Description:FIELD OF THE INVENTION

The present disclosure relates to the field of fluid testing. More particularly, the present disclosure relates to a system for evaluating the performance of a thermic fluid.

BACKGROUND

Nowadays, solar energy became an alternative to various conventional energy sources as the usage of solar energy eliminates fossil fuel emissions which reduces air pollution. Solar energy is the conversion of energy from sunlight into electricity, either directly using Photovoltaic (PV) cells or indirectly using Concentrated Solar Power (CSP). The CSP systems generate solar power by using lenses, mirrors, and tracking systems to focus a large area of sunlight into a receiver. PV cells convert sunlight into an electric current using the photovoltaic effect.

The existing CSP systems are installed in an industry such as in a power plant to produce solar power for various heat transfer applications such as the heating of thermic fluids. The thermic fluids are used in the industry to receive and deliver the heat and therefore, the thermic fluids should have high-temperature stability, and a low corrosion behavior towards common structural materials such as stainless steel (SS304, SS316L) and mild steel. Therefore, there is a need to evaluate the performance and properties of thermic fluids before using the thermic fluids in the industry.

However, the existing systems do not have a provision to evaluate the performance and properties of the thermic fluids before the use of thermic fluids in the industry, so an optimal thermic fluid cannot be chosen. This affects the overall functionality of the systems which may result in the failure of the components.

Therefore, in view of the above-mentioned problems, there is a need to provide a system that can eliminate one or more above-mentioned problems associated with the existing systems.

SUMMARY

This summary is provided to introduce a selection of concepts, in a simplified format, that are further described in the detailed description of the disclosure. This summary is neither intended to identify key or essential inventive concepts of the disclosure and nor is it intended for determining the scope of the disclosure.

The present disclosure provides a system for evaluating the performance of a thermic fluid for a heat transfer application. The system may include a storage tank, a solar thermal collector, a corrosometer, and a steam plant emulator. The storage tank is adapted to store the thermic fluid, and the solar thermal collector is fluidically connected to the storage tank. The solar thermal collector is adapted to receive solar radiation to provide a first predefined amount of heat to the thermic fluid. The corrosometer is positioned downstream to the solar thermal collector and is adapted to determine the corrosiveness of the thermic fluid. The steam plant emulator is fluidically coupled to the solar thermal collector to receive the heated thermic fluid and is fluidically coupled to the storage tank. The steam plant emulator receives the first predefined amount of heat from the heated thermic fluid to heat water to emulate steam generation and determine a heat transfer coefficient of the thermic fluid based on the emulation.

A method for evaluating the performance of a thermic fluid is also disclosed herein. The method may include supplying the thermic fluid from a storage tank to a solar thermal collector fluidically connected to the storage tank. Further, the method may include heating the thermic fluid by providing a first predefined amount of heat from a solar thermal collector. Herein, the solar thermal collector is adapted to receive solar radiation to provide the first predefined amount of heat to the thermic fluid. In the next step, the corrosiveness of the thermic fluid is determined by a corrosometer positioned downstream to the solar thermal collector. Finally, the method may include measuring a heat transfer coefficient of the thermic fluid by a steam plant emulator fluidically coupled to the thermic fluid heater to receive the heated thermic fluid and fluidically coupled to the storage tank. The steam plant emulator receives the first predefined amount of heat from the heated thermic fluid to heat water to emulate steam generation and determine the heat transfer coefficient of the thermic fluid based on the emulation.

As mentioned above, the system of the present disclosure may evaluate the performance of the thermic fluid for the heat transfer application. The system may determine the corrosiveness and the heat transfer coefficient of the thermic fluid. Based on the determined values of the corrosiveness and the heat transfer coefficient, the optimal thermic fluid may be selected for use in a power plant. This improves the overall efficiency and performance of the power plant. Further, the system includes the solar thermal collector adapted to receive solar radiation to provide a first predefined amount of heat to the thermic fluid. The solar thermal collector converts sunlight into the first predefined amount of heat. This reduces the overall cost as sunlight is available in abundance.

To further clarify the advantages and features of the present disclosure, a more particular description of the disclosure will be rendered by reference to specific embodiments thereof, which being illustrated in the appended drawings. It is appreciated that these drawings depict only typical embodiments of the disclosure and are therefore not to be considered limiting of its scope. The disclosure will be described and explained with additional specificity and detail with the accompanying drawings.

