Brian Zinchuk is editor and owner of Pipeline Online
Boundary Dam Unit 6. Photo by Brian Zinchuk
There’s been a lot of talk about the coal refurbishment. Here’s the plan, the most detailed one Pipeline Online has seen to date.
Back in June, 2025, the Government of Saskatchewan announced it would not be shutting down its coal-fired power generation fleet, but rather refurbishing its coal fleet and running them for many years, as a bridge to eventual nuclear power. Minister of Crown Investments Corp and Minister Responsible for SaskPower Jeremy Harrison made the announcement by way of an emailed letter to SaskPower employees.
The move was the most significant energy-related action made by this government over the last decade. It breathed new life and hope into the communities of Estevan, Coronach and Bienfait, which Pipeline Online has reported on extensively. Between the two mines and three power plants, 1100 direct jobs were saved, instead of certain doom that was expected as a result of the federal coal regulations. Those regulations require conventional coal-fired power generation (without carbon capture) to shut down by December 31, 2029. That’s three years and nine months from today. According to Estevan Mayor Tony Sernick, that community alone was expecting to lose a third of its population as a result. But if the province carries through with this refurbishment, there will be ample work for years to come.
These are the numbers of coal jobs in Saskatchewan, according to the Saskatchewan First Energy Security Strategy and Supply Plan, released on Oct. 20, 2025.
But what will that refurbishment actually look like? Buried deep in the “Complete Responses to Interrogatories from the Saskatchewan Rate Review Panel [2026 and 2027 Rate Application],” is the most detailed plan Pipeline Online has seen to date. Below is the verbatim text from that document.
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Note that the nameplate capacities for each of the coal units are rounded up from otherwise published numbers SaskPower has on its website showing details about its grid.
The timeline lays out a plan to start “repowering” individual generating units one at a time starting in 2027 with Boundary Dam Unit 5 and concluding in 2035. Currently BD4 and 5 are officially retired, but the minister’s plan is to bring those back in service soon. That additional power capacity was a critical factor in attracting a new $12 billion Bell data centre for Regina announced March 16. Its requirements almost exactly match the nameplate output of those two units combined. That’s not a coincidence.
All seven coal-fired units are on the list, and notably Boundary Dam Unit 3 – the one with a carbon capture facility attached to it – is listed for repowering in 2034. That’s 20 years after it officially went online in 2014.
Also of note is how this timeline meshes with SaskPower’s stated timeline for small modular reactor development. That timeline expects the first unit to go online in 2034 for commissioning. That would mean it would be going online right around the time the last coal units are being repowered.
It also notes, “Currently, SaskPower has no plans for the addition of carbon capture and storage facilities to any other power generating unit.”
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Context
All of this assumes a change in government does not reverse this path, and that the current Saskatchewan Party government follows through with the coal refurbishments. In recent weeks, the Official Opposition New Democratic Party has criticized coal refurbishment as not being the least expensive option, and has expressed an interest in using natural gas and renewables instead, as a bridge to nuclear power. Their detailed plan has not been released to date. If they form government at any time over the next two, possibly three elections, they could choose to stop coal refurbishments in its tracks.
All of this is in the context of the current ongoing construction of the natural gas-fired 370 megawatt Aspen Power Station near Lanigan, whose output will principally service the BHP Jansen mine being built nearby. Aspen is expected to cost $1.7 billion, more than double the $825 million cost of the recently completed Great Plains Power Station at Moose Jaw. That power station went online in December, 2024. And its predecessor, Chinook Power Station at Swift Current, went online in 2019 at a cost of $605 million. Significantly, all three of these stations are essentially clones of each other, showing an almost tripling of cost per unit from the first to the third power station.
And since about 90 per cent of the natural gas SaskPower uses for its power stations comes from Alberta, increasing natural gas consumption and gas prices means sending potentially billions to Alberta per year, whereas Saskatchewan owns nearly all the coal it burns, and charges itself next to nothing for it. It does, however, pay Westmoreland Mining about a third of a billion dollars per year to mine it, with much of that money remaining in the communities of Estevan, Bienfait and Coronach.
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Chinook cost $1.6 million per megawatt to build, while Aspen is expected to cost $4.6 million per megawatt to build. The coal refurbishments, on the other hand, vary from $3.3 million per megawatt to restore BD4 to $1.3 million per megawatt for BD5. The two Poplar River units and the one at Shand are expected to cost about $1.2 million per megawatt to refurbish. BD6 is the cheapest, at $1.1 million per megawatt in capacity.
Boundary Dam Unit 5
By those metrics published in this report, building new natural gas will be more than three times the cost, per megawatt, of restoring much, but not all, of the coal fleet. Even if their cost doubled compared to the estimates, nearly all the units would still be cheaper to refurbish than to build new natural gas, which is a firm number from current work.
Put another way, replacing 1,500 megawatts of coal – the entire fleet – with natural gas power stations at the same cost of Aspen, would be $6.9 billion. This plan lists the total cost at $2.6 billion.
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Here is the excerpt on coal from the document:
Question:
With reference to the statement on page 5 of the application that SaskPower is executing a program to life-extend its coal-fired generation facilities for 25 years, please:
- Provide a detailed description of the Coal Fleet Repowering Initiative including current estimated timelines to refurbish each of the units and associated costs per unit.
