On November 27, 2025, the Government of Alberta and the federal government signed a memorandum of understanding that sets out a framework for a new oil pipeline to the West Coast, alongside commitments on carbon capture, electricity grid expansion and faster project approvals. For an Alberta investor, the document is less a construction plan than a signal about where public policy intends to steer capital over the next several years.
The MOU contemplates Alberta applying to the Major Projects Office by July 1, 2026, with a federal commitment to designate the pipeline a national-interest project. It also folds in the Pathways carbon capture initiative and grid expansion, which together describe an industrial agenda rather than a single asset.
The macro backdrop is calmer than it was a year ago. The Bank of Canada held its policy rate at 2.25% on December 10, 2025, after cuts totalling 275 basis points since June 2024. Lower borrowing costs make long-dated infrastructure returns easier to underwrite, but they do not remove the execution, regulatory and political risks that have historically shaped Canadian energy infrastructure.
Key Takeaways
- The November 27, 2025 MOU sets a framework for a West Coast bitumen pipeline, Pathways carbon capture, grid expansion and faster approvals, not a financed project
- Alberta is expected to apply to the Major Projects Office by July 1, 2026, with a federal commitment to a national-interest designation
- Opportunity spans midstream, carbon capture, power generation and transmission, and the service businesses that support all three
- Execution and political risk remain substantial, so investors should stage capital rather than price in outcomes that are still years away
- With the Bank of Canada holding at 2.25%, financing conditions favour patient, well-structured positions in supporting infrastructure
What the MOU Commits To, and What It Does Not
A memorandum of understanding is a statement of intent between governments. The November agreement describes a framework for a new pipeline carrying bitumen to Asian markets through the West Coast, support for the Pathways carbon capture project, expansion of the electricity grid, and a commitment to faster regulatory approvals. It sets a date, July 1, 2026, by which Alberta is to apply to the Major Projects Office, and records a federal commitment to designate the pipeline a national-interest project under the Building Canada Act, which became law in June 2025.
What the MOU does not do is name a proponent, fix a route, specify a capital cost, or arrange financing. Those elements come later, and they are where most of the value and most of the risk sit. Commercial commitments from shippers, Indigenous participation, cooperation along the route, and a construction plan that survives cost inflation all remain to be settled.
The practical reading is that the province and Ottawa have narrowed their disagreements and set a process in motion. That matters because process has been the binding constraint on Canadian energy infrastructure for more than a decade. It is not yet a reason to reprice midstream assets as though a new export corridor were operating.
Midstream and the Export Corridor Question
The case for a second West Coast outlet rests on the experience of the first. The Trans Mountain Expansion entered commercial service on May 1, 2024, lifting capacity by 590,000 barrels per day to 890,000 barrels per day, at a total project cost of about $34 billion. Yet the United States still took roughly 93.8% of Canadian crude exports between May 2024 and April 2025, a reminder of how concentrated the customer base remains and how long diversification takes.
For midstream investors, the MOU raises two distinct questions. The first is whether a new line will be built, and when. The second, which is more immediately investable, is what happens to existing gathering, storage, terminalling and rail assets while the answer is pending. Producers who anticipate more export capacity tend to invest in upstream volumes and in the logistics that connect them to trunk lines, and those supporting assets can generate contracted cash flow well before any new pipeline is sanctioned.
The prudent posture is to favour assets whose returns do not depend on the new corridor being completed but would improve if it were. Storage and blending capacity, regional pipelines feeding existing systems, and terminal infrastructure at tidewater fit that description. Investments whose thesis begins and ends with a sanctioned West Coast line are, at this stage, a bet on politics as much as on engineering.
Pathways and the Carbon Capture Opportunity
Including the Pathways carbon capture project in the MOU ties the pipeline conversation to the emissions conversation, which is how it will be judged by investors, export customers and the federal government alike. Carbon capture, utilization and storage in Alberta benefits from favourable geology, an existing industrial base and a regulatory system that has approved storage hubs.
