Category Archives: EuroSun2008-2

System design

The system design follows two different approaches. The first one is the “Compact System” for very low fresh water capacities between 100 and 500 l/day. The second one is a “Two-Loop System” for higher capacities.

Compact System

The low thermal capacity of MD-modules enables a quick change of feed volume flow and operation temperature without instabilities in the desalination process. Thus the MD-modules can directly be connected to a corrosion free solar thermal collector without any heat storage. Intermittent operation is possible without reasonable efficiency losses.


Fig. 4: Compact System — sketch of the principle set up (left), demo-system installed in December 2006 in

Tenerife, Spain (right)

The main components of the Compact System are a 500 l feed storage (not represented in the sketch of Fig.4, left side), 1 MD-module, a 6- 7m2 sized solar thermal collector, a pump and a PV module for the electrical power supply of the pump and control system. While the feed storage is mounted above the collectors, most of the hydraulic components are installed in a closed housing covered by the back site of the collectors. However, the cold feed water is pumped into the condenser channel. Afterward the pre-heated feed water leaves the condenser outlet and enters the solar thermal collector which is directly connected to the condenser outlet. The feed temperature is increased by about 5 to 10 K and is re-circulated to the evaporator inlet. The advantage of this configuration is its simplicity and the good efficiency because there are no additional heat losses by a heat exchanger. The disadvantage is that no common flat plate collectors can be used, but the collectors must have sea water resistant riser and header tubes.

The distillate flows to a fresh water tank. The brine rejected from the evaporator outlet of the MD module is recirculated to the feed storage. So the salt concentration as well as the temperature of feed water in the feed storage increases over the day while the content of water decreases due to distillate production. The feed storage is refilled automatically when a certain level or temperature is reached.

Six Compact Systems were constructed, installed and operated since December 2004 in Pozo Izquierdo (Gran Canaria), Alexandria (Egypt), Irbid (Jordan), Kelaa (Morocco) and Freiburg (Germany). In December 2007 an improved compact system with a maximum daily capacity of 120 litres was installed in Tenerife, Spain (Fig. 4, right hand side).

Function control

Among other disadvantages with conventional solar collector systems there is the problem that nobody realizes if they work badly or not at all or even if a forthcoming failure is near. It is

suspected that at least one forth of all solar collector systems (in Germany) is practically out of order or has even more heat losses than harvest (gain). Installations without antifreeze must work nearly error-free. Otherwise their producer will be bankrupt soon. Therefore sophisticated and reliable diagnosis software is essential. The solar controller of the Paradigma AquaSystem has these functions since 2003 and works with the same software for single family houses as well as for industrial installations of any size. It is alarming but characteristic for the German solar market that these tools were not developed until they were technically necessary whereas both the producers of conventional solar installations and the distributors of subsidies have been making do with the high failure rate for many years.

Development of process heat collectors for Solar Heat for Industrial Processes (IEA-SHC Task 33 SHIP)

Matthias Rommel

Fraunhofer Institute for Solar Energy Systems ISE, Heidenhofstr. 2, 79110 Freiburg, Germany

matthias. rommel@ise. fraunhofer. de


A large share of the energy which is needed in commercial and industrial companies for production processes is below 250°C. Solar collectors for the temperature level up to 80°C are already on the market. But new and advanced collector technologies are needed for the higher temperature levels between 80°C and 250°C.

Several new development activities on process heat collectors have been started in the last years. Many, but of course not all of them were somehow linked to Subtask C of the IEA-SHC Task 33/Solar PacesIV "Solar Heat for Industrial Processes" which was carried out under the Solar Heating and Cooling Programme SHC of the International Energy Agency IEA. The paper gives an overview on these collector developments.

Also Fraunhofer ISE is involved in different collector development activities for process heat applications. In order to carry out high quality R&D work in this field together with the solar industry, a new collector testing facility was set up which allows to measure efficiency curves for collector operating temperatures up to 200°C.

Keywords: process heat collectors, industrial process, IEA SHC Task 33, SHIP, collector testing

1. Introduction

As reported by Weiss et al. in [1], the solar thermal collector capacity in operation worldwide in 2006 equalled 127.8 GWth corresponding to 182.5 million square meters at the end of the year 2006. Of this, 102.1 GWth were accounted for by flat-plate and evacuated tubular collectors and 24.5 GWth for unglazed plastic collectors. Air collector capacity was installed to an extent of 1.2 GWth.

