Canadian governments kept Canada captive to one buyer.
I know what a single buyer does to a place. Down at the co-op in Friendship, Adams-Columbia Electric Cooperative sets rates based on what Dairyland Power charges, and Dairyland Power buys from a handful of generators, and what those generators pay for fuel gets passed straight through to my neighbor’s electric bill. The man with one outlet for his work does not have a market. He has a price handed down to him. Canada has lived that way in oil and gas for a generation. The country is the world’s fourth-largest oil producer and fifth-largest natural-gas producer, yet roughly 90 percent of its crude exports and nearly all of its natural-gas exports cross one border into one market.
That is not an energy strategy. It is a hostage situation.
Oil and gas make up about a fifth of Canada’s exports, according to Statistics Canada. They are the country’s largest single export contributor, and because Canada has accepted a permanent discount on its heavy crude and a permanent constraint on its ambition, that discount shows up downstream in the prices paid by every farmer running diesel through a John Deere and every propane tank filling a Wisconsin farmhouse for winter. Abundant resources sat in the basement of the global energy system: technically brilliant, politically housebroken, and dependent on one customer.
That excuse just expired.
Mark Carney stood at the Canada Investment Summit and said, “We are unleashing our full potential as an energy superpower.” For a decade, that sentence would have been a punchline. Now it is a permitting bill Carney’s government introduced this month, a tax-code rewrite, and a pipeline route all moving in the same direction. Carney has been courting the money to pay for it since the summer.
The forces breaking the old arrangement are stacking up. Donald Trump’s trade war has made the United States an unreliable customer, not merely an indifferent one. The Iran conflict has reminded Asian refiners that geographic concentration of supply is a strategic liability. America’s turn toward Venezuelan heavy crude, which competes directly with Canadian heavy, tells Canadian producers that the neighborhood customer will not always be a customer at all.
The new government in Ottawa is responding with the most aggressive energy-export push Canada has attempted since the 1970s. Alberta is revising its royalty regime to push investment into the ground. Ottawa is moving to raise the federal capital-cost deduction for new wells, pipelines, and processing facilities from its current 25-to-30 percent range to a full 100 percent write-off for new projects. BMO Capital Markets estimates that change could lift oil producers’ cash flow per share by about 6 percent on average. The number that matters to someone in Adams County is not the cash-flow figure. It is what that kind of investment shift does to the price of diesel at the pump and the price of propane for the corn dryer when Canadian heavy crude stops selling at a permanent discount and the global heavy-oil market starts clearing properly.
The other half of the rewrite is time. Ottawa wants to compress federal review of major projects into twelve months, replacing a permitting regime that historically took two to three years or more. That old delay is not an abstraction. I have watched county-level permitting processes here in Wisconsin drag farm projects and co-op infrastructure builds out over eighteen months while consultants billed by the hour. The machinery of delay costs real money to the people waiting on the other side of it. In Canada, the delay killed more megaprojects than geology ever did.
The infrastructure plan gives the policy a road to travel on. The most consequential piece is the proposed West Coast pipeline, which would carry Alberta crude to tidewater and then toward Asian refiners. Wood Mackenzie estimates that ultraheavy-crude refining capacity is split roughly evenly between the U.S. Gulf Coast and Asia. Asian refineries already process the kind of crude Canada produces and currently source much of it from places considerably less stable than Alberta.
TD Economics projects roughly 6.8 million barrels a day of total Canadian takeaway capacity by 2034 under the full slate of proposed pipelines and expansions. About 30 percent of that capacity would run west toward the Pacific. Not all of it would go to Asia; some would serve domestic refineries and the U.S. West Coast. But it would mark a structural break from near-total dependence on one buyer.
That structural break matters to Wisconsin. The Midwest refinery corridor that serves our part of the state depends on a steady stream of Canadian heavy crude. When that supply was captive and the discount was wide, Midwest refiners picked up cheap feedstock while Canadian producers ate the loss. If the West Coast route works and Canadian producers gain a real second market, the discount narrows and the price of heavy crude firming up in the Gulf Coast and Midwest moves accordingly. That flows into refined-product pricing for diesel, heating oil, and the propane that fills tanks across central Wisconsin every October.
