Manitoba Invests $4 Million in First Large-Scale Geothermal District Manitoba is moving geothermal energy from individual buildings toward large-scale community heating and cooling, with the provincial government committing up to $4 million to a planned geothermal district at the University of Manitoba's Fort Garry campus in Winnipeg. The project, known as Southwood Circle , is planned as an approximately 80-acre mixed-use development that could eventually include more than 1,000 homes alongside office, commercial, retail and hospitality space. According to the Manitoba government, the geothermal system is expected to provide heating and cooling for at least 1,000 new homes by 2028 , making it the province's first large-scale geothermal district energy system. The announcement forms part of Manitoba's new Net Zero Action Plan , released on September 9, 2026. The plan sets out 90 actions intended to guide the province toward its stated net-zero emissions objective by 20...
Geothermal Isn't Expensive: The Reservoir Always Has the Final Say
Somewhere beneath a volcanic ridge, a drill bit is turning through rock that has not moved in two million years. It costs money every second it turns. And nobody on the surface — not the engineer, not the financier, not the minister who announced the megawatts — knows yet whether that well will produce steam or silence.
That single moment explains almost everything people get wrong about geothermal energy.
Geothermal is routinely described as expensive, slow, capital-hungry and haunted by drilling risk. Investors are reminded that tens of millions can disappear underground before a single megawatt reaches a grid. All of that is true.
But it is not the whole truth.
The uncomfortable question the industry keeps avoiding is this: is geothermal expensive, or is the way we develop geothermal making it expensive?
Those are two completely different problems. One is geology. The other is us.
Why Geothermal Refuses to Behave Like Other Renewables
Solar has become a shipping and logistics exercise. Panels arrive with datasheets, degradation curves and warranties. Wind has become an engineering procurement exercise: measure the resource, pick the turbine, model the yield. Gas is a catalogue purchase — order the capacity, pay the fuel bill.
Geothermal offers no catalogue.
Before a developer can promise anything, they must understand what nature quietly assembled beneath their feet over geological time. Heat. Permeability. Fracture networks. Fluid chemistry. Pressure. Recharge. None of it is visible. All of it decides whether the project is a business or a write-off.
And here is the part no amount of capital can change:
There is no presentation that alters a reservoir.
There is no board resolution that forces a well to flow.
There is no policy paper that improves permeability in a formation nobody properly understood.
The reservoir always has the final say.
The 10,000 MW Problem
The most seductive number in geothermal is the resource estimate. It is also the most dangerous.
Countries announce thousands — sometimes tens of thousands — of megawatts of potential. Studies identify promising volcanic systems. National plans publish confident totals. Conferences applaud.
Investors, however, ask something far less romantic:
How many megawatts can you actually deliver, at what cost, and by when?
When a field is repeatedly presented as a 10,000 MW opportunity but delivers a modest fraction of it, the problem has stopped being the size of the resource. The problem now lives in the long, unglamorous chain between an estimate and a turbine: exploration, geological interpretation, geophysics, well targeting, drilling strategy, well design, reservoir engineering, procurement, project management, financing, offtake contracts, transmission, operations — and above all, execution.
A theoretical 10,000 MW that cannot produce bankable electricity is not an investment proposition. It is a geological possibility still waiting for someone competent to convert it.
Uncertainty Is Not an Excuse — It's a Discipline Requirement
The subsurface is genuinely heterogeneous. Permeability varies over metres. Temperature varies with depth in ways models only approximate. Chemistry corrodes and scales. Pressure shifts once production begins. Reinjection changes reservoir behaviour in ways that can take years to reveal themselves. Wells outperform, or humiliate, their forecasts.
That uncertainty is real and permanent. But it should never become a shield.
Quite the opposite. Geological uncertainty means geothermal demands more discipline, not less.
Every disappointing well should generate knowledge. Every drilling campaign should sharpen the geological model. Every reservoir response should refine production strategy. Every equipment failure should improve the next specification.