BRIEF DESCRIPTION OF THE DRAWINGS

These and other features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein:

Figure 1 illustrates a schematic of a system for evaluating the performance of a thermic fluid, according to an embodiment of the present disclosure;

Figure 2 illustrates a schematic of a first section of the system, according to an embodiment of the present disclosure;

Figure 3 illustrates a schematic of a second section of the system, according to an embodiment of the present disclosure;

Figure 4 illustrates a schematic of a third section of the system, according to an embodiment of the present disclosure;

Figures 5(a), 5(b), 5(c), 5(d) and 5(e) illustrate examples of the system according to an embodiment of the present disclosure; and

Figure 6 illustrates a flow chart depicting a method for evaluating the performance of a thermic fluid, according to an embodiment of the present disclosure.

Further, skilled artisans will appreciate that elements in the drawings are illustrated for simplicity and may not have necessarily been drawn to scale. For example, the flow charts illustrate the method in terms of the most prominent steps involved to help to improve understanding of aspects of the present disclosure. Furthermore, in terms of the construction of the device, one or more components of the device may have been represented in the drawings by conventional symbols, and the drawings may show only those specific details that are pertinent to understanding the embodiments of the present disclosure so as not to obscure the drawings with details that will be readily apparent to those of ordinary skill in the art having benefit of the description herein.

DETAILED DESCRIPTION OF FIGURES

While the embodiments in the disclosure are subject to various modifications and alternative forms, the specific embodiment thereof has been shown by way of example in the figures and will be described below. It should be understood, however, that it is not intended to limit the disclosure to the particular forms disclosed, but on the contrary, the disclosure is to cover all modifications, equivalents, and alternatives falling within the scope of the disclosure.

It is to be noted that a person skilled in the art would be motivated from the present disclosure to modify a system for evaluating the performance of a thermic fluid as disclosed herein. However, such modifications should be construed to be within the scope of the disclosure. Accordingly, the drawings show only those specific details that are pertinent to understand the embodiments of the present disclosure, so as not to obscure the disclosure with details that will be readily apparent to those of ordinary skill in the art having benefit of the description herein.

Accordingly, the system for evaluating the performance of the thermic fluid is described with reference to the figures and specific embodiments; this description is not meant to be constructed in a limiting sense. Embodiments of the present disclosure will be described below in detail with reference to the accompanying drawings.

Details of a system 100 for evaluating the performance of a thermic fluid are explained with respect to Figures 1, 2, 3, and 4. Specifically, Figure 1 illustrates a schematic of the system 100 for evaluating the performance of the thermic fluid while Figure 2 illustrates a schematic of a first section 102 of the system 100. Further, Figure 3 illustrates a schematic of a second section 104 of the system 100 while Figure 4 illustrates a schematic of a third section 106 of the system 100.

The system 100 is adapted for evaluating the performance of the thermic fluid for heat transfer application. In an embodiment, the system may be embodied as a test rig, without departing from the scope of the present disclosure. Thus, the system 100 may evaluate the performance of the thermic fluid to be used in a power plant at a larger scale. Thus, the performance of the multiple fluids can be evaluated in the system 100. Based on this evaluation, an optimal fluid may be selected from among the multiple fluids, and this optimal fluid may be used in various industries such as power plants.

The thermic fluid is adapted to be circulated within the system 100. During the circulation, a phase of the thermic fluid may be changed upon the receipt of heat. The thermic fluid may be circulated in one of a laminar flow, a turbulent flow, and a transitional flow within the system 100. The thermic fluid may include, but is not limited to, diphenyl oxide and biphenyl. The system 100 is adapted to install in a defined space such as a laboratory. Herein, the system 100 may evaluate one or more properties of the thermic fluid circulating within the system 100. The one or more properties may include, but is not limited to, corrosiveness, heat transfer coefficient, heat loss rate, viscosity, temperature, and pressure of the thermic fluid.

Based on the evaluated properties of the thermic fluids, the optimal thermic fluid may be selected to use in the power plant. Herein, the optimal thermic fluid may be referred to as a thermic fluid having thermal stability, so that the thermic fluid can sustain at higher temperatures. The higher temperature, but not limited to, may be up to 425 degree Celsius or more. Thus, thermic fluids with good thermophysical properties and high thermal stability at higher temperatures are preferable for the working mediums in a Concentrated Solar Power (CSP) unit. Therefore, the system 100 is used to evaluate one or more properties of the thermic fluids.
Referring to Figure 1, the system 100 may include the first section 102, the second section 104, and the third section 106. Herein, the first section 102, the second section 104, and the third section 106 may be fluidically connected to each other to form a closed loop. Further, each of the first section 102, the second section 104, and the third section 106 may accommodate the thermic fluid.

