Canada Ended 30 Years of One Customer — In a Single Week

Added: 2026-06-02

[00:00:01]There is a number I want you to hold in your mind before we go any further. $26 billion every year gone, not stolen, not mismanaged, not lost to corruption or incompetence, simply left on the table year after year after year because Canadian oil had nowhere else to go except one customer who knew it and priced. Accordingly, for 30 years, every barrel of Alberta crude that left the ground was sold at a discount to world prices. The Ducks WTI differential Western Canadian Select trading below the global benchmark, sometimes by $14 a barrel, sometimes by $18. In 2018, the worst year on record, by $50 a barrel Canadian, producers were essentially giving their oil away because the pipeline map left them no alternative.

[00:00:46]That is 30 years of value that should have flowed into Alberta royalties, into federal tax revenues, into the pension funds of every Canadian who holds an energy stock in there spore CPP. 30 years of a discount that was accepted as permanent because ending it required something Canada had never managed to build a second exit in a single week in late May 2025 that changed in two directions at once for the first time in Canadian history. On Thursday, May 29th, South Bow confirmed binding 20-year transportation commitments for the Prairie Connector 450,000 barrels per day heading south from Hardesty, Alberta to the US Gulf Coast. Commercial support secured. Final investment decision targeted for mid 2027. The project reuses 150 km of Keystone XL steel already sitting in the ground in Saskatchewan.

[00:01:36]15 days earlier on May 15th, Prime Minister Mark Carney and Alberta Premier Danielle Smith stood together in Calgary and signed the West Coast pipeline implementation agreement 1 million barrels per day from the same starting point. Hardesty heading west to the British Columbia coast and from there to Asian buyers who have never had reliable Canadian supply before. Same source two exits 1.45 million barrels per day of new export capacity moving simultaneously through development. More new pipeline capacity announced in a single month than Canada built in the previous 20 years combined. And almost nobody outside the energy industry has connected these two stories into the single picture they actually represent.

[00:02:17]That picture is what this video is about. Not just two pipeline announcements, not just infrastructure news, the beginning of the end of a 30-year structural trap that has cost every Canadian, whether they work in oil or not, billions of dollars every single year it has been in place. Over the next 30 minutes, I am going to walk you through exactly what these pipelines are, where they actually stand right now, what the math says about the money that flows once they operate, and what honest caveats you deserve to hear alongside the good news. Because this story deserves the full picture, not just the headlines. If this is the kind of analysis you want to stay ahead of the economic shifts that affect your retirement, your provinces finances, and Canada's position in the world before they hit mainstream coverage, hit subscribe right now. You will not regret it. To understand why two directions matters, not just two pipelines, two actual directions, you have to understand how Canada got trapped in the first place. Alberta oil sands produce some of the largest proven reserves on the planet. Canada sits on approximately 170 billion barrels of recoverable oil.

[00:03:19]The third largest reserve in the world.

[00:03:21]By any measure of resource endowment, Canada should be a global energy price setter. For 30 years, it was a price taker. The reason is straightforward and worth stating plainly. Canadian Oil had one customer, the United States, and more specifically the landlocked refinery complex in Illinois, Ohio, Michigan, and Minnesota built decades ago specifically to process Alberta heavy crude through pipelines that went one direction south into the American Midwest. No Pacific access, no Atlantic access, no competition. American Midwest refineries did not need to offer world prices because Canadian producers had no one else to call. The choice for Alberta producers was binary sell at whatever price the American buyer offered or leave the oil in the ground that is not a market that is a captive relationship and captive relationships always produce the same outcome. The buyer extracts maximum value from the supplier. The Ducks WT differential is what that extraction looks like in numbers.

[00:04:19]Western Canadian Select, the benchmark for Alberta Heavy crude, has traded at a persistent discount to West Texas Intermediate, the American benchmark for most of the past two decades. The average gap in recent years has been between 14 and $18 per barrel on 4 million barrels per day of Canadian production. That discount costs Canada between 20 billion and 26 billion per year every year. Alberta Central, the provincial economic research body, calculates that the 30-year cumulative cost of that discount is in the hundreds of billions of dollars. Provincial royalties forgone, federal corporate taxes not collected, pension fund dividends not paid, infrastructure not built, Trans Mountain changed part of this calculation when its expansion opened in May 2024. For the first time, Canadian producers could reach Pacific Tidewater and Asian buyers could bid against American refineries for the same barrels. The differential narrowed Alberta Central calculated $13 billion in recovered value in the first year of Trans Mountain expansion operations alone. But Trans Mountain is not enough.