When that learning loop breaks, something expensive happens: the industry starts paying full price, repeatedly, for the same mistake. That is not geological risk. That is institutional forgetfulness with a drilling invoice attached.
The Reservoir Does Not Read Corporate Narratives
There is often a wide gap between what a geothermal project claims and what its reservoir has actually demonstrated.
A deck can show thousands of megawatts. A feasibility study can contain elegant simulations. A company can publish beautiful photographs of a rig at sunset. A delegation can attend every international forum on the calendar. A government can announce a target with genuine conviction.
None of it produces steam.
Steam comes from rock, heat and permeability. The reservoir does not respond to narrative. It responds to geology — and to the quality of the engineering aimed at it.
Which is why geothermal needs a culture of evidence rather than announcement. The numbers that matter are unglamorous and specific: well productivity, production test results, decline rates, reservoir pressure trends, injection response, drilling days per well, non-productive time, cost per successful well, capacity factor, and levelized cost.
Those are the metrics that build investor conviction. Everything else is atmosphere.
Drilling Must Stop Being the Industry's Permanent Alibi
Drilling is unquestionably the largest single source of geothermal risk and expenditure. But "geothermal is expensive because drilling is expensive" is where analysis usually stops — and that is intellectually lazy.
The better question is: why is the drilling expensive?
Is the geology genuinely difficult, or poorly understood? Are wells being targeted with the best available subsurface imaging, or with institutional habit? Are rigs utilised efficiently, or waiting on parts, permits and paperwork? Is equipment procured competitively? Are crews trained to current standards? Are well designs optimised for this formation, or copied from the last one? Is non-productive time measured and attacked week by week? Are lessons from well seven visible in well eight? Are contractors incentivised for performance or for time on site? Does procurement create delay that quietly becomes cost? Is drilling performance benchmarked with the same intensity that a competent oil and gas operator applies as a matter of routine?
These questions are uncomfortable. They are also where the savings live.
If one development consistently needs far more time and money to drill comparable wells than another, the geological explanation deserves investigation — and so does the operational one. Geology matters enormously. But geology cannot be allowed to become a blanket receipt for every failure.
The Real Cost of One Unproductive Well
A failed or underperforming well is never just a line item.
It delays the project. It increases financing requirements. It dents investor confidence. It forces additional drilling. It rewrites the reservoir model. It complicates debt servicing. It pushes back first generation. And in a young market, it can quietly damage the credibility of an entire country's geothermal story.
Then the feedback loop begins.
High drilling costs create a perception of expensive geothermal. That perception raises the cost of capital. Expensive capital makes projects less competitive. Less competitive projects attract less investment. Less investment means fewer wells. Fewer wells mean no learning curve, no supply-chain scale, no cost reduction.
The industry ends up trapped inside its own cost narrative — a prophecy financing itself.
Discipline Is the Second Geothermal Resource
Developers speak of heat as the resource. Technically correct. Commercially incomplete.
There is a second resource, and it is scarcer than heat: discipline.
Discipline is deciding from evidence rather than institutional comfort. It is abandoning a drilling target when the data stops supporting it, even after money has been spent defending it. It is redesigning a programme that is visibly failing instead of completing it for the sake of the schedule. It is investigating why a well underperformed rather than blaming the formation and moving on. It is measuring procurement efficiency. It is knowing the true cost of a single drilling day. It is asking why a rig is idle today. It is holding contractors and project teams to outcomes. It is refusing to confuse activity with progress.
Because scale is not capability.
An organisation can employ thousands of people and still have a productivity problem. It can own its own rigs and still have a drilling problem. A country can sit on world-class geothermal potential and still have a development problem.
Headcount does not generate megawatts. Execution does.
The Offtaker Problem Nobody Wants to Discuss
Geothermal economics do not end at the wellhead. A technically excellent project still needs a commercial ecosystem capable of carrying it.
If the electricity buyer cannot reliably pay for contracted power, project economics erode regardless of reservoir quality. If tariffs do not reflect the cost structure of firm baseload generation, investment stalls. If power purchase agreements are weakly structured, lenders retreat. If transmission slips behind the power plant, finished capacity sits stranded, generating interest instead of revenue.
So geothermal cannot be assessed purely as a drilling problem. It is a whole-system problem. Reservoir, wells, gathering system, turbine, grid, offtaker, regulator and financing structure must all function together.
One weak link is enough to break the investment case — and it is rarely the link everyone was watching.
Policy Can Make Geothermal Look Expensive When It Isn't
Geothermal economics are spread across decades. Exploration happens years before revenue. Development capital is committed long before the first electricity sale. That timeline makes the resource unusually sensitive to institutional behaviour.
Investors need regulatory stability, predictable permitting, bankable contracts and unambiguous resource rights. When those are missing, uncertainty simply migrates from the subsurface to the statute book — and it is priced exactly the same way.
Investors have already accepted that the reservoir is uncertain. They should not also be asked to price avoidable policy uncertainty on top of it.
Because when licensing is slow, tariffs unclear, procurement opaque and offtake arrangements unpredictable, capital gets more expensive. And when capital gets more expensive, geothermal is blamed again for being expensive.
The industry urgently needs to separate intrinsic geothermal risk from self-inflicted institutional risk. The first is geology's price. The second is a choice.
The Per Diem Culture Is Not an Energy Strategy
There is a deeper institutional problem that geothermal development can no longer politely ignore: some projects are run as administrative activities rather than commercial engineering enterprises.
Meetings are held. Workshops are convened. Delegations travel. Reports are compiled. Photographs are circulated. Conferences are attended. Targets are re-announced with new dates.
And the only question that matters goes unanswered:
What physically changed in the resource?
Did drilling cost per well fall? Did the success rate improve? Did steam availability increase? Did generation rise? Did maintenance costs decline? Did project development get faster? Did investors receive better risk-adjusted returns?
If the honest answer is no, then activity has been mistaken for progress — an expensive substitution.
Geothermal cannot be developed as a nine-to-five exercise in which attendance quietly becomes the measure of success. The reservoir does not recognise attendance. It recognises engineering.
Innovation Must Survive Contact With the Reservoir
None of this is an argument against innovation. Geothermal needs it desperately.
Advanced and directional drilling, high-temperature materials and electronics, better logging tools, reservoir stimulation, machine learning applied to subsurface data, sharper geophysics, automation and improved well control can all make this industry meaningfully more productive.
But every innovation should face one question: does it improve the economics or technical performance of the resource?
If a technology cannot shorten drilling time, sharpen targeting, raise well productivity, extend equipment life, deepen reservoir understanding or reduce project risk, its commercial value must be interrogated — however impressive the demonstration.
Geothermal does not need innovation theatre. It needs innovation that survives contact with the reservoir.
What the Best Geothermal Developers Actually Understand
The strongest operators in this industry grasped something early that others treat as a detail: the reservoir is not an input to the business model.
The reservoir is the business model.
Everything else is derived from it. Production strategy must reflect reservoir characteristics. Drilling must reflect geological understanding. Injection must reflect observed reservoir response. Generation capacity must reflect sustainable steam availability rather than optimistic aggregation. Expansion must reflect demonstrated field performance rather than theoretical potential.
That is why serious geothermal companies invest in reservoir engineers, geologists, drilling engineers, production engineers, data scientists and commercial professionals who genuinely work together.
The industry cannot afford silos where the commercial team sells capacity the reservoir team has not demonstrated, or where drilling repeats designs that reservoir performance already discredited. Silos are how good resources become disappointing assets.
From Resource Potential to Bankable Megawatts
The most useful change geothermal could make is linguistic — and therefore cultural.
Stop asking how much geothermal energy exists underground. Start asking:
How much bankable electricity can this reservoir sustainably deliver?