The first section 102 may be referred to as a storage section adapted to supply and store the thermic fluid. The first section 102 may include, but is not limited to, a storage tank 107, a pump 116, and an oil drain tank 118. The second section 104 may be referred to as a thermal section. The second section 104 may include, but is not limited to, a solar thermal collector 120, a corrosometer 122, a viscometer 124, a thermic fluid heater 126, and a sample tank 128. Further, the third section 106 may be referred to as a heating section. The third section 106 may include, but is not limited to, a steam plant emulator 130, and a water tank 132.

The storage tank 107 is adapted to store the thermic fluid, and the solar thermal collector 120 is fluidically connected to the storage tank 107. The solar thermal collector 120 is adapted to receive solar radiation to provide a first predefined amount of heat to the thermic fluid. The corrosometer 122 is positioned downstream to the solar thermal collector 120 and is adapted to determine the corrosiveness of the thermic fluid. The steam plant emulator 130 is fluidically coupled to the solar thermal collector 120 to receive the heated thermic fluid and is fluidically coupled to the storage tank 107. The steam plant emulator 130 receives the first predefined amount of heat from the heated thermic fluid to heat water to emulate steam generation and determine a heat transfer coefficient of the thermic fluid based on the emulation.

The details of the first section 102 are explained with respect to Figure 1 in conjunction with Figure 2. The storage tank 107 may be adapted to store the thermic fluid. The storage tank 107 is connected to the solar thermal collector 120 of the second section 104 through the pump 116. The pump 116 may be positioned downstream of the storage tank 107 and upstream of the solar thermal collector 120 to circulate the thermic fluid within the system 100. In an embodiment, the storage tank 107 may have, but is not limited to, a cylindrical shape, without departing from the scope of the present disclosure. In another embodiment, the storage tank 107 may have, but is not limited to, a cuboidal shape, without departing from the scope of the present disclosure.

Further, the storage tank 107 may include, but is not limited to, a deaerator 108, a reservoir 110, and an expansion container 112. The deaerator 108 is adapted to remove a foreign element from the thermic fluid. The reservoir 110 is fluidically coupled to the deaerator 108 and is adapted to accommodate the thermic fluid expanded during the heating of the thermic fluid. The expansion container 112 is adapted to maintain the static pressure of the thermic fluid to control the Net Positive Suction Head (NPSH) for a pump 116 and support the inert blanketing.

The deaerator 108 may receive gas adapted to maintain a positive pressure of the thermic fluid during the heating of the thermic fluid to avoid cavitation. In the illustrated embodiment, a gas tank 114 may be coupled with the deaerator 108 to supply the gas. In an embodiment, the gas may include, but is not limited to, nitrogen or any inert gas. In another embodiment, multiple gases may be supplied to the deaerator 108 to avoid cavitation during the heating of the thermic fluid. The storage tank 107 may include at least one pressure sensor positioned adjacent to the deaerator 108. The at least one pressure sensor is adapted to measure the pressure of the thermic fluid to be circulated within the system 100.

The pump 116 may be adapted to circulate the thermic fluid within the system 100. The pump 116 may include an inlet port and an outlet port opposite the inlet port. The inlet port of the pump 116 may be fluidically coupled to an outlet port of the storage tank 107. The outlet port of the pump 116 may be fluidically coupled to an inlet port of the solar thermal collector 120. Further, the pump 116 may include a variable frequency drive adapted to control the flow rate of the thermic fluid to be passed through the solar thermal collector 120.

The oil drain tank 118 is fluidically coupled to the storage tank 107. The oil drain tank 118 may accommodate the thermic fluid to be supplied to the storage tank 107. The oil drain tank 118 is adapted to fill the thermic fluid inside the storage tank 107. Further, the oil drain tank 118 is adapted to drain the thermic fluid from the storage tank 107 to measure the heat loss rate of the thermic fluid.

