The Smith-Carney MOU was supposed to be a breakthrough for market access. Four months in, the deal is missing deadlines and lacking private sector interest.
The federal-provincial pipeline memorandum of understanding signed on November 27, 2025, was framed as a generational opportunity. A new Indigenous co-owned oil pipeline to Canada’s West Coast, five potential BC port locations under evaluation, and a framework for durable market access that would outlast political cycles. It was the kind of announcement that moves capital. Four months later, the deal is already slipping.
Deadlines Missed Before the First Shovel
Premier Danielle Smith acknowledged publicly that the April 1, 2026 targets laid out in the MOU have been missed. The next milestone, a formal application for the Northwest Coast Oil Pipeline, is expected by July 1. But the larger problem is harder to fix with a revised timeline. No private company has come forward to build or purchase the project. That is the detail that should concern every Albertan watching this file. Memoranda of understanding are political instruments. They signal intent. They do not move dirt, lay pipe, or generate export revenue. Without a private sector partner willing to deploy capital, this deal remains a press release with a longer shelf life than most.
Alberta’s Market Access Problem Persists
Alberta produces roughly more than four million barrels of oil per day. The province remains overwhelmingly dependent on a single export route to the United States through the existing Trans Mountain and Enbridge Mainline systems. Keystone XL taught the industry what happens when a single route becomes a political hostage. Trans Mountain’s expansion, delivered years late and billions over budget under federal ownership, proved that government-led pipeline development is no substitute for market-driven infrastructure. The MOU contemplated something more ambitious. A new corridor to the Pacific. Access to Asian buyers who are paying premiums for heavy crude. A structural fix to the price differential that has cost Alberta billions in lost revenue over the past decade. But ambition without execution is just noise.
The Regulatory Reality
The regulatory pathway alone should sober anyone expecting fast results. A West Coast pipeline requires federal impact assessments, provincial environmental reviews in British Columbia, marine shipping evaluations, and engagement with dozens of First Nations whose consent frameworks vary enormously. Even with political will in Ottawa and Edmonton, the permitting timeline for a project of this scale is measured in years, not months.
Investment Confidence vs. Commercial Urgency
Capital markets are watching closely. With the Trans Mountain expansion now operational and absorbing incremental barrels, the commercial urgency for a second new Pacific route has shifted. Producers have adjusted their logistics. Rail capacity has expanded. The question facing any prospective builder is whether the demand case justifies the billions in upfront capital when existing infrastructure is no longer at full capacity the way it was in 2018 and 2019. Alberta’s energy sector remains in strong financial shape. Capital expenditures are projected at $18.9 billion for 2026. Major producers are targeting six million barrels per day by 2030. The investment thesis for Alberta oil is intact. But market access remains the single greatest structural vulnerability in the province’s energy economy. And the deal that was supposed to address it is behind schedule before the first shovel touches the ground. The July 1 application deadline matters. If it slips too, the MOU starts looking less like a breakthrough and more like another entry in the long catalogue of pipeline ambitions that never survived contact with Canadian regulatory reality. Alberta has been here before. The province cannot afford to be here again.
Daniel Mercer covers energy and industrial policy for the Alberta Tribune.