[00:05:23]The pipeline is running at 96% capacity.

[00:05:26]It has room for between 70,000 and 90,000 additional barrels using drag reducing agents before it hits its physical ceiling. One Pacific Route nearly full, serving a fraction of Canada's potential Asian market for the discount. to close further for Canadian producers to fully capture world prices.

[00:05:43]Canada needs more exits, more buyers bidding against each other, more competition for the same barrels. That is exactly what 1.45 million new barrels of export capacity in development represents, not just infrastructure.

[00:05:57]Competition and competition in commodity markets always flows back to the producer as higher realized prices. Stay with me because the math gets very specific from here and the numbers are worth understanding. Let me walk you through each pipeline separately.

[00:06:11]Starting with Prairie Connector because the details matter and the distinction between what is confirmed and what is still in development matters even more.

[00:06:19]On Thursday, May 29th, 2025 at 6:00 in the morning, Southb published an announcement on Globe Newswire confirming that the Prairie Connector open season was successful. The phrase open season in pipeline terminology refers to the formal commercial process through which producers commit to long-term transportation agreements before a final investment decision is made. Southbell reported binding 20-year commitments for firm transportation from Hardesty Alberta to us delivery points Cushing Oklahoma first and from their onward to Gulf Coast refineries.

[00:06:50]According to Reuters sources with knowledge of the commercial process, at least 400,000 barrels per day in binding commitments were secured. Southba CEO Bevon Worse be called it a critical milestone and confirmed the project is advancing toward a final investment decision targeted for mid 2027. The infrastructure foundation for this pipeline is unusually strong because a significant portion of it already exists.

[00:07:15]150 km of steel pipe sitting in the ground in Saskatchewan was originally installed for the Keystone XL project before its cancellation. Southba has acquired rights to that steel and intends to incorporate it into the prairie connector route. The US side of the connection received a Trump presidential permit on April 30th, 2025, authorizing Bridger Pipeline System to connect to the Canadian portion at the border. That permit is a material milestone because presidential permits for crossber pipelines are historically the longest leadtime regulatory item in North American pipeline development.

[00:07:49]Southb is now building what the company calls the preid work package. The collection of remaining permits, government permit durability asurances, indigenous consultation processes, engineering cost estimates, and financing arrangements required before a final investment decision can be formally made. CEO Worspa specifically mentioned government permit durability asurances as a required condition. This is a phrase worth understanding. It refers to contractual or legislative protections that prevent a future government from cancelling the project mid construction. The same kind of cancellation that killed Keystone XL after billions had already been spent.

[00:08:25]Prairie Connector's commercial logic depends on 20-year shipping commitments.

[00:08:29]Those commitments only hold if the shippers believe the pipeline will actually be built and operated. Permit durability asurances are what creates that confidence. On the current optimistic timeline, FID mid 2027, construction starting late 2027, prairie connector could be in service by 2029, subject to regulatory approval, completed indigenous consultation, secured financing, and the permit durability asurances not yet in hand.

[00:08:54]This is a project with real commercial momentum. The steel exists, the US permit is signed. The binding contracts are in place. The credible path to completion is clearer than at any point in the project's history. It is not built yet, but it is the furthest along it has ever been, and for Alberta producers who have waited 15 years for Gulf Coast Access since Keystone XL was first proposed, that momentum is meaningful. The West Coast pipeline story requires more careful handling because the political milestone is real and significant, and the distance between that milestone and a working pipeline is also real and significant.

[00:09:29]Both things are true at the same time.

[00:09:31]On May 15th, 2025, Prime Minister Mark Carney and Alberta Premier Danielle Smith signed what the two governments called the West Coast Pipeline implementation agreement in Calgary. The joint appearance itself was notable. A Liberal federal government and a conservative provincial government standing together to commit. Two new oil infrastructure represents a political alignment that has been absent from Canadian energy policy for most of the past decade. The implementation agreement establishes a specific sequence of milestones. Alberta submits its formal proposal to Ottawa's major projects office by July 1st, 31 days from the signing. The federal government designates the project as a project of national interest by October 1st under Car's updated regulatory framework. That designation triggers a one-year review process with cabinet signoff before the technical assessment begins a structure designed to move major projects faster than the previous system allowed. The proposed pipeline would carry 1 million barrels per day from Hardesty, Alberta to the British Columbia coast, where the oil would be loaded onto Asian tankers.

