ENERGY

The Feedback Loop: How Canada Is Paying $35 Billion to Replace Half the Pipeline Capacity It Lost

Companion to "How Canada Built an Energy Bottleneck From Both Sides" (March 2026)

Published July 3, 2026 · 24 sources · 12 min read

Aerial illustration of a single translucent pipeline filled with Canadian currency stretching across boreal landscape toward the Pacific coast, with three faded ghost-outline pipelines running parallel but broken and dissolving into the terrain

THE RECEIPTS Energy · Captive Cost

The pipeline capacity that private capital was willing to build has been replaced by a structure in which substantially all disclosed pre-FID risk rests with public entities, at several multiples of the original cost per barrel.

Between 2006 and 2021, three privately financed pipeline projects proposed to move approximately 2.5 million barrels per day of Canadian crude to new export markets: Northern Gateway to the Pacific, Energy East to the Atlantic, and Keystone XL to the U.S. Gulf Coast. Two had binding shipper commitments in place. Combined projected cost: roughly C$20 billion plus US$8 billion in private capital. Two were cancelled through Canadian regulatory or political pathways and one through U.S. presidential action. A fourth, Trans Mountain, was rescued by the federal government in 2018 after Kinder Morgan walked away from the construction risk. The final public cost reached C$34.2 billion. (See: The Feedback Loop, March 2026.) [23]

On July 2, 2026, Canada and Alberta announced the West Coast Oil Pipeline: 1 million barrels per day along a southern corridor to the B.C. coast. No private company has been publicly identified as majority sponsor or lead proponent. The only disclosed private participant, Pembina Pipeline Corporation, holds a 10 percent economic interest with full discretion over any final investment decision and zero capital at risk before that decision is made. No binding shipper commitments, toll rates, break-even analysis, or exit strategy have been published in any document reviewed. If the pipeline proceeds at the reported C$35 billion working estimate, total public capital committed to west-coast pipeline infrastructure would approach C$74 billion, delivering less than half the capacity that private capital once proposed, at roughly C$39,000 to C$46,000 per barrel per day of capacity.

This article documents the ownership structure, capital exposure, and risk allocation of Canada's proposed West Coast Oil Pipeline. It does not attribute motive to any government or private actor.

Sources and methodology below.

~2.5M bpd

Cancelled private pipeline capacity: Northern Gateway + Energy East + Keystone XL

C$34.2B

Final all-in cost of Trans Mountain Expansion, 6.3× the original C$5.4B estimate

Published binding shipper commitments for the West Coast Oil Pipeline

~C$39K/bpd

Capital intensity of publicly sponsored west-coast capacity, if reported C$35B estimate holds

Full analysis · 24 sources · 12 min read

2.5 Million Barrels a Day of Private Pipeline Capacity

Before the federal government purchased Trans Mountain in 2018, private companies had proposed to build roughly 2.5 million barrels per day of new Canadian export pipeline capacity. The projects were distributed across three corridors, each backed by an identified corporate proponent willing to commit development capital and, in most cases, binding long-term transportation agreements. [1] [2] [3]

Northern Gateway, proposed by an Enbridge subsidiary, would have carried 525,000 barrels per day of crude from Bruderheim, Alberta, to a marine terminal at Kitimat, B.C., for export to Asian markets. The projected cost was C$7.9 billion. Enbridge and ten partner energy companies invested more than C$450 million developing the proposal. The NEB's Joint Review Panel recommended approval with 209 conditions in December 2013. [10]

Energy East, proposed by TransCanada (now TC Energy), would have transported 1.1 million barrels per day from Alberta and Saskatchewan to a marine terminal in New Brunswick, opening Atlantic and European export routes. The projected cost was approximately C$12 billion. By 2013, TransCanada reported that it had secured legally binding shipper commitments covering roughly 900,000 barrels per day. [14]

Keystone XL, also a TC Energy project, would have moved 830,000 barrels per day from Alberta to the U.S. Gulf Coast. The cost was reported at roughly US$8 billion. Shippers on the existing Keystone system committed to renewed 20-year contracts with a cost-sharing mechanism for any gap between estimated and actual project costs. [15]

A fourth project, the Trans Mountain Expansion, was proposed by Kinder Morgan to add approximately 590,000 barrels per day to the existing Trans Mountain system. The 2013 application estimated the cost at C$5.4 billion and identified 708,000 barrels per day of firm shipper commitments from thirteen companies. [24]

Collectively, private capital proposed to build more pipeline export capacity than the Canadian oil industry had ever requested at one time, across three compass points, with identified revenue structures. None of it was completed under private ownership.