Response:
In response to the Government of Saskatchewan’s Saskatchewan First Energy Security Strategy and Supply Plan, SaskPower launched the Coal Modernization Program. It will extend the operation of all seven of its coal-fired generating units to 2050. The generating units and associated infrastructure included in this program comprise:
- Boundary Dam Power Station (located south of the City of Estevan): Unit 3 (BD3 = 150 MW),
- Unit 4 (BD4 = 150 MW), Unit 5 (BD5 = 150 MW), and Unit 6 (BD6 = 300 MW)
- Shand Power Station (located east of the City of Estevan): Unit 1 (SH1 = 300MW)
- Poplar River Power Station (located east of the Town of Coronach): Units 1 and 2 (PR1 & PR2 = 300 MW each)
- The coal mines near Estevan and Coronach.
- Transmission infrastructure at all coal-fired power stations.
Listed below is the assessment schedule/status of each unit:
- BD0/6: Assessment completed, undergoing governance reviews
- PR0/2: Assessment to be completed in April 2026 (60% complete)
- PR1: Assessment to be completed in September 2026 (15% complete)
- SH0/1: Assessment to be completed in December 2026 (5% complete)
- BD3, BD4 and BD5 condition assessments to be complete in April 2027 (0% complete)
Order of magnitude estimates (+100% / – 50%) were developed in January 2025, drawing on data from the BD3 (2014) and PR1 (2008) Life Extension projects. Below are order of magnitude estimates for each unit’s major life extension.
Poplar River Power Station Units 1 and 2. Photo by Brian Zinchuk
The major life extension/unit rebuild schedule is currently as follows, and is subject to change:
- BD6 Repowering – Phase I in 2028 and Phase II in late 2029 and 2030
- PR0/PR2 Repowering in 2031
- SH0/SH1 Repowering in 2032
- PR1 Repowering in 2033
- BD3 Repowering in 2034
- BD5 Repowering – Phase I in late 2027 and early 2028, and Phase II in 2035
- BD4 Repowering in 2035
- Note: some life extension work is being advanced and/or staged outside of these dates to ensure unit reliability, optimize construction, and manage execution risks.
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Question:
Provide copies of any and all financial and economic analyses conducted by SaskPower or the provincial government to confirm extending the life of coal facilities would be the lowest cost generation option over the long term compared to other potential generation sources.
Response:
Based on the direction to extend the life of coal rather than follow the Clean Electricity Regulations, SaskPower has reduced projected capital expenditures by more than $21 billion to 2050. This was achieved by avoiding the construction of new natural gas generation power plants equipped with Carbon Capture, and avoiding the construction of new transmission and distribution infrastructure associated with additional renewable generation. External consultants have estimated the cost of refurbishing SaskPower’s 1500MW of existing coal facilities at $2.6 billion, while the cost of a new 370 MW combined cycle gas generating plant is currently $1.7 billion.
The decision to extend the life of existing coal-fired generation assets was not driven by a determination that coal life extension represents the lowest-cost generation option. Rather, the decision reflects a strategic policy choice grounded in the principles of energy security, system reliability, affordability, and the need to ensure sufficient electricity supply to support economic growth in Saskatchewan.
Shand Unit 1. Photo by Brian Zinchuk
The provincial Energy Security Strategy sought to strengthen and expand the reliability and capacity of Saskatchewan’s electricity system through a diversified, all-of-the-above approach to generation investment. This approach included weighing the value and cost of extending legacy generation assets against prevailing trends and constraints associated with new-build options. As part of this assessment, cost-benefit considerations incorporated temporal and system-specific factors, including the ability to maintain existing operating units, demand and supply-chain constraints affecting new natural gas generation, and the relative certainty associated with in situ fuel supplies available in Saskatchewan, including coal and uranium. Ultimately, the policy decision was anchored in prioritizing certainty and security of supply to ensure ongoing system reliability.
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Saskatchewan’s electricity system faces unique structural and transitional challenges, including limited legacy hydro resources, increasing demand associated with economic development, and the requirement to maintain reliability while transitioning to a lower-emissions grid. In this context, coal life extension provides dependable baseload capacity that supports system adequacy, operational flexibility, and diversity of supply, while reducing exposure to fuel, technology, and supply-chain risks during a period of significant change.
Question:
Please discuss the implications for SaskPower’s existing coal supply contracts and provide a discussion of when its current contracts expire and timelines for future coal supply contract negotiations.
Response:
In the current contracts, supply and delivery of coal expires at the end of 2029. Negotiations have already started to amend the current contracts and to execute new contracts for the supply and delivery of coal starting in 2030. It is estimated that the new contracts and amendments to the existing contracts will be complete in 2028.
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Carbon capture
Question:
Please discuss whether SaskPower will be able to make use of its existing carbon capture and storage facilities when the repowering initiative is complete and whether or not SaskPower has plans for additional carbon capture and storage facilities.
Response:
In 2013-2014, Boundary Dam Unit 3 was redesigned for carbon capture integration that involved major investments in the boiler, steam turbine & generator, controls, electrical balance of plant, feedwater and steam systems. In 2034, BD3 will be repowered to life extend the operation of the power generating unit. This will involve like for like replacement of assets to extend operations to 2050. At this time, it is anticipated the carbon capture and storage facilities will continue to operate after BD3 is repowered.
Currently, SaskPower has no plans for the addition of carbon capture and storage facilities to any other power generating unit.
Join the Pipeline Online Podcast Live on X at 1 p.m. on Monday, March 30. Ron Wallace and Tammy Nemeth are our guests. Wallace is a former member of the National Energy Board, and Nemeth is an energy analyst we’ve had on before. Why does Canadian-produced oil and gas need to be decarbonized, but imported oil and gas, or product from Newfoundland, does not? That’s a really good question… Watch live on X here.
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As always, here’s some related content to this coal story: