Baseload vs Peaker: Why Industrial Sites Are Paying the Wrong Price

Industrial electricity buyers have been systematically mispriced for decades. Not because utilities are acting in bad faith, but because the rate structures that govern industrial tariffs were designed around a grid where peaking capacity was the scarce resource. That underlying assumption is eroding, and if you are buying power for a 24/7 manufacturing operation, the rate structure is increasingly working against you.

Geothermal baseload does not fix your utility bill. But it changes the math when you start evaluating alternatives, because the cost structure of geothermal is almost perfectly inverse to the cost structure of the peaker-driven tariffs most industrial buyers are on.

How Peaker Pricing Entered Industrial Tariffs

The story starts with how utilities recover capital. Building a peaking plant that runs 200 to 400 hours per year requires recovering the capital cost of that plant across every kilowatt-hour sold, not just the hours the plant runs. The result is a rate structure with two components: a volumetric energy charge and a demand charge. The demand charge, based on your peak 15-minute or 30-minute consumption in the billing period, is how the utility ensures that the peaker plant capital gets recovered whether or not it runs.

For a manufacturer with a relatively flat load profile, this structure is punishing. You might draw 8 megawatts continuously and spike to 11 megawatts for one 30-minute window because a heat treatment oven cycled on alongside your normal production load. That 11-megawatt peak sets your demand charge for the entire month, even though your average draw was 8.2 megawatts. The effective cost of that single demand event, spread over the billing period, can easily be $40,000 to $80,000 depending on your tariff, your state, and your utility.

This is the dirty secret of industrial electricity pricing: the price you pay per megawatt-hour has very little relationship to the cost of serving your actual load. It has a lot to do with the worst 30 minutes of your month.

Capacity Factor and Why It Matters for Alternatives

The central difference between peaking capacity and baseload capacity is capacity factor. A peaker plant runs at a capacity factor of 5 to 15 percent. A utility-scale solar installation in the American Southwest runs at 25 to 28 percent capacity factor. Wind at good sites runs 35 to 45 percent. Geothermal runs at 85 to 95 percent capacity factor.

That difference in capacity factor is where the economics break. A geothermal unit generating at 90 percent capacity factor over a year is producing roughly 7,900 megawatt-hours per installed megawatt. A solar installation at 27 percent capacity factor produces about 2,365 megawatt-hours per installed megawatt. To produce the same annual energy output, you need roughly 3.3 times as many megawatts of solar nameplate capacity.

The capacity factor calculation also drives LCOE. If your capital cost for a modular geothermal unit is $3,200 to $4,500 per kilowatt of installed capacity, and you are spreading that capital cost over 7,900 megawatt-hours per kilowatt-year versus 2,365 megawatt-hours per kilowatt-year for solar, the per-megawatt-hour capital cost of geothermal is substantially lower even though the absolute capital cost per kilowatt is currently higher than solar. This math improves further as you factor in the absence of battery storage requirements.

The Demand Charge Offset

For an industrial buyer on a demand charge tariff, the value of baseload generation has a second component beyond simple energy cost offset: demand charge reduction. If a modular geothermal unit is covering your continuous base load at, say, 4 megawatts, and your grid demand peaks at 11 megawatts, your net peak demand on the utility tariff drops by 4 megawatts. Depending on your demand charge rate, which for large industrial tariffs commonly runs $12 to $22 per kilowatt-month, that reduction has a monthly value of $48,000 to $88,000 at 4 megawatts of continuous offset.

Note that this only works if the geothermal unit is actually dispatching during your demand peak. This is why the dispatch architecture matters. An intermittent generator that happens to be producing during your peak event provides demand offset only incidentally. A geothermal unit with intelligent dispatch can be managed to ensure it is producing at rated output during the billing windows that determine your demand charge, because it can produce at rated output during those windows reliably. That is the difference between baseload and intermittent from an industrial procurement standpoint.

What Geothermal Does Not Fix

We want to be direct about the limitations here, because overselling the economics does nobody any good.

First, modular geothermal does not eliminate grid dependence. A modular unit sized for an industrial campus baseload will typically cover 40 to 70 percent of annual energy demand, with the remainder coming from the grid. Demand charge mitigation depends on the unit running during demand peaks, which it can do, but you are still subject to utility tariff structures for the portion you are drawing from the grid.

Second, the economics depend on your load profile. A manufacturer with a genuinely peaky load profile, where your average demand is 30 percent of your peak demand, is a worse candidate for baseload geothermal than a manufacturer with a flat load where average demand is 80 percent of peak demand. We run a preliminary load analysis for every site we evaluate, and the load shape is one of the first things we look at.

Third, interconnection and permitting timelines are real. A modular geothermal unit serving an industrial site in behind-the-meter configuration is generally faster than a utility-scale project, but it is not a 90-day project. You are looking at 18 to 30 months from contract to operations in most Basin and Range locations, depending on permitting jurisdiction and existing infrastructure.

The Comparison That Actually Matters

When we talk to industrial procurement leads, the comparison is rarely geothermal versus solar. It is geothermal versus diesel backup plus current tariff structure versus a long-term PPA with a renewable developer. The relevant comparison is the 15-year total cost of energy including demand charges, backup generation costs, and carbon compliance costs if your state or sector has a carbon price mechanism.

On that 15-year horizon, a modular geothermal unit sized for a mid-scale industrial site looks materially better than most alternatives for sites with continuous 24/7 heat and power demand, assuming the geology is workable. The geology question is why we do the site assessment before we talk about project economics. There is no point running 15-year financial models for a site where the formation temperature at accessible depth is marginal.

The underlying point is not that geothermal is the right answer for every industrial buyer. It is that the pricing system industrial buyers are operating under was designed for a different era of the grid, and the assumptions embedded in that system are increasingly misaligned with both the carbon transition and the actual cost of producing reliable baseload power from resources that are already in the ground.