Three Pipelines Cancelled. One Rescued. C$2.4 Billion in Private Capital Lost.

Northern Gateway was approved by the NEB in 2014. In June 2016, the Federal Court of Appeal overturned the approval on the grounds of insufficient Indigenous consultation. In November 2016, the federal government directed the NEB to dismiss the application and formally cancelled the project. The Northern Coast Tanker Ban, legislated in 2019, closed the Kitimat corridor to crude tanker traffic. Enbridge recorded a C$373 million impairment charge. [13]

Energy East was filed in October 2014. In August 2017, the NEB expanded the scope of its review to include assessments of upstream greenhouse gas emissions from production that would flow through the pipeline. TransCanada requested a 30-day suspension of the application in September 2017 and terminated the project the following month. The company recorded a C$954 million after-tax impairment charge. Its termination statement did not attribute the withdrawal to a single factor. [14]

Keystone XL followed a different path. President Obama rejected the presidential permit in 2015. President Trump reinstated it. President Biden revoked it on January 20, 2021. TC Energy terminated the project on June 9, 2021, and reported a net financial impact of approximately US$1.1 billion after recoveries, insurance, and Alberta government support. Unlike Northern Gateway and Energy East, Keystone XL was cancelled by a foreign government, not by Canadian regulatory or policy action. [15]

Trans Mountain followed a fourth pattern. After the Federal Court of Appeal quashed the project's approval in August 2018 on Indigenous consultation and environmental review grounds, Kinder Morgan announced it would not proceed without certainty. The federal government purchased the pipeline system and expansion project for C$4.5 billion in August 2018, stating it did not intend to be a permanent owner. The expansion entered commercial service in May 2024. The final all-in cost reached approximately C$34.2 billion, including capitalized carrying costs. That is 6.3 times the original 2013 estimate of C$5.4 billion. [6] [16]

Across the three cancelled projects, the conservative documentable tally of private capital destroyed is roughly C$2.4 billion: Enbridge's C$373 million Northern Gateway impairment, TC Energy's C$954 million Energy East impairment, and TC Energy's approximately US$1.1 billion net financial impact from Keystone XL. [13] [14] [15]

The cumulative effect of these outcomes on investor confidence is the same regardless of which jurisdiction cancelled each project. By 2026, no private company had been publicly identified as willing to take a majority stake in a new Canadian export pipeline. The regulatory environment had been specifically redesigned to remove the barriers the industry cited as deal-killers. Private capital still would not lead.

The West Coast Oil Pipeline: Government as Proponent

On July 2, 2026, Prime Minister Carney and Alberta Premier Smith announced that Alberta had submitted a proposal for the West Coast Oil Pipeline to the federal Major Projects Office. The pipeline would transport 1 million barrels per day along a route that largely follows the existing Trans Mountain corridor, from a receipt terminal near Bruderheim, Alberta, to a marine terminal on the southern B.C. coast. [1] [2]

The ownership structure places governments in the lead. Canada and Alberta will hold equal partnership in the project. Trans Mountain Corporation, the federal Crown entity that built and operates the expanded Trans Mountain system, will serve as lead proponent, construction manager, and eventual operator. The federal government has committed to pursuing designation of the pipeline as a project of national interest under the Building Canada Act by October 1, 2026, and to making best efforts to issue a conditions document by September 1, 2027, at which point construction could begin. [2] [4] [5]