The solar heat is mainly used in the household sector for domestic hot water and room heating. In contrast to that, the use in commercial and industrial applications is very limited up to now. On the other hand, the industrial sector in the OECD countries has the highest share of the total energy consumption, at approximately 30%. Solar heat for industrial processes is therefore an important field with a high potential of conventional energy savings, reduction of CO2 emission and economical interest for the solar thermal industry in Europe and world-wide.

A large share of the energy which is needed in commercial and industrial companies for production processes is below 250°C. Solar collectors for the temperature level up to 80°C are already on the market. But new and advanced collector techniques are needed for the higher temperature levels. Especially collectors for operating temperatures between 80°C and 250°C are of interest.

Insulation Layer Underneath the Floor Slab

All cases shown above were calculated with an insulation layer of 10 cm underneath the floor slab. However, industrial buildings are often constructed without an insulation layer underneath the floor. The concrete floor is put directly on some kind of gravel to prevent the concrete from frost damage.

Table 2. Comparison of parameters of heavy and wet soil and light and dry soil.

Soil Parameters

Space Heating Demand



Heat Capacity

with insulation layer underneath the floor

without insulation layer underneath the floor




QSH, w/insulation

QSH, w/o insulation

W/(m K)


J/(kg K)

kWh/(m2 a)

kWh/(m2 a)

Heavy soil (wet)






Light soil (dry)






How much energy is lost through the floor slab of such a building depends on the physical parameters of the soil underneath. To illustrate the influence of an insulation layer underneath the floor slab and to show the influence of the soil characteristics, simulations were carried out with two extreme sets of soil parameters: very light and dry soil such as sand that doesn’t conduct the heat well and heavy wet soil such as clay that is much more dense and conducts heat well (see Table 2). As expected, the influence of the soil parameters on the heat demand of the building is much larger if there is no insulation layer underneath the building. However, the most important result is that the space heating demand is roughly doubled without an insulation layer underneath the building.

Calculation of the Number of Parallel Rows

Подпись: M Подпись: Qrow image229 Подпись: (eq.4)

The next step is the calculation of the number of parallel rows, M. This value is a function of the thermal power required by the power block, Qt. The number of rows is the integer rate of this demanding thermal power, Qt, by the thermal power generated in a row, Qrow, which is given by the useful thermal power supplied by every collector, Qutil, colc, multiplied by the pre-design number of collector per row, Npredesign, i. e.,

2. Solar field optimization

In the northern hemisphere, the solar incidence angle in winter is larger than in summer. So the solar irradiation available on the solar field is smaller (due to the cosine effect) and then the generated power decreases too. To reduce this winter effect, the designer could increase the

number of rows, but it would add an overproduction of thermal energy in summer that can not be used by the power block. This wasted thermal energy is known as dumping of energy.

With the methodology proposed in this paper, the optimum size of the solar field is the one that produces the highest electrical power generation with the lowest dumping of energy (below 3%, [5]). To determine this optimum, simulations with several sizes of the solar field are run along a real year (i. e., introducing ambient temperature and solar irradiation data from a typical meteorological year). The sizes are around the already calculated number of rows, M, in the pre­design. A model of the solar thermal power plant is, therefore, necessary.

The model of the solar thermal power plant has two independent components: the solar field model and the power block model (Fig.1).

Подпись: Metheorological data. Fig 1. Scheme of the solar thermal power plant model.

For the solar field model the simulation program TRSNYS (TRansient SYstem Simulations), [6], has been used. This program has a modular structure, which allows of programming in blocks. The different blocks considered for the solar field models are (Figure 1): a thermal and hydraulic model of a parabolic trough collector, a thermal and hydraulic model of a pipeline connection between two collectors in a row, a solar incidence angle calculator and a block reporting the general arrange of the solar field (number of collectors per row and number of rows in the solar field).

It is advisable that the direct normal irradiance and ambient temperature data are mean values in 10 or 15-minute time periods, in order to account transient clouds. The maximum time step to record these meteorological data being considered useful enough is 1 hour. The hydraulic and thermal models of the parabolic trough collectors and their interconnecting pipelines are stationary models.