The gas side matters just as much. Proposed LNG projects could send 55 percent of Canadian natural-gas exports to non-U.S. markets by the early to mid-2030s. Analyst projections suggest Canadian gas prices could roughly double by the late 2020s as export capacity comes online. For Adams County, that is not a futures-market story. Natural-gas prices are the leading edge of what dairy operations pay to heat calf barns in January, what the co-op pays for power generation, and what households pay on the winter heating bill. Canadian gas leaving Canada for Asian LNG terminals means less cheap gas flowing south, and less cheap gas flowing south means higher input costs all the way down the chain to the farm and the family.
Tourmaline Oil, Canadian Natural Resources, and ARC Resources — now part of Shell — stand to benefit. The condensate story tightens the loop. Oil-sands operators need condensate to dilute bitumen thick as peanut butter into something that can flow through a pipeline. Canadian producers have been pulling up gas partly because the condensate attached to it is necessary for the oil business. A real LNG market turns the byproduct into the main course.
The oil payoff is mechanical. Existing pipelines are already running near full utilization. A West Coast route could narrow the discount between Canadian heavy crude and the U.S. benchmark by up to $3 a barrel over time, according to analyst estimates. Three dollars a barrel sounds like a number for the trading desk. Spread it across millions of barrels moving through Midwest refineries that supply Wisconsin gas stations, farm co-ops, and home-heating dealers, and it shows up in the prices that show up in Adams County. Every dollar of that discount that gets recovered is a dollar the producers were handing to their one captive buyer. That is a dollar per barrel of captured value that was being extracted from the Canadian side of the ledger and passed through to the buyer’s side, the way a middleman at the grain elevator takes his cut off every bushel.
The supply-side tailwind is the slow-motion depletion of U.S. shale. Enverus projects U.S. oil production peaking in the early 2030s as the remaining wells become progressively more expensive to drill. Canada’s oil sands have the opposite cost profile: heavy upfront capital, followed by steady production over decades.
That is reservoir physics, not a slogan. It means that in ten years, the country that has been supplying cheap heavy crude to Midwest refineries will have less of it, and the country that is building new pipelines to new markets will be deciding where its product goes based on price, not proximity.
The honest obstacle is the producers themselves.
Federal approval of the West Coast pipeline is conditional on major producers funding a separate multibillion-dollar carbon-capture project. That is a serious demand. Canadian operators have strong balance sheets and a friendlier price environment, but they have not yet committed to the checks. Oil-sands projects take years to develop and require multibillion-dollar bets up front. Producers do not write those checks until they know the regulatory framework they will be operating under.
The deadline is November 15, when definitive agreements are expected.
That deadline is not a press-release date. It is the point at which Canadian producers decide whether they want to be a Canadian-led industry or a U.S.-appendage industry for another decade.
Carney’s investment push in Toronto and the twelve-month permitting cap are not two separate stories. One is the demand signal from political leadership: Canada intends to become a supplier of consequence to the world rather than a captive supplier to one country. The other is the supply signal: the permitting machinery is being rebuilt around the bottleneck that stalled major projects for a generation.
The 100 percent write-off, Alberta’s royalty changes, the West Coast pipeline, the LNG build-out, the carbon-capture condition, and the twelve-month review cap are not gestures. Together they amount to a sequenced industrial strategy aimed at breaking a forty-year single-customer dependency in a single decade.
I think about it from the shop floor in Adams County. When a man who builds one thing has one buyer, he takes what the buyer offers. When that man builds a road to a second buyer, the first buyer either comes up in price or loses the product. Canada has been the tradesman with one customer for forty years. The market is tightening, the supply chains are fragmenting, and the refiners and LNG importers of Asia are looking for politically reliable crude and gas. The geology was already there. The machinery to monetize it was not.
The energy-superpower framing is not hyperbole. The geology already made Canada one. What has changed is that Ottawa and Alberta have finally begun acting like it.
The remaining question is not whether Canada has the resource. It does. The question is whether its producers will fund the infrastructure that lets the country escape the discount, the dependency, and the political housebreaking. November 15 will tell us whether Canada’s energy decade has finally begun — or whether Ottawa and Alberta have merely opened the basement door.