Pembina Pipeline Corporation, the sole disclosed private participant, entered a non-binding Heads of Agreement on July 2. Its economic interest through construction will be 10 percent, with the opportunity for an additional 10 percent once the pipeline enters commercial operation. Pembina's own news release discloses the terms clearly: the structure includes protection for Pembina on cost overruns and returns; Pembina will have full discretion over any final investment decision; and Pembina "shall have no at-risk development capital prior to FID." Definitive agreements are targeted for September 2026. [12]

These terms are protective: Pembina preserves FID discretion, avoids at-risk development capital before FID, and retains cost-overrun and return protections. The disclosed structure places substantially all pre-FID downside risk on public entities, while the sole named private participant preserves optionality without committing capital. [12] [20]

The following items do not appear in any public document reviewed as of July 3, 2026: a final capital cost estimate, the names of committed shippers, committed shipper volumes, a toll framework, a break-even analysis, or an exit or divestiture strategy. [1] [2] [12] [18]

The Building Canada Act, which received Royal Assent on June 26, creates the regulatory mechanism for the project. For any project designated as being in the national interest, every determination required for a federal authorization is deemed to have been made "in favour of permitting the project." The designated minister then issues a single conditions document that replaces all other required federal authorizations. The Act also requires a public registry with detailed cost estimates and projected timelines. It preserves the duty to consult with Indigenous peoples but allows cabinet to exempt projects from certain statutes by regulation. [7] [8] [11] [19]

Separately, the Canada-British Columbia Cooperative Prosperity Agreement, signed on July 2, confirms that the federal North Coast tanker ban will remain in place and commits the parties to negotiate a "legally binding framework" under which B.C. will "share meaningfully in the economic upside of the project." Mechanisms discussed include an annual royalty payment to B.C. by the pipeline operator. As of July 3, neither the royalty rate, the terms of an environmental response fund, nor any enforceable remedies for non-compliance are defined. The deadline for negotiating financial commitments related to the pipeline is December 1, 2026. The southern route reduces but does not eliminate Indigenous consent risk: affected communities along the Trans Mountain and southern B.C. corridor have distinct rights, risk exposure, and negotiating positions that the North Coast resolution does not address. [3] [2]

C$39,000 Per Barrel Per Day

If the West Coast Oil Pipeline proceeds at the reported C$35 billion working estimate, total public capital committed to west-coast pipeline infrastructure since 2018 would reach approximately C$73.7 billion: C$4.5 billion for the Trans Mountain purchase, C$34.2 billion for the Trans Mountain Expansion, and C$35 billion for the new pipeline. That figure is illustrative because no official capital cost for the West Coast Oil Pipeline has been published. The C$35 billion estimate was reported by CBC News based on Alberta government documentation; the Alberta government's own public page states that cost estimates are still being reviewed. [18] [1]

Total capacity across both pipelines would be approximately 1.89 million barrels per day: 890,000 from Trans Mountain and 1 million from the proposed pipeline. That implies a capital intensity of roughly C$39,000 per barrel per day across the combined system. If the denominator is limited to incremental export capacity created by public decisions since 2018, the figures are 1.59 million barrels per day (the 590,000-barrel TMX expansion plus 1 million from the new pipeline) at roughly C$46,000 per incremental barrel per day. [6] [2]

Against U.S. comparators, the gap is large even after allowing for different geography, marine terminal requirements, inflation timing, and currency effects. Dakota Access Pipeline (DAPL) cost approximately US$3.78 billion and moves roughly 570,000 barrels per day, for a capital intensity of approximately US$6,600 per barrel per day. The original Keystone pipeline cost approximately US$5.2 billion for 591,000 barrels per day of nameplate capacity, or about US$8,800 per barrel per day. These are not equivalent projects. But the directional gap between roughly US$7,000 per barrel per day and C$39,000 or more is structurally significant. [15]