The thermal model uses the corresponding heat balance, while the hydraulic model calculates the pressure drop using the Bernoulli equation. The mass flow of the heat transfer fluid in the solar field is the one which assures at every moment (i. e., under typical beam irradiance and ambient temperature) a fixed solar field outlet temperature. This temperature is always below the maximum bulk temperature of the thermal oil used as working fluid in the solar field and is previously defined for the solar field pre-design, taking into consideration the efficiency of the oil to water heat exchanger and the steam temperature needed at the inlet of the turbine. At the inlet of the turbine, the temperature — and pressure — is considered to be constant, unlike the steam mass flow, which varies depending on the oil mass flow in the solar field.

The power block model considers the influence of steam mass flow variations at the inlet of the turbo-generator on its electric output. This influence is handled by a fitting curve obtained from the data given by the turbine manufacturer. A conventional fossil fuel boiler may be introduced if hybridization is considered.

The main results of the plant simulation are the incident solar energy onto the solar field, the useful thermal energy produced in the solar field and in the conventional boiler — if any-, the electrical energy generated in the turbine and the dumping of energy, all these results integrated along one year.

3. Example

As an example, let’s consider a parabolic trough solar power plant of 50 MWe somewhere in the South of Spain without storage. It is assumed that there are no restrictions or limitations in the size and orientation of the plot for the solar plant. The heat transfer fluid considered in this example is Therminol VP1 and the parabolic trough collector model is the ET-II (5.76m aperture width, 142.8m useful length). The orientation of the collectors is North-South. The Rankine cycle is assumed to have 38% gross efficiency (thus 131.6 MWth have to be supplied by the solar field at nominal conditions). The power block specifications determine that the temperature of the oil at the inlet and outlet of the solar field are 296°C and 393°C, respectively. 12% conventional fossil fuel energy supply is allowed in a yearly basis.

In the pre-design it is assumed a Direct Normal Irradiance of 850W/m2 and an ambient temperature of 25°C. The temperature difference at the outlet and inlet of the solar field and the used collector features determines that every row needs to have 4 collectors. The required thermal power defines that 74 rows are necessary if the calculation procedure explained in section 2 is applied.

In the optimization of the solar field, the meteorological data available are given in 1-hour time steps. An interpolation procedure has been followed to obtain 5-minute data sets. The accumulated annual direct normal irradiation is 2286 kWh/m2. Simulations are run for ±10% of number of rows to have a dumping of energy lower than 3%. Having in mind a central feed configuration of the solar field piping, an even number of rows are necessary, so the annual performances of the plant with 66, 74 and 82 rows are carried out.

The annual solar energy onto the collector field (insolation), the thermal energy it produces, the electricity output of the power plant and the percentage of wasted energy is shown in Fig. 2 for different sizes of the solar field. As with 82 rows the dumping of energy was lower than 1%, the corresponding results for a plant with 90 rows are also obtained and shown. Running the plant simulation model with typical meteorological data for 74 rows a small dumping of energy is observed, becoming zero with 66 rows. Increasing the solar field size from 74 rows to 82 rows (10.8 %) the electric energy production increases 10%: from 94GWh to 103GWh. When the performance with 74 rows is compared with the one of 90 rows (21.65% of increase in size), the increase of the annual electric production is 17.2 % (from 94GWh to 110GWh), but with 3.37 % of dumping of energy. Thus the electricity production does not increase/diminish in the same percentage as the increase/reduction of the solar field size.

Подпись: 3.5 3.0 2.5 2.0 1.5 1.0 0.5 0.0 Подпись: n° rows of collectorsimage2340s












Incident energy


Thermal energy


Electrical energy


—— Dumping of energy


Fig 2. Incident, thermal, electrical and wasted energy as function of solar field size.

Keeping the criterion of being below 3 % dumping of energy, the optimized size of the solar field will be between 66 and 88 rows. The next step must be the economical evaluation of these few options.

4. Conclusions

In order to better design a parabolic trough power plant, simulation tools for finding out the optimal solar field size are necessary. Up to now, these simulation tools have an economical criterion as the only figure of merit, requiring a new optimization process every time there was any variation in the economical situation to apply. A way to reduce the number of cases to consider is by including another energetic criterion. This paper presents a methodology to optimize parabolic solar fields where an energetic criterion is applied prior the economical one. A first estimation of the solar field is obtained with a simple calculation, assuming representative meteorological conditions (pre-design). Taking this pre-designed solar field size as reference, annual evaluations of the performance of the plant with different sizes are analyzed. The limits where this size range stays are determined keeping the wasted energy (dumping), due to the oversizing of the solar field in summer, below 3%.