The details of the second section 104 are explained with respect to Figure 1 in conjunction with Figure 3. Herein, the solar thermal collector 120 is fluidically connected to the storage tank 107. The pump 116 may be positioned in between the solar thermal collector 120 and storage tank 107. The inlet port of the solar thermal collector 120 may be coupled with the outlet port of the pump 116, and an outlet port of the solar thermal collector 120 may be coupled to the thermic fluid heater 126. The solar thermal collector 120 is adapted to receive solar radiation to provide the first predefined amount of heat to the thermic fluid.

The solar thermal collector 120 may be embodied as a parabolic trough collector, without departing from the scope of the present disclosure. The solar thermal collector 120 may include a spectrally solar selective coating (SSC) provided on the surface of the solar thermal collector 120 to absorb maximum solar radiation. The SSC may be optically designed to absorb the incident irradiation on the surface of the solar thermal collector 120 for reducing the emissivity of the surface. This may reduce the radiation losses from the surface.

The solar thermal collector 120 may include a mirrored surface of a linear parabolic-shaped reflector which may direct solar irradiation onto a receiver. In an embodiment, the receiver may be embodied as evacuated absorber tubes, without departing from the scope of the present disclosure. Herein, a vacuum up to 10-3 m bar may be maintained in between SSC coated absorber tube enclosed by an outer glass tube. Further, the system 100 may include a supervisory control and data acquisition (SCADA) controlled automated tracking unit.

The SCADA controlled automated tracking unit is adapted to control a movement of the solar thermal collector 120 based on the temperature of the thermic fluid. The SCADA controlled automated tracking unit may move the solar thermal collector 120 in accordance with the movement of Sun, such that maximum solar radiations may incident on the surface of the solar thermal collector 120. This may generate more heat for heating the thermic fluid. Further, the viscometer 124 may be positioned downstream of the storage tank 107 and upstream of the solar thermal collector 120. In an embodiment, the viscometer 124 may be positioned between the pump 116 and the storage tank 107. The viscometer 124 is adapted to measure the viscosity of the thermic fluid after absorbing the heat.

In the illustrated embodiment, the corrosometer 122 is positioned downstream to the solar thermal collector 120. The corrosometer 122 may be positioned between the solar thermal collector 120 and the thermic fluid heater 126. The corrosometer 122 is adapted to determine the corrosiveness of the thermic fluid. The corrosometer 122 may include a metallic probe adapted to form a contact with the thermic fluid to evaluate the corrosiveness of the thermic fluid based on a metal loss of the metallic probe. The metal loss may be measured from the increase in electrical resistance of the metallic probe. More than one corrosometer 122 may be installed in the system 100 to evaluate the corrosiveness of the thermic fluid. In an embodiment, the metallic probe may be formed of Stainless Steel (SS304, SS316L). In an embodiment, the corrosometer 122 may be embodied as an electrical resistance corrosion probe 122, without departing from the scope of the present disclosure. In another embodiment, corrosometer 122 may be embodied as a corrosion coupon, without departing from the scope of the present disclosure.

The thermic fluid heater 126 may be positioned downstream of the corrosometer 122 and upstream of the steam plant emulator 130 to receive the thermic fluid exiting from the solar thermal collector 120. In an embodiment, an inlet port of the thermic fluid heater 126 may be coupled to the corrosometer 122 positioned downstream to the solar thermal collector 120. An outlet port of the thermic fluid heater 126 may be fluidically coupled with the steam plant emulator 130.

The thermic fluid heater 126 is adapted to supply a second predefined amount of heat to the thermic fluid based on the temperature of the thermic fluid exited from the solar thermal collector 120. The second predefined amount of heat may be defined as an amount of heat supplemented by the thermic fluid heater 126 in absence of solar irradiation or in the presence of insufficient solar radiation less than 600 W/m2. In an embodiment, the thermic fluid heater 126 may be embodied as an electric heater of 18KW, without departing from the scope of the present disclosure. The sample tank 128 of the system 100 may be positioned upstream of the thermic fluid heater 126 and downstream of the steam plant emulator 130, wherein the sample tank 128 is adapted to collect a sample of the thermic fluid to evaluate at least one property of the thermic fluid.

The details of the third section 106 are explained with respect to Figure 1 in conjunction with Figure 4. Herein, the steam plant emulator 130 is fluidically connected with the thermic fluid heater 126 coupled to the solar thermal collector 120. The steam plant emulator 130 is adapted to receive the heated thermic fluid. The steam plant emulator 130 may be positioned upstream of the thermic fluid heater 126 and downstream of the solar thermal collector 120. The steam plant emulator 130 is also fluidically coupled to the storage tank 107. In the illustrated embodiment, an inlet port of the steam plant emulator 130 may be coupled to the outlet port of the thermic fluid heater 126.