The differential narrowing argument does not close the gap. If the differential effect were US$3 per barrel, as CAPP reported in April 2026 for the existing Trans Mountain system, the gross annual value on 1 million barrels per day would be approximately US$1.1 billion before operating costs, utilization risk, and financing charges. On a C$35 billion capital base, the arithmetic yields a nominal simple payback of approximately 32 years, and that calculation excludes maintenance capital, taxes, and the assumption that the pipeline operates at or near full capacity for decades. [22]

The Parliamentary Budget Officer's 2024 valuation of the existing Trans Mountain system provides a benchmark. The PBO estimated the system's value at C$29.6 billion to C$33.4 billion depending on post-contract service assumptions, and stated explicitly that if the system were sold at either of those values, the government would record a loss. As of July 2026, no sale has been completed. The Canada Development Investment Corporation's 2025 annual report describes its stewardship of Trans Mountain Corporation as managing for "successful monetization in due course." [6] [17]

The only comparable Canadian crude pipeline megaproject completed in the period, Trans Mountain Expansion, finished at 6.3 times its original 2013 estimate. [6]

The 8-Million-Barrel Question

The pipeline's demand case rests on whether Canadian crude production will grow fast enough to fill 1 million barrels per day of new capacity. Premier Smith has stated publicly that Alberta's goal is to reach 8 million barrels per day of production over the next 10 to 15 years. She reiterated this target on July 2. [2] [21]

The major public forecasts reviewed do not support that figure on that timeline. The Canada Energy Regulator's Energy Futures 2026 report projects Canadian crude oil production reaching 5.8 million barrels per day by 2030 under its Current Measures scenario, rising from 5.5 million in 2024. Across all CER scenarios, the full range of projected production by 2050 is 4.8 to 6.5 million barrels per day. The CER's highest projection does not reach 8 million barrels per day at any point in its modelling horizon. [9]

The International Energy Agency's Oil 2025 report projects total Canadian liquids supply at 6.8 million barrels per day by 2030. That figure is broader than crude alone, including natural gas liquids and condensates, and it is still well below 8 million. CAPP's own data shows total Canadian oil production, including NGLs and condensates, averaged 6.1 million barrels per day in 2025. [22]

The pipeline also depends on a parallel commitment. The July 2 announcement describes construction of the West Coast Oil Pipeline and construction of the Pathways carbon capture project as "mutually dependent." The Implementation Agreement between Canada and Alberta, signed May 15, 2026, uses the same language. A tripartite agreement with the Oil Sands Alliance was announced on July 2, with a stated target of 16 million tonnes per year of emissions reductions. The capital cost, detailed timeline, and legal enforceability of the Pathways commitment are not publicly defined in the documents reviewed. The pipeline's risk is therefore not a single-project risk. It is a paired-project risk: the pipeline depends politically on Pathways, and Pathways depends on carbon pricing, public investment, and oil-sands participation that remain separately contested. [2] [4]

Key Facts — Documented

Northern Gateway: 525,000 bpd westbound, C$7.9 billion projected cost, NEB approved with 209 conditions (2014), federal government cancelled (November 2016), Enbridge C$373 million impairment. [10] [13]
Energy East: 1.1 million bpd, C$12 billion projected cost, approximately 900,000 bpd binding shipper commitments, TransCanada withdrew (October 2017), C$954 million after-tax impairment. [14]
Keystone XL: 830,000 bpd, approximately US$8 billion, 20-year shipper contracts, U.S. presidential permit revoked (January 2021), TC Energy net financial impact approximately US$1.1 billion. [15]
Trans Mountain Expansion: 590,000 bpd incremental capacity, C$5.4 billion original estimate (2013), final all-in cost C$34.2 billion (6.3×), PBO 2024 valuation C$29.6–33.4 billion (PBO stated a sale at those values would record a loss). [6] [24]
West Coast Oil Pipeline: 1 million bpd proposed, no published final capital cost, no published shipper commitments, Pembina 10% with full FID discretion and zero pre-FID capital at risk. [1] [12]
Building Canada Act (Bill C-5): Royal Assent June 26, 2025. For national interest projects, all federal authorization determinations are deemed made in favour of permitting. [7] [8]
CER Energy Futures 2026: Canadian crude oil production projected at 5.8 million bpd by 2030 (Current Measures), range of 4.8–6.5 million bpd by 2050 across all scenarios. Premier Smith's target: 8 million bpd. [9]

