Solar thermal can produce clean heat to run processes that cause a third of global carbon emissions. In this article, I argue that a $1 Trillion pot of gold may await the right solutions.
Due to costs and other barriers, solar thermal’s present footprint on the global energy production map is negligible. Industry experts agree that the solar thermal industry needs to reduce the cost of the heat they produce and overcome a host of barriers and that if they manage to do so, the market potential for their solution should be significant (e.g. ). But it is hard to find estimates of how significant the market opportunity is and at what prices solar thermal needs to be offered to the market to realize the potential.
Heat is heat no matter how it is produced. Consequently, most end-users producing products for price-sensitive markets are prone to go for the cheapest source which today is fossil fuels. In this article, I will try to estimate the price tag solutions must meet to compete head-to-head with natural gas in the US market and in Europe. I will also estimate the market potential for solar heat for industrial processes in the range of 120ºC-220ºC. In my next article “Solar Heat – a Roadmap to Below $25/MWh”, I identify barriers to reaching these price targets and discuss how to circumvent other
My estimates are based on several assumptions all of which can be discussed. Please do so in the ‘Comments’ section. The more we discuss, the wiser we get. The wiser we get, the closer we may get to the pot of gold.
First, a look at the market for energy as it may evolve towards 2050. Note how heat below 400ºC despite increased electrification, continues to show a steady annual demand of slightly more than 10,000 TWh.
The Role of Storage
Seasonal heat storage needs to be developed for solar thermal to fully replace fossil fuels. Until this potentially happens, solar thermal solutions need to be working in integration with fossil-based systems. A simple method for
integration is to produce heat to existing storage tanks.
For day/night storage pressurized water tanks are available and able to do the job up +200ºC. Some large industrials have such tanks installed already today to protect against risks of short-term interruption of their gas supply.
Day/night storage at this temperature level should allow industries to cover 30-40% of their demand. The coverage potential depends on how much the sun shines (expressed as DNI). For my estimates below, I assume DNI<1600=30%, DNI 1600-2000=35%, and DNI>2000 = 40%.
My analysis of the market opportunity goes as follows:
- According to NREL (National Renewable Energy Laboratory), US industries annually use around 1500 TWh of process heat in the 120ºC-220ºC temperature range .
- The cost of producing this heat using natural gas (NG) depends on local NG prices. It is those prices solar thermal ultimately needs to meet. Figure 2 below shows NG 2018/2019-prices by US-state .
- Solar thermal heat gets cheaper to produce the more the sun shines. For data on the annual amount of sunshine, please also refer to the map below .
**Figure 2:** Industrial natural gas prices in the USA 2018\*/2019 combined with a map of the average DNI (direct natural irradiation) in the period 1999-2018 [5+6].
- If industrial process heat demand is distributed similarly to the population distribution in the US  and if 30-40% the total 120ºC-220ºC process heat demand can be covered by solar heat production combined with
day/night storage in pressurized water tanks, then cost-competitive solutions are looking at a 290,000 MW opportunity.
- Assuming 25 year’s depreciation, 4% cost of capital (how to get to 25 years & 4% will be discussed in “Solar Heat – a Roadmap…”), maintenance of $5/MWh, and market prices per state set to match the cost of natural
gas in each state, then the generation of process heat in the 120ºC-220ºC range represents a $180 billion opportunity for solutions capable of moving down a cost curve from $820,000/MW installed in California where
the 29,000 MW potential represents a $24 billion opportunity towards $90,000/MW in Oklahoma representing a $285 million market potential. All of this assuming the solution providers are capable of eliminating the
end-users’ perceived risks. How to eliminate these risks is also discussed in “Solar Heat – a Roadmap…”.
The addressable market will increase with the introduction of cost-competitive heat storage technologies, and with the development of methods to use solar-generated heat to pre-heat higher temperature processes. E.g., pre-heating the feedwater in fossil-fired power plants in the US could increase the market opportunity with an additional 50,000 MW solar thermal capacity , thereby adding $25-30 billion to the US market potential.
If providers of solar thermal solutions turn to the world outside the US, e.g. Europe, then they are generally looking at markets with much higher industrial NG prices. The figure below shows minimum NG prices (in €) for large-scale end-users across Europe. Again, on the background of a map illustrating the local solar conditions.
I estimate the European consumption of industrial process heat in the 120ºC-220ºC range to be 1860 TWh [4+11+12]. Assuming DNI 1500 as an average, an average natural gas price of $35/MWh , and keeping other assumptions the same as for the US, this should allow for a price of $820,000/MW and a potential for installing 370 GW resulting in an opportunity worth $370 billion including service and maintenance.
For the rest of the world, I haven’t looked into the numbers in similar detail, but given the total size of the global energy consumption [2+3] and given most of the world outside the US has energy prices similar to Europe [e.g. 13], the total opportunity should be at least in the vicinity of $1 Trillion.
How much are end-users willing to pay for solar heat?
As the cost of solar field investment and maintenance is known, the price of the energy produced is also known. Facing the potential of increased costs from carbon emission taxes, increased pressure from climate concerned consumers, and other possible levies if governments start to factor the costs of particle emissions’ effect on their health systems and the general uncertainty from ever-fluctuating energy prices, many end-users are willing to pay a premium in exchange for the certainty of energy prices.
For example, in 2018 the average NG price across the US states was $21.2 per MWh but since 2015 the average monthly price has fluctuated in the range of $15-25 per MWh. To protect themselves against the risks of fluctuating energy prices, companies looking for stable prices can buy futures. The present average price for futures from 2020-2032 is $8.6 per MWh . Likely, such a premium is only attractive to companies with very energy-intensive processes and investors betting on increasing prices. Still, the existence of the futures shows that fixed prices may justify a premium.
Based on this reasoning, I assume that end-users in the US on average are willing to pay a 15% premium on top of last year’s NG prices in exchange for securing a fixed energy price.
How much is the market willing to pay for a solar field?
The cost of producing solar heat depends much on how much the sun shines. However, end-users can only be expected to care about how the cost of solar heat compares to heat produced by natural gas. As discussed above, for the US this means prices in the range of 8-34/MWh and around $35/MWh in Europe. Assuming an average NG price of $25 in the most relevant states, I have plotted the unsubsidized cost targets (in $/MW) as a function of the solar irradiation in the figure below.
I believe the $25/MWh target is within reach. Getting there requires a look into the cost of land and heat transportation and an adjustment of the presently preferred business model in the solar thermal industry. This I discuss in “Solar Heat – a Roadmap to Below $25/MWh”.
Thank you for reading,