The steam plant emulator 130 receives a total amount of heat from the heated thermic fluid to heat water to emulate steam generation. Herein, the total amount of heat may include the first predefined amount of heat and the second predefined amount of heat of the heated thermic fluid. The steam plant emulator 130 may determine a heat transfer coefficient of the thermic fluid based on the steam emulation. Further, the water tank 132 may be connected to the steam plant emulator 130 to supply water. The steam plant emulator 130 transfers the heat from the thermic fluid to the water to convert the water into steam. In an embodiment, the steam plant emulator 130 may be embodied as a steam generator, without departing from the scope of the present disclosure.

In the system 100, the first predefined amount of heat and the second predefined amount of heat may be supplemented to the thermic fluid, and the total heat may be released in the steam plant emulator 130 to analyse the thermal stability of the thermic fluid at steady state conditions from 250 to 300 degree Celsius. Thus, the system 100 may evaluate the heat loss rate of the thermic fluid at higher temperatures, during the circulation of the thermic fluid within the system 100.

Examples of the system 100 having different arrangements for the components of the system 100 are explained in Figures 5(a), 5(b), 5(c), 5(d), and 5(e). Referring to Figure 5(a), the system 100 may include the storage tank 107, the pump 116, the oil drain tank 118, the solar thermal collector 120, the steam plant emulator 130, and the water tank 132 for evaluating the stability of the thermic fluid. The stability of the thermic fluid is evaluated with the balance of the system to capture the heat transfer characteristics of the thermic fluid in laminar, transitional, and turbulent flow conditions. Herein, the balance of the system applies to all supporting components of the system 100 which are needed to run the system 100 and assess the performance of the thermic fluid.

Referring to Figure 5(b), the system 100 has similar components as explained with reference to Figure 5(a). Additionally, the system 100 may include the electrical resistance corrosion probe 122 positioned downstream of the solar thermal collector 120 at location 7 and upstream of the steam plant emulator 130. The electrical resistance corrosion probe 122 is adapted to evaluate the corrosiveness of the thermic fluid on general constructing materials.

The electrical resistance corrosion probe 122 is formed of the metallic material such as stainless steel. The electrical resistance corrosion probe 122 may form the contact with the thermic fluid circulating within the system 100. Due to this contact with the thermic fluid, the metal loss from the electrical resistance corrosion probe 122 may be occurred. After a predefined time, the electrical resistance corrosion probe 122 may be removed from the system 100, and the metal loss is measured. Thus, the corrosiveness of the thermic fluid is evaluated based on the metal loss from the electrical resistance corrosion probe 122. In an example, the predefined time may be referred to as 100 cycles when the thermic fluid may be heated at 300 °C, without departing from the scope of the present disclosure.

Referring to Figure 5(c), the system 100 has similar components as explained with reference to Figure 5(a). Additionally, the system 100 may include the electrical resistance corrosion probe 122 positioned downstream of the solar thermal collector 120 at one of locations 9 and 10 and the viscometer 124 positioned upstream of the solar thermal collector 120 at location (8). Herein, the viscometer 124 is adapted to find the viscosity variation of thermic fluid in the system 100. The thermic fluid circulating within the system 100 may come in contact with the viscometer 124. The viscometer 124 may have a capillary tube and the thermic fluid may flow through the capillary tube. The time taken by the thermic fluid to flow in the capillary tube is measured to evaluate the viscosity of the thermic fluid.

Referring to Figure 5(d), the system 100 has similar components as explained with reference to Figure 5(a). Additionally, the system 100 may include a first electrical resistance corrosion probe 122 positioned downstream of the solar thermal collector 120 and upstream of the thermic fluid heater 126 to evaluate the corrosiveness of the thermic fluid.

Referring to Figure 5(e), the system 100 has similar components as explained with reference to Figure 5(a). Additionally, the system 100 may include a first electrical resistance corrosion probe 122 positioned downstream of the solar thermal collector 120 at location 9 and a second resistance corrosion probe 122 positioned downstream of the thermic fluid heater 126 at location 10. Further, the viscometer 124 is positioned upstream of the solar thermal collector 120 at location (8) to find the viscosity variation of thermic fluid in the system 100.