An example to illustrate how to proceed with a specific case is explained. After the methodology

presented here, the economical optimization that would follow is reduced to just a few cases.


[1] Greenpeace, SolarPACES, ESTIA: “Concentrated Solar Thermal Power Now — Exploiting the Heat from the Sun to Combat Climate Change”, September 2005

[2] X. Garcia Casals “La ene^a solar termica de alta temperatura como alternativa a las centrales termicas convencionales y nucleares”, 2001

[3] V. Quaschning, R. Kistner, W. Ortmanns, “Influence of Direct Normal Irradiance Variation on the Optimal Parabolic Trough Field Size: A Problem Solved with Technical and Economical Simulation”. ASME Journal of Solar Energy Egineering, 124 (2002) 160-164

[4] FLAGSOL, 2008, http://www. flagsol. com/FLAGSOL. htm, visited on August 2008

[5] J. I. Ajona, “Electricity Generation with Distributed Collector Systems”. Course: “Solar Thermal Electricity Generation”. Plataforma Solar de Almeria (13th-17th July, 1988).

[6] TRNSYS. A Transient System Simulation Program. Solar Energy Laboratory. University of Wisconsin. USA. (1994)

The potential for solar process heat in the European Union

The results of the potential studies for different European countries are reported in the figure and the table below. The potential solar process heat estimated in the PROMISE study for Austria [5] reaches 5.4 PJ/year, while the Iberian Peninsula (Spain and Portugal, [6]) and the Italian studies [7] show a potential of 21 PJ/year and 32 PJ/year respectively.


Figure 4. Solar process heat potential in selected European countries (PJ/year).

The study carried out for the Netherlands shows a quite lower potential (<2 PJ/year). The reason for this is because the hot water production up to only 60 °C was assessed in twelve industry branches, thereby limiting the scope of the analysis.

In Table 1, the potential for the use of solar thermal in the industrial sector in different countries is reported in terms of delivered energy (PJ/year), capacity (GWth) and collector area (Mio m2). These potential figures are also compared to the corresponding industrial heat demand, in order to obtain the share of heat demand that could be covered by using solar thermal.

The results reported show that solar thermal systems could provide the industrial sector with 3^4% of its heat demand in Austria, Italy, Portugal, Netherlands and Spain.

Extrapolating this result to the European Union (EU 25), considering an average share of 3.8%, the potential for solar thermal applications in industry reaches a value for heat production of 258 PJ/year. The corresponding potential figures in terms of capacity and area have been calculated taking into account two possible yield values for the solar plants: 400 kWh/m2 year and 500 kWh/m2 year.

Table 1. Industrial heat demand and solar process heat potential for selected countries and for EU25.


Industrial final energy consumption

Industrial heat demand (Final energy to heat demand

conversion factor: 0.75)

Solar process heat potential at low & medium temperature

Solar process heat/ Industrial heat demand

Potential in terms of capacity

Potential in terms of collector area





[Mio m2]












5.5 — 7

8 — 10





1.3 — 1.7

1.9 — 2.5













0.5 — 0.7

0.8 — 1

EU 25





100 — 125

143 -180

2. Conclusions

Even though solar thermal is used today mainly for providing hot water to households and pools, the conducted survey clearly highlights that, given its relevance in total final energy consumption, the industrial sector cannot be ignored.

Moreover, a remarkable share of its heat demand is needed in the low and medium temperature range, and this is true particularly for certain industrial sectors (food — including wine and beverage, textile, transport equipment, metal and plastic treatment, chemical) and for several processes (cleaning, drying, evaporation and distillation, blanching, pasteurisation, sterilisation, cooking, painting, surface treatment).

Studies based on both industry statistics and on case studies performed for assessing the solar thermal potential in industrial applications came to consistent outcomes regarding the share of low and medium temperature heat required by the industrial branches noted above.

The analysis of the surveyed country potential studies also shows that, even though using quite different methodologies, the obtained figures are quite similar and that solar thermal could provide the industrial sector with 3^4% of its heat demand.

This result allows the extrapolation of the national figures to the European level: solar thermal could provide 258 PJ/year of thermal energy to the EU25 industrial sector, which means an installed capacity of 100-125 GWth (143^180 Mio m2).

The most ambitious target for solar thermal, developed by ESTIF (European Solar Thermal Industry Federation), is to reach a level of 320 GWth installed in 2020, meaning about 1 m2 per capita and 19.7 Mtoe/year of energy delivered [8].