Context — What Both Sides Omit

What the announcement coverage does not report: Before the government purchased Trans Mountain in 2018, approximately 2.5 million barrels per day of privately financed pipeline capacity was proposed across three projects, at a combined projected cost of roughly C$20 billion plus US$8 billion. All three had identified proponents and shipper relationships. The replacement now proposed delivers less than half that capacity at several multiples of the per-barrel cost. Pembina's participation terms preserve FID discretion, avoid pre-FID capital risk, and include cost-overrun and return protections. The PBO's 2024 valuation of Trans Mountain concluded that a sale at assessed values would record a loss for government. No exit strategy for either Trans Mountain or the proposed new pipeline has been publicly disclosed.

What opposition coverage does not report: Canada exports approximately 97 percent of its crude oil to the United States. Diversification of export markets is a genuine strategic interest during an active trade conflict. Trans Mountain has already shifted meaningful export flows toward Asia, with CDEV reporting that roughly 60 percent of loaded exports from the Westridge Marine Terminal were destined for Asian markets. The government claims the project would support up to 175,000 jobs during construction and operation; the employment case may strengthen the strategic-industrial argument even if it does not by itself demonstrate that the pipeline can repay public capital. The Building Canada Act was designed specifically to remove the regulatory barriers that contributed to the cancellation of the three previous pipeline proposals; the Act's deeming power operates alongside conditions and consultation requirements, not as a standalone override. The regulatory environment for a new Canadian pipeline has never been more favourable than it is in July 2026. The government's stated position is that it is acting as a catalyst, not as a permanent owner. [2] [7] [17]

Interpretation

The West Coast Oil Pipeline's ownership structure documents a transfer of downside risk from the private sector to the public. Roughly 2.5 million barrels per day of privately financed pipeline capacity was cancelled or blocked over the preceding decade. The replacement delivers less than half that capacity, at several multiples of the per-barrel cost, with no published binding shipper commitments, no published break-even case, and the sole named private participant holding contractual protections that preserve its optionality while avoiding pre-FID capital risk. The conditions under which this investment returns more than it costs have not been publicly established.

Counter-interpretation: The strongest case for the West Coast Oil Pipeline is not commercial. It is strategic. Canada's near-total export dependence on the United States represents a structural vulnerability that the trade war of 2025–2026 has made urgent. The Trans Mountain system has already demonstrated that west-coast capacity redirects export flows toward Asian markets. Government may be justified in acting as lead proponent precisely because its own past regulatory and policy decisions destroyed private investor confidence in Canadian pipeline development. Northern Gateway was approved by the NEB and then cancelled by cabinet. Energy East was withdrawn after a mid-process change to the regulatory scope. Kinder Morgan walked away from Trans Mountain rather than carry the political risk. In this context, the government assuming the development role can be understood as corrective action rather than subsidy, and the Building Canada Act's deeming power was designed to ensure the regulatory barriers that killed those projects cannot recur. This counter-interpretation is substantive. What it does not address is whether the investment recovers the public capital committed, or whether the structure creates an escalating obligation with no defined exit point. The distinction between "strategically justified" and "commercially viable" is the distinction between the public bearing risk it chose and the public recovering its cost. [2] [6] [17]

What Would Change This Assessment

Binding shipper commitments: As an editorial test rather than a formal project-finance standard: if the government publishes binding transportation service agreements covering at least 70 percent of the West Coast Oil Pipeline's 1 million bpd capacity, at toll rates sufficient to recover total capital costs within a disclosed contract or toll period acceptable to lenders and independently reviewed, the Captive Cost frame weakens materially and the project reads as a conventional infrastructure investment with a defined commercial foundation.
Private final investment decision: If Pembina Pipeline or another private partner moves from a protected option position to a binding final investment decision with real capital at risk, without protections that leave public entities responsible for construction overruns beyond a normal pro-rata equity exposure, the finding that no private entity is willing to bear meaningful downside risk weakens materially.
Published break-even case: If the Building Canada Act public registry publishes detailed cost estimates, a toll methodology, and a break-even model reviewed by PBO, CER, or another named independent body without a finding that capital recovery depends on undisclosed subsidies, uneconomic tolls, or implausible utilization, the finding that the conditions for public capital recovery have not been defined weakens. The Act requires publication of detailed cost estimates for listed projects. This test will become available if the project receives its national interest designation.