[00:10:33]Oil flowing to buyers in Japan, South Korea, China, and India markets that currently have no reliable Canadian heavy crude supply is targeted for 2033 or 2034 on the optimistic construction scenario. Here is the honest picture of where this project actually stands today. The proposal has no confirmed builder. No private sector company has publicly committed to building this pipeline. No approved route has been filed. No completed indigenous consultation framework exists for the communities along the proposed corridor.

[00:11:03]No cost estimate has been published.

[00:11:06]British Columbia Premier David Ebe has not publicly endorsed a new oil pipeline crossing his province. The tanker moratorium on northern BC waters. The regulatory prohibition on oil tanker traffic on the northern coast that has been in place since 2019 may need to be addressed for certain proposed routes.

[00:11:23]That process has not been initiated publicly. Construction starting September 2027, as the optimistic scenario suggests, requires every one of those outstanding items to be resolved simultaneously within approximately 24 months. That is an extremely compressed timeline for a project of this complexity. What the agreement does provide is something that has genuine value even without a builder or a route.

[00:11:45]Political alignment between Ottawa and Edmonton removes the federal provincial conflict that killed Energy East in 2017. The new regulatory framework Carney built removes the decadel long approval bottleneck that stalled Trans Mountain. The July 1st submission deadline creates public accountability for progress. For the first time in Canadian history, a federal government and the Alberta government are pursuing a Pacific oil pipeline together under a framework designed to move at speed. The gap between a signed agreement and a working pipeline is measured in years of work not yet done. The gap between a signed agreement and no signed agreement is the entire previous decade. Both of those things are simultaneously true.

[00:12:25]Let me walk through the pricing math carefully because this is where the two pipelines stop being infrastructure stories and start being personal financial stories for every Canadian.

[00:12:34]Start with Prairie Connector. GF Coast refineries in Texas and Louisiana process Canadian heavy crude differently than Midwest refineries in Illinois and Michigan. GF Coast refineries were originally built for Venezuelan heavy crude which is chemically similar to Alberta oil sands bummen. When Venezuelan supply declined following US sanctions, GF Coast refineries became hungry for exactly the product Alberta produces, they compete for it. That competition means they pay more. The conservative estimate used by Alberta Central in their Trans Mountain analysis is that GF Coast Access improves realized pricing for Canadian heavy crude by approximately $4 per barrel compared to captive Midwest prices. $4 per barrel on 450,000 barrels per day is $1.8 8 million per day over a full year.

[00:13:21]That is $657 million in recovered value value that was previously surrendered as part of the Ducks discount, now the West Coast pipeline. Trans Mountain's first year of expanded operations achieved approximately $6 per barrel improvement in realized pricing as Asian buyers bid against American refineries for the first time. apply the same $6 improvement conservative given that Trans Mountain was absorbing the pricing benefit of opening a new market from scratch to 1 million barrels per day. $6 per barrel on 1 million barrels per day is $6 million per day over a full year.

[00:13:55]That is $2.19 billion in recovered value. Add both pipelines together. 657 million from Prairie Connector plus $2.19 billion from the West Coast pipeline equals 2.847 $847 billion per year in recovered value above what Canada earns today from those barrels.

[00:14:14]Over a 20-year operating life, the term of Southba's commercial commitments that is more than $56 billion in cumulative recovered pricing now follow where that money actually goes. It does not disappear into corporate offshore accounts. Alberta royalties are calculated as a percentage of wellhead value. Higher realized prices mean higher royalties flowing into provincial revenues and the heritage fund. Federal corporate tax receipts increase when energy companies earn more on the same barrels. Dividends increase across the Canadian energy sector southbound in bridge Canadian natural resources suncoris companies whose shares are held in the CPP investment board, the Ontario teachers pension plan and the Alberta Investment Management Corporation. When Canadian oil gets a better price because it has more ways to reach more markets, every Canadian with a pension is better off. That is not a political statement.