According to the European Solar Thermal Technology Platform (ESTTP), the goal for 2030 is to have installed a total capacity of 960 GWth by 2030.

Assuming that 10% of the calculated potential for solar heat in industrial applications were to be actually implemented within 2020, a total capacity between 10 and 12 GWth in industrial applications would give a contribution of 3^4% to the overall target of 320 GWth.

Following these assumptions, the industrial use of solar thermal energy could assure a market volume of 1,000 MWth/year, which would mean a 50% growth with respect to the current European annual solar market volume, that equalled 2,100 MWth (almost 3,000,000 m2) installed in 2006.

By exploiting this potential, 10,000-15,000 new jobs could be created by 2020. This figure represents a relevant share of the occupational target for the overall solar thermal sector, which according to the European Solar Thermal Technology Platform will be able to offer 224,000 full time jobs by 2020.

Even assuming a quite conservative scenario for the penetration of solar thermal use in the industrial sector, its contribution for reaching the EU set targets for 2020 is significant.

Finally, regarding future improvements of this analysis, new and more complete studies are needed within the EU framework to assess the detailed potential at national and EU levels in the different industrial sector and expand the current data available to solar thermal companies and policy makers.


[1] W. Weiss, I. Bergmann, G. Faninger, Solar Heat Worldwide — Markets and contribution to the energy supply 2005, International Energy Agency 2007.

[2] Data for 2004, based on EUROSTAT statistics.

[3] ECOHEATCOOL (IEE ALTENER Project), The European Heat Market, WP 1, Final report, Published by Euroheat & Power. www. ecoheatcool. org.

[4] D. Jaehnig, W. Weiss (AEE INTEC), Design Guidelines — Solar Space Heating of Factory Building with Underfloor Heating Systems, IEA Task 33/IV, 2007. Downloadable from www. iea- shc. org/task33/publications/index. html

[5] Muller, T. et al., PROMISE — Produzieren mit Sonnenenergie, Potenzialstudie zur thermischen Solarenergienutzung in osterreichischen Gewerbe — und Industriebetrieben within the Fabrik der Zukunft (BMVIT) Subprogram, Final report 2004.

[6] H. Schweiger et al., POSHIP (Project No. NNE5-1999-0308), The Potential of Solar Heat for Industrial Processes, Final Report.

[7] Solar thermal potential study for process heat in Italy, IEA Task 33/IV.

[8] European Solar Thermal Industry Federation, “Solar Thermal Action Plan for Europe”, www. estif. org.

Solar collector flow rates and temperatures

The system employed a small capacity fan, 12 DC 5We PAPST that required an external energy supply. The power needed was supplied by a small PV-panel unit of 10 We. Thus the performance of the fan was not continuous and therefore the flow rate was mainly depended on the irradiance levels. Thus for the highest irradiance level, the collector delivered the maximum flow rate and for lower irradiance levels, there was a limit where the fan did not operate.

The study of the solar collector performance requires the analysis of the flow rate dependence with the irradiance but also the pneumatic system characteristics. The fan was powered by the PV-panel that pumped the flow through the system to cross the woodchip. In order to find the relationship between flow rate and irradiance, it was necessary to study the pneumatic characteristics of both fan and system, and also the electrical connection between fan and PV-panel separately.


The electrical connection between PV-panel and fan can be analysed in the I-V curves that describes the electrical characteristics of both 10We PV-panel and 5We fan, Figure 5 shows operational voltages at two irradiances levels. It may be noted that not all the power generated by the PV-panel is supply to the fan as operational points don’t coincide with the maximum power curve. During the periods of high irradiance, the fan will be operated over capacity, although the fan motor showed no signs of fatigue or damage. [6]

Fig 5: PV module and fan electrical characteristics with systems operating voltage

The final drying flow depended on the pneumatic characteristics curves of the system. The flow blown by the fan needs to overcome the pressure drop associated to the air resistance to pass through the solar dryer. The head losses of the solar dryer were located in three differenced parts: the transpired plate, the flexible duct and the woodchip layer. Therefore the drying flow depended on the type of plate used and on the thickness of the woodchip layer. For all the tests, the thickness

Подпись: Figure 6 shows a plot of measured flow rate as a function of irradiance for a single day period. The test was taken on the 4th of August in 2008 when the sky was overcast and occasionally sunny. The flow rate increases reaching its maximum value for the higher irradiance, so for 1310 W/m2 the air flow was 248 m3/h. The connection of the PV-panel with the low power fan is reflected on a low threshold irradiance of 135 W/m2 that corresponds to a flow of 57 m3/h. This enhanced the system potential to work even on days with low light.

of the woodchip layer was 3cm that corresponds to the 3kg of product employed before in the drying tests.