Sources (24)

Government of Alberta. "West Coast Oil Pipeline." alberta.ca (July 2, 2026). Link
Prime Minister of Canada. "Canada and Alberta advance west coast pipeline project proposal and Pathways Project Carbon Capture Initiative." pm.gc.ca (July 2, 2026). Link
Prime Minister of Canada. "Canada-British Columbia Cooperative Prosperity Agreement." pm.gc.ca (July 2, 2026). Link
Prime Minister of Canada. "Implementation Agreement for the Canada-Alberta Memorandum of Understanding of November 27, 2025." pm.gc.ca (May 15, 2026). Link
Prime Minister of Canada. "Canada-Alberta Memorandum of Understanding." pm.gc.ca (November 27, 2025). Link
Parliamentary Budget Officer. "Trans Mountain Pipeline — 2024 Report." pbo-dpb.ca (November 8, 2024). Link
Parliament of Canada. Bill C-5, One Canadian Economy Act (Building Canada Act). Royal Assent, June 26, 2025. Link
Parliament of Canada. LEGISinfo — Bill C-5. Link
Canada Energy Regulator. "Canada's Energy Future 2026." cer-rec.gc.ca (March 2026). PDF
National Energy Board. "Connections: Report of the Joint Review Panel for the Enbridge Northern Gateway Project." neb-one.gc.ca (December 2013). Link
Canada.ca. "Building Canada Act — Projects of National Interest." canada.ca (2025). Link
Pembina Pipeline Corporation. "Pembina Signs Agreement to Participate in a Proposed Nation-Building Energy Corridor." pembina.com (July 2, 2026). Link
Enbridge Inc. Annual Report (2016/2017), Northern Gateway impairment charge, C$373 million. Attributed to Enbridge regulatory filings and NEB Joint Review Panel record.
TC Energy (formerly TransCanada). Energy East Pipeline Ltd. termination announcement (October 5, 2017) and 2017 Annual Report, C$954 million after-tax impairment charge.
TC Energy. Keystone XL termination announcement (June 9, 2021) and Q2 2021 financial report, net financial impact approximately US$1.1 billion after recoveries.
Trans Mountain Corporation. Year-end 2023 financial statements. Total estimated TMEP cost: C$34.2 billion including capitalized carrying costs.
Canada Development Investment Corporation. 2025 Annual Report. TMC revenue, performance data, and "successful monetization in due course" language.
CBC News. "Alberta pitches southern route for West Coast pipeline, with a price tag of $35B or more." cbc.ca (July 3, 2026). Link (Acceptable as reporting.)
Norton Rose Fulbright. "How the new Building Canada Act works." nortonrosefulbright.com (June 30, 2025). Link (Acceptable as reporting.)
Canada's National Observer. "Government-owned Trans Mountain to lead $35-44 billion oil pipeline to BC Lower Mainland." nationalobserver.com (July 2, 2026). Link (Acceptable as reporting.)
The Canadian Press. "Alberta pitches new bitumen pipeline to B.C. coast with TMX, Pembina partners." (July 2, 2026). (Acceptable as reporting.)
Canadian Association of Petroleum Producers. April 2026 production and WCS-WTI differential data. (Acceptable as reporting.)
The Receipts. "The Feedback Loop: How Canada Built an Energy Bottleneck From Both Sides." thereceipts.ca (March 2026). Link
Kinder Morgan. Trans Mountain Expansion Project Application to the National Energy Board (December 2013). 708,000 bpd firm shipper commitments, C$5.4 billion estimated cost.

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