[00:15:06]It is arithmetic. The ducks discount is not an abstraction. It is money that should be in Canadian public accounts, Canadian retirement funds, and Canadian provincial services. $56 billion over 20 years is the cost of the single customer trap. Two pipelines into directions is the exit. If this math is landing for you, if you have never seen these numbers laid out this clearly before, hit subscribe and ring the bell. This is the kind of analysis this channel delivers every single time. There is a third major energy development running alongside both pipelines that most Canadians are not tracking and it completes the picture in a way that makes the full scope of what is happening in Canadian energy much clearer. In Bridg's Sunrise natural gas expansion in British Columbia, $4 billion in construction with groundbreaking scheduled for July 2026.

[00:15:54]This is not an oil pipeline, but it matters to this story directly because it feeds the infrastructure that makes LG Canada phase 2 viable. LG Canada is the $40 billion liqufied natural gas export terminal in Kitamat, British Columbia, the largest private sector investment in Canadian history. Built as a joint venture between Shell, Petronis, Petrokina, Mitsubishi, and Korea Gas.

[00:16:16]Phase 1 shipped its first cargo in June 2025, the first Canadian LNG ever to reach Asian buyers. Phase 2 would more than double the terminal's capacity.

[00:16:27]Shell's $14 billion acquisition of Ark Resources earlier this year secured the Montney natural gas supply that phase 2 requires. The LNG Canada final investment decision for phase 2 is targeted before December 2026. If that fit is approved, Canada would simultaneously have oil moving south through Prairie Connector, oil moving west through the West Coast pipeline, and natural gas moving west through LNG Canada phase 2, oil south, oil west, gas west. three simultaneous major energy export expansions, all with construction timelines or investment decisions in the same window. This is what Canada's energy superpower ambition looks like when it moves from political language into commercial reality. Not a plan, not a vision statement, binding 20-year contracts, signed implementation agreements, construction start dates, and investment decisions with specific dollar amounts and specific timelines attached to them. In the same 30-day window in May 2025, Southbo announced binding contracts. Carney and Smith signed the West Coast agreement in Bridge confirmed its BC construction schedule and Shell's arc acquisition closed. That is not coincidence. That is a coordinated commercial and regulatory environment finally moving at a pace that matches the scale of Canada's actual resource endowment. One important context for the natural gas side. The IMBridge Sunrise expansion is British Columbia infrastructure for BC production. The West Coast Oil Pipeline is Alberta infrastructure for Alberta production. The two projects are separate technically but complimentary strategically. Both require BC cooperation. Both benefit from the same regulatory acceleration framework Carney implemented and both point toward a Pacific export market that Canada is building access to simultaneously across two commodities. The combined picture is genuinely without precedent in Canadian energy history. More major energy export capacity moving through development simultaneously in 2025 than at any previous point. And underpinning all of it, the same foundational strategic logic Canada has spent 30 years as a single direction, single customer commodity producer and the combination of political will, regulatory reform and commercial market conditions has created the first real opportunity to change that permanently. The question is whether every moving piece falls into place on schedule. And that is where the honest caveat becomes essential. I am not going to tell you two announcements mean two working pipelines. They do not.

[00:18:52]And you deserve the honest version of this story, not just the exciting version. Prairie Connector is the more advanced of the two projects. The commercial support is confirmed. The US presidential permit is signed. The Keystone XL steel is in the ground. The binding 20-year contracts are in place.

[00:19:09]The credible path to a 2029 inservice date exists, but Prairie Connector is still not built. The FID is 13 months away. CEO worst Ben named government permit durability asurances as a specific required condition and those asurances are not yet secured. Canadian regulatory approval for the Alberta portion is not yet complete. Indigenous consultation processes are ongoing.

[00:19:32]Financing has not been closed. If a political change in Ottawa before the FID undermines confidence in permit stability, the commercial logic of 20-year shipping commitments becomes harder to maintain. The project has more momentum than at any previous point. It also has more distance to travel before the first barrel of oil flows. The West Coast pipeline is significantly earlier in its development. Let me be direct about what the implementation agreement actually confirmed and what it did not.

[00:19:59]It confirmed political alignment between federal and provincial governments, which is genuinely new and genuinely significant after a decade of conflict.