The present disclosure also relates to a method 200 for evaluating the performance of the thermic fluid as shown in Figure 6. The order in which the method steps are described below is not intended to be construed as a limitation, and any number of the described method steps can be combined in any appropriate order to execute the method or an alternative method. Additionally, individual steps may be deleted from the method without departing from the spirit and scope of the subject matter described herein.

The method 200 begins at step 202 at which the thermic fluid may be supplied from the storage tank 107 to the solar thermal collector 120 fluidically connected to the storage tank 107. Herein, the solar thermal collector 120 may be positioned downstream of the storage tank 107. The pump 116 may be positioned between the storage tank 107 and the solar thermal collector 120 to transfer the thermic fluid from the storage tank 107 to the solar thermal collector 120.

At next step 204, the thermic fluid is heated by providing a first predefined amount of heat from the solar thermal collector 120. Herein, the solar thermal collector 120 is adapted to receive solar radiation to provide the first predefined amount of heat to the thermic fluid. The thermic fluid may pass through the solar thermal collector 120 and receive the first predefined amount of heat.

At next step 206, the corrosiveness of the thermic fluid is determined by a corrosometer 122 positioned downstream to the solar thermal collector 120. Herein, the corrosometer 122 may include the metallic probe adapted to form contact with the thermic fluid to evaluate the corrosiveness of the thermic fluid based on a metal loss of the metallic probe. The metal loss may be measured from the increase in electrical resistance of the metallic probe.

Finally, at step 208, the heat transfer coefficient of the thermic fluid is measured by the steam plant emulator 130 fluidically coupled to the thermic fluid heater 126 to receive the heated thermic fluid. The steam plant emulator 130 may be positioned upstream of the thermic fluid heater 126 and downstream of the solar thermal collector 120. The steam plant emulator 130 is also fluidically coupled to the storage tank 107. The steam plant emulator 130 receives the total amount of heat from the heated thermic fluid to heat water to emulate steam generation and determine the heat transfer coefficient of the thermic fluid based on the emulation.

The system 100 of the present disclosure may evaluate the performance of the thermic fluid for the heat transfer application. The system 100 may determine the corrosiveness and the heat transfer coefficient of the thermic fluid. Based on the determined values of the corrosiveness and the heat transfer coefficient, the optimal thermic fluid may be selected for use in a power plant. This improves the overall efficiency and performance of the power plant. Further, the system 100 includes the solar thermal collector 120 adapted to receive solar radiation to provide a first predefined amount of heat to the thermic fluid. The solar thermal collector 120 converts sunlight into the first predefined amount of heat. This reduces the overall cost as sunlight is available in abundance.

The system 100 of the present disclosure may evaluate the thermal stability, cyclic stability, pumpability, corrosiveness, heat loss rate, and heat transfer characteristics of thermic fluids circulating under the laminar, transitional, and turbulent flow conditions within the system 100. Herein, the system 100 may supplement additional heat to the thermic fluid to test the thermic fluids at higher temperatures. After the evaluation, the behavior of the thermic fluid at higher temperatures is predicted. This improves the performance of the industry in which the selected thermic fluid is adapted to be used, by saving time and effort associated with the individual testing of the thermal properties of the thermic fluids. Further, the evaluation of the thermic fluids in the system 100, may also eliminate any failure associated with the thermal conditions.

While specific language has been used to describe the present subject matter, any limitations arising on account thereto, are not intended. As would be apparent to a person in the art, various working modifications may be made to the method in order to implement the inventive concept as taught herein. The drawings and the foregoing description give examples of embodiments. Those skilled in the art will appreciate that one or more of the described elements may well be combined into a single functional element. Alternatively, certain elements may be split into multiple functional elements. Elements from one embodiment may be added to another embodiment. , Claims:We Claim:

1. A system (100) for evaluating the performance of a thermic fluid for a heat transfer application, the system (100) comprising:
a storage tank (107) adapted to store the thermic fluid;
a solar thermal collector (120) fluidically connected to the storage tank (107) and adapted to receive solar radiation to provide a first predefined amount of heat to the thermic fluid;
a corrosometer (122) positioned downstream to the solar thermal collector (120) and adapted to determine corrosiveness of the thermic fluid; and
a steam plant emulator (130) fluidically coupled to the solar thermal collector (120) to receive the heated thermic fluid, and fluidically coupled to the storage tank (107), wherein the steam plant emulator (130) receives the first predefined amount of heat from the heated thermic fluid to heat water to emulate steam generation, and determine a heat transfer coefficient of the thermic fluid based on the emulation.