The difference between those two questions is the difference between a brochure and a business.
Bankable megawatts require evidence. They require successful wells, sustained reservoir performance, infrastructure, a creditworthy offtaker, financing, credible cost estimates — and an organisation demonstrably capable of executing.
Only then does potential become an investment opportunity rather than a talking point.
The Industry's Best Asset Is Its Own History
Geothermal has decades of global operating experience. That should be its sharpest competitive advantage, and it is largely underused.
Every field is a case study. Some reservoirs have shown remarkable longevity across half a century. Others declined faster than anyone modelled. Some drilling campaigns achieved world-class productivity. Others struggled through avoidable failures.
All of it is data.
Cost histories should be studied. Well designs should be compared across basins. Reservoir behaviour should be modelled against outcomes, not intentions. Drilling performance should be benchmarked internationally rather than locally. Procurement structures should be examined for where money quietly leaks.
And failures should be treated as expensive sources of knowledge, not embarrassments to be buried beneath the next presentation. A failure you learn nothing from is the only truly wasted well.
Investors Don't Need Another Geothermal Speech
Investors already understand the climate argument. They know geothermal delivers firm, low-carbon electricity. They know it complements variable renewables. They understand direct use, district heating and industrial heat. They are watching enhanced geothermal systems closely.
They do not need to be persuaded that geothermal matters.
They need evidence that the business works: numbers, risk management, credible timelines, reliable offtake, competent execution, and confidence that the organisation holding the licence understands both the reservoir and the balance sheet.
Climate rhetoric attracts attention.
Economics keep investors in the room.
The Harsh Truth: Geothermal Does Not Forgive Incompetence
This is the conclusion the sector finds hardest to say out loud.
Geothermal is unforgiving. A poor decision underground becomes an enormous financial problem above ground, and it cannot be quietly corrected later.
A badly targeted well consumes millions and returns nothing. A delayed project accumulates interest while producing no revenue. A flawed reinjection strategy can compromise reservoir performance for years. A dysfunctional drilling operation multiplies cost with impressive consistency. A weak offtake agreement destroys bankability regardless of resource quality. And a weak institution can turn a world-class field into a chronically underperforming asset.
So geothermal should not be marketed as easy. It isn't.
But difficult is not the same as uneconomic — and that distinction is where the industry's future is decided.
The Heat Beneath Our Feet
There is an extraordinary resource under the surface of the Earth.
It does not vanish at sunset. It does not wait for wind. It can deliver heat and power continuously for decades, through droughts, fuel-price shocks and cloudy seasons alike.
But unlocking it requires more than ambition.
It requires scientific discipline. Engineering excellence. Commercial realism. Institutional accountability. Policy that makes sense. Investors who genuinely understand subsurface risk. And organisations willing to listen to what the reservoir is actually telling them, especially when the message is inconvenient.
The industry can keep publishing theoretical resource numbers. It can keep announcing ambitious targets. It can keep describing enormous potential.
But eventually the well has to be drilled. The steam has to flow. The turbine has to turn. The electricity has to reach the grid. The offtaker has to pay. The investor has to earn a return. And the reservoir has to stay productive.
Everything else is commentary.
The Alphaxioms Position
Geothermal should stop apologising for its geology and get dramatically better at understanding it.
It should stop hiding weak execution behind the complexity of the subsurface. It should stop confusing theoretical potential with bankable capacity. It should stop celebrating activity while measurable outcomes remain absent. It should stop treating drilling as an unavoidable black box of rising cost.
It should benchmark relentlessly and publish honestly. It should reward successful wells, falling costs, higher productivity and reliable generation. It should build institutions capable of matching the complexity of the resource they have been entrusted to develop.
Because geothermal is not simply another renewable technology competing for attention. It is a long-term industrial commitment to the heat beneath our feet.
And that commitment is only ever settled in one place.
The reservoir always has the final say.
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