Solar Tower with Thermal Energy Storage: A “Consolidated” Technology with a Single Plant of Decent Size Built on Earth Producing Less Than 30% of the Planned Electricity

Guest essay by Albert Parker

If we consider the latest (2017) National Renewable Energy Laboratory Annual Technology Baseline data, [1] and [2], they say current representative technology for concentrating solar power is molten-salt power towers with 10 hours two-tank thermal energy storage. They admit the first (and only) large molten-salt power tower plant with 10 hours of storage is Crescent Dunes, 110 MW, commissioned in 2015.

Their concentrated solar power workbook is based on purely hypothetical solar towers with direct two-tank 10 hours thermal energy storage supposed to deliver annual capacity factors (ratio of actual electricity delivered in a year vs. the product of the installed capacity by the number of hours in a year) largely exceeding the 50% mark, more precisely 56% in an insulation class 3 location (Las Vegas, NV) or 59% in an insulation class 5 (Dagget, CA).

These capacity factors of 56% and 59% correspond to an annual electricity production per unit capacity (power) of 4,906 and 5,168 kWh/kW that are nowhere to be seen even close in plants on Earth.

If we look at the operational Concentrated Solar Power stations of capacity above even only 50 MW in the entire world, this list includes 34 stations, 31 of them are parabolic trough, a much more consolidated and reliable concentrated solar power technology, 1 is Fresnel reflector, and only 2 of them are solar tower.

The 2 power stations are both in the United States, the 377 MW Ivanpah Solar Electric Generating System and the 110 MW Crescent Dunes Solar Energy Project.

As actual electricity production of these plants is available from the United States Energy Information Administration [3], we may certainly check if the numbers by NREL are right.

As a comparison, we also consider the data of a more reliable concentrated solar power parabolic trough plant similarly recently built, the 250 MW Genesis, that has no thermal energy storage.

For the 377 MW Ivanpah, the planned electricity production was 1,079,232 MWh per year, corresponding to a capacity factor of 32.68%, with minimal support by burning natural gas.

For the 110 MW Crescent Dunes, the planned electricity production was 500,000 MWh per year, corresponding to a capacity factor of 51.89%.

For Genesis, the planned electricity production was only 580,000 MWh per year, corresponding to a capacity factor of 26.48%.

Figure 1 presents the monthly capacity factors of Ivanpah, Crescent Dunes and Genesis.

Worth to mention, the monthly capacity factors vary according to the season.

To deliver an annual capacity factor of 56% or 59% solar only, the summer capacity factors should be much larger than that to compensate the lower spring/fall and more than that winter capacity factors.

Ivanpah has no thermal energy storage, but boost by combustion of natural gas. So far, it has been able to reach a 21.29% annual capacity factor only not accounting for the significant natural gas combustion. As the natural gas can be burned better in a combined cycle gas turbine plant, the actual annual capacity factor is reduced to 14.42% when corrected for the consumption of natural gas in a combined cycle gas turbine plant.

Crescent Dunes is the current representative technology for concentrating solar power by NREL.

The project has delivered so far much less than the projected electricity production, a 13.21% annual capacity factor in the best year.

The plant had a major issue in the thermal energy storage that prevented electricity production for a long time, and is not recovering yet.

The more reliable Genesis has been able to produce electricity reaching an annual capacity factor of almost 30% without any boost by natural gas combustion, a value even better than the expected.

It does not seem appropriate to propose as “current technology” a technology that does not seem mature yet, while downplaying what is already working much better.

The thermal energy storage is not such a well proven and mature technology. Similarly, but marginally better, the solar tower technology is much more troublesome than the parabolic trough technology.

While NREL does not update the numbers to match reality, the South Australian government and the Federal Government of Australia have recently decided to build (about) same of Crescent Dunes power plant by same developer in Port Augusta, South Australia [4], [5].

Fig. 1 – Monthly capacity factors for the Ivanpah, Crescent Dunes and Genesis concentrated solar power plants. Design annual capacity factors are 32.68% for Ivanpah (but with minimal support from the burning of natural gas), 51.89% for Crescent Dunes, and 26.48% for Genesis. Ivanpah has been able to reach a 21.29% annual capacity factor in 2016 only not accounting for the significant natural gas combustion. Crescent Dunes has delivered a 13.21% annual capacity factor in 2016. Genesis has been able to produce electricity reaching an annual capacity factor of almost 30% in 2006.

References

[1] National Renewable Energy Laboratory (NREL). 2017 Annual Technology Baseline. Golden, CO: National Renewable Energy Laboratory. www.nrel.gov/analysis/data_tech_baseline.html

[2] National Renewable Energy Laboratory (NREL). Concentrating Solar Power. atb.nrel.gov/electricity/2017/index.html?t=sc&s=ov

[3] Energy Information Administration (EIA). Electricity data browser – Plant Level Data.

Available online: www.eia.gov/electricity/data/browser/

[4] ABC News (2017), Solar thermal power plant announced for Port Augusta ‘biggest of its kind in the world’.

www.abc.net.au/news/2017-08-14/solar-thermal-power-plant-announcement-for-port-augusta/8804628

[5] Renewable Economy (2017). Aurora: What you should know about Port Augusta’s solar power-tower.

reneweconomy.com.au/aurora-what-you-should-know-about-port-augustas-solar-power-tower-86715/

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