2. The system (100) as claimed in claim 1, comprising:
a viscometer (124) positioned downstream of the storage tank (107) and upstream of the solar thermal collector (120) to measure viscosity of the thermic fluid after absorbing the heat.

3. The system (100) as claimed in claim 1, comprising:
a thermic fluid heater (126) positioned downstream of the corrosometer (122) and upstream of the steam plant emulator (130) to receive the thermic fluid exiting from the solar thermal collector (120), wherein the thermic fluid heater (126) is adapted to supply a second predefined amount of heat to the thermic fluid based on a temperature of the thermic fluid exited from the solar thermal collector (120).

4. The system (100) as claimed in claim 1, wherein the storage tank (107) comprises:
i) a deaerator (108) adapted to remove a foreign element from the thermic fluid;
ii) a reservoir (110) fluidically coupled to the deaerator (108) and adapted to accommodate the thermic fluid expanded during heating of the thermic fluid; and
iii) an expansion container (112) adapted to maintain static pressure of the thermic fluid to control the Net Positive Suction Head (NPSH) for a pump (116) and support the inert blanketing.

5. The system (100) as claimed in claim 3, wherein the deaerator (108) comprises a gas adapted to maintain a positive pressure of the thermic fluid during the heating of the thermic fluid to avoid cavitation.

6. The system (100) as claimed in claim 1, wherein the storage tank (107) comprises a pressure sensor adapted to measure the pressure of the thermic fluid to be circulated within the system (100).

7. The system (100) as claimed in claim 4, wherein the pump (116) is positioned downstream of the storage tank (107) and upstream of the solar thermal collector (120) to circulate the thermic fluid within the system (100), wherein the pump (116) comprises a variable frequency drive adapted to control a flow rate of the thermic fluid to pass through the solar thermal collector (120).

8. The system (100) as claimed in claim 1, comprising an oil drain tank (118) fluidically coupled to the storage tank (107), wherein the oil drain tank (118) is adapted to fill the thermic fluid inside the storage tank (107), and the oil drain tank (118) is adapted to drain the thermic fluid from the storage tank (107) to measure the heat loss rate of the thermic fluid.

9. The system (100) as claimed in claim 1, comprising a sample tank (128) positioned upstream of the thermic fluid heater (126) and downstream of the steam plant emulator (130), wherein the sample tank (128) is adapted to collect a sample of the thermic fluid to evaluate at least one property of the thermic fluid.

10. The system (100) as claimed in claim 1, comprising a water tank (132) connected to the steam plant emulator (130) to supply water, the steam plant emulator (130) transfers the heat from the thermic fluid to the water to convert the water into steam.

11. The system (100) as claimed in claim 1, wherein the corrosometer (122) comprises a metallic probe adapted to form contact with the thermic fluid to evaluate the corrosiveness of the thermic fluid based on a metal loss of metallic probe, wherein the metal loss is measured from the increase in electrical resistance of the metallic probe.

12. The system (100) as claimed in claim 1, wherein the solar thermal collector (120) is a parabolic trough collector, and the parabolic trough collector comprises a spectrally solar selective coating provided on a surface of the parabolic trough collector to absorb maximum solar radiation.

13. The system (100) as claimed in claim 1, comprising a supervisory control and data acquisition (SCADA) controlled automated tracking unit adapted to control a movement of the solar thermal collector (120) based on the temperature of the thermic fluid.

14. A method (200) for evaluating the performance of a thermic fluid, the method (200) comprising:
supplying (202) the thermic fluid from a storage tank (107) to a solar thermal collector (120) fluidically connected to the storage tank (107);
heating (204) the thermic fluid by providing a first predefined amount of heat from the solar thermal collector (120), wherein the solar thermal collector (120) is adapted to receive solar radiation to provide the first predefined amount of heat to the thermic fluid;
determining (206) corrosiveness of the thermic fluid by a corrosometer (122) positioned downstream to the solar thermal collector (120); and
measuring (208) a heat transfer coefficient of the thermic fluid by a steam plant emulator (130) fluidically coupled to the thermic fluid heater (126) to receive the heated thermic fluid, and fluidically coupled to the storage tank (107), wherein the steam plant emulator (130) receives the first predefined amount of heat from the heated thermic fluid to heat water to emulate steam generation, and determine the heat transfer coefficient of the thermic fluid based on the emulation.