Fig 6: Measured flow rate vs. irradiance

Figure 7 shows the collector outlet and collector temperature rise against the irradiance for the same day as previous. Considering that air flow rate increases with irradiance, the graph shows the tendency of temperatures to increase with irradiance as well. For low irradiances the average temperature rise was 10°C and for high irradiance levels it was 20°C. The degree of scatter in the temperature rise is mainly attributed to variances in the ambient temperature and fluctuations in the collector flow. Also the transitory time to the steady state and wind effect may affect in the collector air and absorber plate temperatures [11].

. Two loop system

The concept of the “two loop “system is different from the compact system and will be favourably from the economical point of view for daily capacities higher than 1000 litre. A sketch of the principle set up is given in figure 5. The design keeps four main differences compared to the compact systems:

A thermal storage tank is used to enable an extended operation time of the MD-modules even after sun-set ^Decreasing specific module costs

The system consists of two loops. The desalination loop is operated with sea water and is separated from the collector loop which do not have to be sea water resistant ^ Cheaper standard components (storage, collectors, pumps) can be used

Several MD-modules are operated in parallel.

A controller is used for charge and discharge of the heat storage and controlling a set point temperature for the evaporator inlet ^The operation conditions can be optimized regarding performance conditions of the MD process.

Simulation computations were carried out for the system design and the development of an adapted control strategy for two different pilot plants. The design capacity for the Aqaba system was 700 — 900 l/day and for the Gran Canaria system 1000 — 1600 l/day. Table 1 provides the key data for both systems.

Table 1: Key data of the two “two loop systems” as designed by simulation computations


Gran Canaria

Design capacity [l/day]

700 -900


Collector area [m2]



Collector type

Standard flat plate

Flat plate double glassed AR

Capacity heat storage [m3]



Number of MD modules



PV area [kWp]



Figure 6 shows a picture of the collector field (left hand side) and the heat storage, hydraulic board and the desalination unit (right hand side) of the Aqaba system installed in December 2005. The two loop system in Gran Canaria was installed in March 2006.


Подпись: Fig. 6: Collector field, solar system and desalination unit of the Aqaba two loop system

Experimental investigations Compact System

The graphs in figure 7 (left side) represent one day of operation of the Compact System in Freiburg on 16th July 2006. The solar irradiation (Irrad) in the collector plain increases up to 1000 W/m2 at noon. The feed pump switches on when a set point temperature of 55°C at the collector outlet is reached. The feed mass flow is in the beginning about 300 l/h and increase with rising solar irradiation to a maximum of 500kg/h at noon.

The distillate production starts immediately after the system start up and increases continuously with the rising evaporator inlet temperature and feed volume flow. The maximum distillate mass flow during noon is about 25 l/h. The maximum evaporator inlet temperature is almost 90°C. The temperature at the condenser inlet (Tcond_in) increases during the day, due to the brine recirculation to the feed tank. At 12:00PM the refilling of the feed storage starts initialized by reaching the critical feed temperature of 50°C at the condenser inlet. As can be seen the temperatures (Tcond_in) decrease immediately by 10 K. The total daily distillate production at the 16th July 2006 was about 140 liter.

Подпись: Two loop system

The first Compact System was installed in Gran Canaria in December 2004 and is still in daily operation with the first MD-module. Figure 6 (right hand side) presents a part of these long term measurements in Gran Canaria. The daily distillate gain is plotted versus the cumulated daily gain of solar energy. The considered period starts in the middle of June 2005 and ended in the middle of June 2006. As can be seen from the one year measurements there is no decrease of specific energy demand during the observed period. For example a daily solar gain of 7kWh/m2 enables an average distillate production of 60 l/day in June 05 as well as in June 06. Differences, in both directions, occur due to specific weather conditions an operation conditions.

