Key Takeaways
- The May 2026 agreement moves the Ottawa–Alberta framework from a broad alignment to a more actionable plan, with defined milestones for pipeline development and clearer policy commitments supporting execution.
- The agreement also strengthens long-term project economics by establishing a more predictable carbon pricing path and reaffirming that pipeline development remains tied to the Pathways CCUS project.
- The agreement is a modest credit positive for the oil and gas, pipeline, and midstream sectors because greater carbon pricing certainty supports future production growth and related infrastructure demand.
In November 2025, Prime Minister Mark Carney and Alberta Premier Danielle Smith signed the Memorandum of Understanding, which created a framework for future energy infrastructure investment in Canada. The MOU established that a proposed West Coast crude oil pipeline and the Pathways carbon capture, utilization, and storage project are mutually dependent, with neither able to proceed without the other. A newly signed implementation agreement introduces specific timelines, carbon pricing commitments, and procedural milestones, moving the framework closer to implementation.
Building on the November 2025 MOU, the agreement between the federal government of Canada and the provincial government of Alberta represents a transition from high-level alignment to a more defined execution pathway for both a proposed west coast pipeline and the Pathways CCUS project. The proposed pipeline is expected to transport 1 million barrels per day of bitumen produced in Alberta to a coastal terminal in British Columbia for export to customers in Asia.
Pathways is expected to be the world’s largest CCUS project, with the potential to reduce oil sands emissions by 16 million tons annually. According to the Prime Minister’s office, the annual emissions reductions are the equivalent of taking 90% of vehicles off the road in Alberta. The project is expected to generate significant economic benefits totaling C$16.5 billion in GDP, C$12.2 billion in labor income, and up to 43,000 jobs at peak construction.
Implementation Agreement Converts MOU Commitments Into Defined Milestones
The agreement introduces clearer sequencing and accountability mechanisms. Alberta is expected to submit a formal pipeline proposal to the federal Major Projects Office by July 1. The federal government will seek to designate the project as one of national interest by Oct. 1.
These milestones build directly on the MOU’s earlier requirement for a project submission timeline, now providing a more structured pathway toward regulatory approval and project sanctioning. In addition, the agreement introduces an explicit pipeline construction timeline, with the Alberta government indicating that construction may begin as early as Sept. 1, 2027, subject to required approvals.
Carbon Pricing Agreement Anchors Project Economics and Policy Certainty
A central feature of the agreement is the formalization of a long-term industrial carbon pricing path, which is critical for both pipeline approval and the viability of Pathways CCUS. Alberta’s industrial carbon price is set to increase from approximately C$95 per ton through its Technology Innovation and Emissions Reduction credit program to about C$130/t (effective price) and approximately C$140/t headline by 2040. This would require Alberta to increase its effective carbon price over time as part of the broader deal. Beginning in 2030, Alberta will apply a minimum price floor to TIER credits.
This pricing framework builds directly on the MOU commitment to establish a carbon pricing system under Alberta’s TIER program. The agreement therefore operationalizes the carbon framework, providing a clearer signal for long-term capital investment. From a credit and investment perspective, the shift to a defined pricing trajectory addresses the absence of enforceable or quantifiable policy commitments—a key limitation of the MOU.
The agreement represents a compromise, with Alberta securing a lower carbon price trajectory relative to the prior about C$170/t federal framework, while the federal government achieves a materially higher and more credible pricing path than the approximately C$95/t baseline.
The agreement reinforces the MOU’s core structural feature: that pipeline construction remains contingent on the Pathways CCUS project, with Intergovernmental Affairs Minister Dominic LeBlanc stating that both projects “would go ahead together.” This maintains the MOU’s original intention that the Pathways project serves as a necessary condition for pipeline development, providing an avenue for the emissions mitigation needed to secure federal approval.
Expanded Policy Framework Improves Investment Visibility
The agreement introduces greater clarity and improved visibility for investors, even as cost pressures from carbon pricing increase. In addition, carbon pricing design elements, such as price floors and structured escalation, are intended to stabilize carbon markets and provide more reliable investment signals. Nevertheless, tying pipeline construction to progress on the Pathways CCUS project maintains uncertainty. Any new pipeline will need to be contractually supported by shippers, who in turn will have to assess whether new production is economically viable after considering the capital investment required to complete the project.
Implications for the Oil and Gas, Pipeline, and Midstream Sectors
The agreement further strengthens the outlook for large-scale energy infrastructure development, moving beyond conceptual alignment to actionable regulatory and policy steps, demonstrates continued federal–provincial cooperation, and establishes a template linking hydrocarbons infrastructure to emissions mitigation frameworks, which may be replicated in future projects.
While we already recognize carbon and greenhouse gas costs as a relevant factor for oil and gas issuers under the Morningstar DBRS criteria, the agreement provides certainty on industrial carbon pricing. A defined pathway for industrial carbon pricing, combined with a shift away from the previously proposed hard emissions cap, provides more certainty for Canadian oil and gas producers looking to grow production. For pipeline and midstream issuers, this is a modest credit positive because greater certainty around future oil production growth improves the long-term outlook for throughput volumes and infrastructure utilization.
However, significant uncertainties remain despite the latest federal–provincial agreement. Key risks include project execution complexity, the need to secure Indigenous and provincial (notably British Columbia) approvals, as well as ongoing uncertainty regarding the federal ban on oil tanker loading along the northern BC coast. In addition, progress on Pathways CCUS remains critical, particularly given its interdependence with the proposed pipeline. While the agreement provides a clearer policy framework, material steps like regulatory approvals, commercial structuring, and final investment decisions are still outstanding, and substantial work remains before construction can realistically proceed.
Private-sector participation and financing represent another central uncertainty. Both the pipeline and the CCUS project will require significant private capital commitments, which are contingent on durable policy support, regulatory clarity, and commercially viable risk–return profiles. In particular, for CCUS, the scale of required investment and reliance on carbon pricing frameworks and government incentives underscore the importance of sustained policy certainty to attract capital investment.
