure supply chains, tightening lead times on mining permitting and driving earlier FIDs on high‑quality deposits.

Timing matters: spot volatility will dominate days–months on shipping and storage dynamics, while project outcomes (FID, permits, financing) play out over 6–36 months and first production for new greenfield liquefaction is a multi‑year (3–6+) story. Reversal catalysts include a rapid scale‑up of US export capacity, major diplomatic de‑escalation, or an economic slowdown large enough to erode industrial gas demand; conversely, repeated disruptions or faster policy alignment among buyers will harden the premium.

For portfolios, prioritize assets with sunk or near‑sunk capex, strong contract coverage, and low execution risk. Avoid financing/greenfield optionality that looks attractive on paper but is exposed to permitting, Indigenous consent and sharply higher capex; those risks compound and can wipe out multi‑year option value.

Key Decisions for Investors

• Long Enbridge (ENB, NYSE) — buy and hold for 6–18 months: rationale is stable regulated cashflows plus optional upside from higher westbound gas flows. Position size 3–5% NAV; target +25–35% upside, stop loss 15% below entry.
• Long Golar LNG (GLNG, NASDAQ) via 6–12 month call spread to cap cost: buy Sep‑6/12‑month $10 calls, sell $15 calls (adjust strikes to current curve). Shipping tightness is a direct short‑dated driver; call spread limits premium decay while keeping upside exposure. Expect 2–3x return if spot charter rates reprice; max loss = premium paid.
• Long Teck Resources (TECK.B, TSX) or similar diversified base‑metals exposure for 12–24 months: secures upside from accelerated mining FIDs tied to energy/EV metal demand. Target +30–40% upside; downside 20–25% if growth stalls — hedge with modest put protection if conviction is portfolio‑level.
• Pair trade: Long Pembina Pipeline (PPL.TO / PBA.TO) or TC Energy (TRP) 9–18 months, short a large European gas‑intensive utility (e.g., RWE DE) sized 1:1 exposure — rationale is exposure to North American export tailwinds vs. European demand/supply pain. Take profits at 20–30% relative performance divergence; widen hedge if regulatory headlines emerge.
• Event hedge: buy short‑dated calls on US natural gas ETF (UNG) or enter a calendar call spread to hedge portfolio exposure over the next two Northern Hemisphere winters. Protects against tightness-driven spikes while limiting carry; unwind if term curve normalizes or US liquefaction announcements meet FID timelines.