[00:20:07]It did not confirm a builder. No private sector company has publicly committed capital to this project. It did not confirm a route. The corridors under consideration crossed some of the most technically challenging terrain in Canada. It did not confirm BC's support.

[00:20:22]Premier EIE has not publicly endorsed a new oil pipeline through his province.

[00:20:27]It did not confirm indigenous consent along the proposed corridor.

[00:20:31]Construction starting September 2027 on the optimistic scenario requires all of those open items to resolve within approximately 24 months. That timeline is achievable in theory. In practice, it represents a compression of regulatory, commercial, and social license work that has never been achieved on a project of this scale in Canada. Even if both pipelines are built on their optimistic timelines, Prairie Connector in service 2029, West Coast Pipeline in service 2033, there is a six-year window in which Trans Mountain continues to carry nearly all of Canada's Pacific export capacity at 96% utilization with limited room to grow. 6 years of the current constraint, 6 years of leaving pricing value on the table while the new infrastructure is built. But here is the context that matters for evaluating those caveats honestly. Six years ago, Trans Mountain was still in court challenges. Energy East was dead.

[00:21:23]Keystone XL was in its final year before Biden canled it. The Ducks differential was blowing out to historic highs. No new export capacity was being built, approved, or seriously proposed on any timeline. The regulatory framework blocked everything. Today, Southbau has binding contracts. Carney and Smith have assigned agreement. Shell has committed $14 billion. In Bridge is breaking ground in July. LNG Canada is approaching its FID and the regulatory framework that blocked all of it for a decade has been replaced with one designed to move at speed. The pipeline map of Canada looks different than it did 1 year ago. It is going to look different again in 5 years. Let me bring this back to the personal level because the numbers I have been walking through 1.45 million barrels per day, 2.8 8 billion per year, 56 billion over 20 years can start to feel abstract when they get that large. They are not abstract. They'll end in specific places in your financial life. If you hold Canadian equities in your Rport EFCA, you likely hold shares in companies whose earnings are directly tied to what Canadian oil fetches at the Wellhead, South Bow, Inbridge, Canadian Natural Resources, Suncor, Cenovis. Higher realized pricing flows directly to earnings which flows to dividends which flows to your account balance. If you are a member of a defined benefit pension plan in Canada, your fund almost certainly holds Canadian energy exposure. The CPP investment board holds billions in Canadian energy equity. The Ontario Teachers Pension Plan holds in bridge units. The Alberta Investment Management Corporation holds oil sands producers. When Canadian oil reaches world prices, every one of those funds earns more on its existing positions without deploying a single new dollar.

[00:23:09]If you live in Alberta, recovered royalty revenues flow into provincial public finances. The Heritage Fund receives contributions from royalty surpluses. Public services, healthcare, education, infrastructure are funded in part by what the provincial government collects on every barrel of oil sold $26 billion per year in suppressed pricing is $26 billion per year that could have been flowing into those accounts and was not. At the federal level, higher corporate tax receipts from the energy sector reduce the pressure on individual taxpayers and on the federal deficit.

[00:23:41]Energy sector prosperity is not a regional issue. It flows through the entire fiscal structure of the country.

[00:23:47]There is also a geopolitical dimension to this that deserves to be named directly. For 30 years, Canada's single customer energy dependence gave Washington structural leverage over Ottawa in trade negotiations. When your most important export has only one buyer, that buyer knows it. Canada's credible ability to threaten diverting oil to Asia to actually root barrels to buyers who compete with American refineries. Depends on the infrastructure to do it. existing. Trans Mountain gave Canada its first credible Pacific exit. 1.45 million additional barrels per day in development gives Canada the leverage to back that threat with commercial reality. A Canada that can actually supply Asia at scale is a Canada that negotiates from a fundamentally different position than one that cannot. That is the full picture in one sentence. Two pipelines, two directions, one Canada that finally decided to use what it has. The Prairie Connector gives American Gulf Coast refineries what they have been waiting 15 years for. The West Coast pipeline gives Asian buyers what they have never had. And together they give Canadian producers what 30 years of single customer dependence denied them. A real market, real competition, and a real price. Drop your thoughts in the comments. Do you think both pipelines get built on schedule, or does Canada still have obstacles to clear? I read every comment, and I want to know what you think. Share this video with someone who needs to understand what this week actually meant for Canada's economic future.