Two policy facts shape that framework at the end of 2025. Alberta froze its industrial carbon price under the TIER system at $95 per tonne on May 12, 2025, citing U.S. tariffs, which reduces the near-term economic pull toward abatement but provides certainty. Federally, Budget 2025 on November 4 introduced a productivity super-deduction that includes immediate expensing for clean energy generation equipment. Investors evaluating CCUS-adjacent businesses, from compression and fabrication to monitoring and engineering, should model outcomes under a range of carbon-price and incentive assumptions and consult their tax advisors on how the new measures apply to specific assets.
Power, Grid and the Supply Chain Behind the Headlines
Generation and transmission
Grid expansion is the least glamorous element of the MOU and possibly the most durable. Alberta’s electricity demand is being pulled upward by industrial electrification, carbon capture facilities that consume significant power, and the province’s AI data centre strategy, which targets $100 billion of private investment over five years and favours a bring-your-own-power model. Investors who prefer regulated or contracted returns will find the grid strand easier to underwrite than the pipeline strand.
Services and fabrication
Every large project produces a long tail of demand for engineering, fabrication, camp services, environmental consulting, trucking, equipment rental and skilled trades. Many of the businesses supplying these services are privately held Alberta companies with owners approaching retirement. That combination of rising demand and ownership transition creates opportunities to acquire or finance service businesses at valuations reflecting current activity, with upside if the policy agenda delivers.
Indigenous partnership capital
Meaningful Indigenous participation has become a condition of major projects in Alberta. The Alberta Indigenous Opportunities Corporation has loan-guarantee capacity of up to $3 billion, with guarantees of $20 million to $250 million per project, and the federal Indigenous Loan Guarantee Program was doubled to $10 billion in March 2025, supporting $20 million to $1 billion per transaction. Investors should expect Indigenous equity in the ownership of any project that emerges from the MOU, and should view partnership quality as a marker of regulatory and social durability.
Execution and Political Risk
The gap between an MOU and an operating asset is measured in years and in multiple points of failure. The Major Projects Office, formed on August 29, 2025 and based in Calgary, exists to shorten approval timelines for national-interest projects, but a designation does not eliminate consultation obligations, environmental assessment or litigation. Cost escalation is the other constant; Trans Mountain’s roughly $34 billion final cost is the reference point every lender and equity investor will use when evaluating a new line.
Political risk operates on several levels. Governments change, and so do their priorities. Trade relations with the United States, which absorbed the vast majority of Canadian crude over the past year, influence both the urgency of diversification and the economics of the assets that would serve it. Investors should treat the MOU as one scenario among several and ask what a position earns if the pipeline is delayed by five years or never proceeds.
Execution risk also sits inside the businesses that would supply a build. Labour availability, wage inflation and the sequencing of several large projects, including LNG, data centres and carbon capture, could strain the same pool of trades and contractors at once.
Positioning a Specialty Portfolio for a Multi-Year Build
A multi-year policy agenda argues for staged capital rather than a single large commitment. The first stage is to identify assets and businesses that earn acceptable returns under current conditions and carry embedded optionality if the MOU’s projects advance. The second stage, after the July 2026 application and any designation, is to reassess with better information about proponents, routes and financing. The third would follow commercial commitments from shippers, when project-level investment becomes a question of terms rather than of existence.
Financing conditions support this patience. With the policy rate at 2.25% following the December 10 hold, the cost of debt for well-structured infrastructure and services businesses is materially lower than it was through 2023 and the first half of 2024. Lenders in Alberta, including the chartered banks, ATB Financial, credit unions and private credit providers, have appetite for contracted cash flow, which can be used to build positions with prudent leverage while equity is reserved for the higher-return opportunities a sanctioned project would create.
Pragma Capital’s view is that the November MOU improves the odds of a stronger Alberta energy and power economy over the next decade without guaranteeing any single outcome. Investors who match their horizon to the policy timeline, favour assets with independent cash flow, and build partnerships with Indigenous communities, lenders and operators will be positioned to benefit if the framework delivers, and protected if it stalls. Owners and investors should consult their legal, tax and financial advisors before committing capital to any strategy discussed here.