Fig 7: Daily measurement — Compact System Freiburg (left), Long term measurement Gran Canaria — daily
permeate production vs. sum of daily solar irradiation (right)

A plot the operation performance of the two loop system in Gran Canaria is presented in figure 8 for a fine day in March. The “Irrad” graph represents the global radiation on the tilted collector surface. The “TCol_out” graph is the collector outlet temperature and the “T_evap_in” line represents the evaporator inlet temperature as adapted by the control unit. As can be seen the collector outlet temperature and the evaporator inlet are rising comparably until 11:00 AM (IG=500W/m2) when the set value at the evaporator inlet is reached. Then the collector outlet temperature continues rising while the evaporator inlet is set to 80°C.


Fig. 8: 24 hour measurement and collector field efficiency of the two loop system in Gran Canaria in March 2006.

From 6:30 PM to 7:30PM the controller switches to storage discharge. As can be seen the temperatures are fluctuating and can not be controlled to the set value. The reason can be found in the slow reaction time of the control unit respectively the slow movement of the Valve. From 7:30PM to 22:30AM the temperature control operates successfully again and the evaporator inlet temperature is set again to 80°C until the storage top temperature decreases below that value. The system is operated with a decreasing evaporator inlet temperature and decreasing distillate flow until 4:15AM, March 24. Then the switch of temperature of 58°C at the evaporator inlet is reached. The distillate volume flow during operation on the set point temperature is about 75 and 80 kg/h. The cumulated distillate gain from the operation period between 10:00 AM March 23 and 6:15 AM March 24 is 1240kg.

The specific energy consumption of the MD unit is in the range of 260 kWh/m3 distillate for low evaporator inlet temperatures of 55°C and decreases down to 180kWh/m3 distillate at a set point operation temperature of 80°C. The specific energy supplied by the collector — respectively the storage loop is 14% to 23 % higher than consumed by the MD unit. That difference can be considered as system losses.

The diagram on the left hand site of figure 8 presents the collector field efficiency (nth) of the Gran

Canaria two-loop system. It was calculated from the temperature difference between collector field in — and outlet, the collector loop mass flow rate, the specific heat capacity of water (Cp) and the measured global radiation in the collector plain.

nth = (T_coll_out — T_coll_in)*mp_coll*Cp / IGt

It can be seen from the graph that in the range of standard operation between 0.06<(dT/G)<0.08 (for G =1000W/m2 and Tamb=20°C this is equal to an average collector temperature range of 80 — 100°C) the collector field efficiency is between 0.61 and 0.5. The stagnation temperature for G=1000W/m2 and Tamb=20°C can be calculated from the efficiency curve with 200°C.

The storage of solar thermal heat

In many cases it is not only more economic but also more efficient to stop the solar system under high irradiance than to store every single Joule which is not used soon and would get lost in the tank later. Therefore our principal concept is to avoid large storage tanks. This is even more the case where high temperatures are required that are accompanied by higher heat losses of the tank. On the other hand systems with small or without tanks can deliver solar heat much faster under bad irradiation conditions if the heat capacity of a storage tank is not a barrier.

The thermal standstill is a normal thing for water systems. In future the restarting of water systems from the thermal standstill will also be a matter-of-course as soon as heat is needed again. A storage capacity of 0.5 kWh per m2 collector area is transferred on the roof and can be saved with the storage tank. This is about 1/100 of the annual energy harvest or even more. A solar collector system that can be restarted from standstill at any time promises a much higher annual energy harvest than installations which can only leave stagnation by cooling down through natural heat losses.

With these positions Paradigma differs essentially from the official recommendations which are based on the traditional flat plate collector technology.

Demand of Thermal Process Heat

If the thermal process heat demand in industrialised countries is analysed, one recognises that there are two ranges of temperatures with a high industrial heat demand: one at a temperature range of 800°C and one in the range up to 250°C. This latter temperature range offers good conditions for the application of solar thermal collectors to cover at least part of that heat demand. The following industrial sectors are especially concerned:

• food and beverage industry

• breweries

• laundries and tanneries

• textile industry

• chemical industry

• paper and pulp industry

• investment goods industry

All over Europe, the process heat demand in this temperature range is estimated to about 400 TWh per year. The potential for solar process heat is estimated in [2] to be 90-112 GWth for the EU25 countries. The development of this market potential will open new growth segments for the European solar thermal industry. Moreover, very promising possibilities for the export of new solar thermal technology exist world-wide, especially to countries and regions with high solar irradiation. Therefore it is necessary to develop new appropriate collectors, system components, storage tanks and complete solar process heat systems in the next years. The aim should be to achieve a number of ‘good practice examples’ within the next years, so that in the future an increasing part of the process heat demand can be covered by solar thermal technology.