US20130344238A1 - Method for in situ coating a tower solar receiver - Google Patents

Method for in situ coating a tower solar receiver Download PDF

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Publication number
US20130344238A1
US20130344238A1 US13/977,674 US201113977674A US2013344238A1 US 20130344238 A1 US20130344238 A1 US 20130344238A1 US 201113977674 A US201113977674 A US 201113977674A US 2013344238 A1 US2013344238 A1 US 2013344238A1
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US
United States
Prior art keywords
receiver
coating
carried out
solar
curing
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US13/977,674
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English (en)
Inventor
Erika Patricia Clavijo Rivera
Noelia Martinez Sanz
Jose Barragan Jimenez
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Abengoa Solar New Technologies SA
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Abengoa Solar New Technologies SA
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Abengoa Solar New Technologies SA filed Critical Abengoa Solar New Technologies SA
Publication of US20130344238A1 publication Critical patent/US20130344238A1/en
Assigned to ABENGOA SOLAR NEW TECHNOLOGIES, S.A. reassignment ABENGOA SOLAR NEW TECHNOLOGIES, S.A. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BARRAGAN JIMENEZ, JOSE, CLAVIJO RIVERA, Erika Patricia, MARTINEZ SANZ, NOELIA, FERNANDEZ QUERO, VALERIO
Abandoned legal-status Critical Current

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Classifications

    • F24J2/485—
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B05—SPRAYING OR ATOMISING IN GENERAL; APPLYING FLUENT MATERIALS TO SURFACES, IN GENERAL
    • B05D—PROCESSES FOR APPLYING FLUENT MATERIALS TO SURFACES, IN GENERAL
    • B05D3/00—Pretreatment of surfaces to which liquids or other fluent materials are to be applied; After-treatment of applied coatings, e.g. intermediate treating of an applied coating preparatory to subsequent applications of liquids or other fluent materials
    • B05D3/02—Pretreatment of surfaces to which liquids or other fluent materials are to be applied; After-treatment of applied coatings, e.g. intermediate treating of an applied coating preparatory to subsequent applications of liquids or other fluent materials by baking
    • B05D3/0254—After-treatment
    • F24J2/07—
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F24—HEATING; RANGES; VENTILATING
    • F24S—SOLAR HEAT COLLECTORS; SOLAR HEAT SYSTEMS
    • F24S20/00—Solar heat collectors specially adapted for particular uses or environments
    • F24S20/20—Solar heat collectors for receiving concentrated solar energy, e.g. receivers for solar power plants
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F24—HEATING; RANGES; VENTILATING
    • F24S—SOLAR HEAT COLLECTORS; SOLAR HEAT SYSTEMS
    • F24S40/00—Safety or protection arrangements of solar heat collectors; Preventing malfunction of solar heat collectors
    • F24S40/40—Preventing corrosion; Protecting against dirt or contamination
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F24—HEATING; RANGES; VENTILATING
    • F24S—SOLAR HEAT COLLECTORS; SOLAR HEAT SYSTEMS
    • F24S70/00—Details of absorbing elements
    • F24S70/20—Details of absorbing elements characterised by absorbing coatings; characterised by surface treatment for increasing absorption
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23D—ENAMELLING OF, OR APPLYING A VITREOUS LAYER TO, METALS
    • C23D5/00—Coating with enamels or vitreous layers
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/40—Solar thermal energy, e.g. solar towers

Definitions

  • This invention belongs to the technical sector that encompasses the procedures to apply liquids or other fluid materials to surfaces, with the prior treatment thereof.
  • the method includes the surface preparation, application of the coating, curing, and in situ vitrification of the receiver.
  • a field of heliostats or mobile mirrors that are oriented according to the position of the sun, reflect solar radiation in order to concentrate the same on a receiver that is located at the top of a tower.
  • the receiver is in charge of transferring the heat that is received to a working fluid such as water, molten salts, etc., with the purpose of generating steam that will expand in a turbine coupled to a generator for the production of electricity.
  • a working fluid such as water, molten salts, etc.
  • These receivers have a special coating that boosts the absorption of the solar radiation concentrated by the heliostats.
  • the tower serves as support for the receiver, which must be located at a certain height above the level of the heliostats with the purpose of improving the cosine effect, which is caused by the angle formed by the incident ray along the perpendicular to the heliostat and reduces the surface of effective reflection of the mirror.
  • Patent DE2734604 A1 (Process for coating for solar panels) discloses the composition of a coating applicable to solar technology that increases the absorption of heat by the solar component. Also, patent FR2399289 A1 shows a lacquer with black pigments that can be deposited in solar collectors and which films can reach thicknesses ranging between 5 and 30 microns.
  • Patent US005562953A shows that, by means of the addition of a non-saturated amine to conventional coatings, the curing rate of the coatings exposed to UV radiation or solar light can be improved.
  • the curing proposed therein is carried out with non-concentrated solar radiation or with UV radiation.
  • Patent WO 2009/146161 A1 presents a method for coating a solar collector, wherein the curing is carried out with concentrated solar radiation.
  • high temperature coatings also require high temperature curing, due to which, after applying the layers, increasing the temperature of the surface is necessary. This process is carried out in ovens appropriate for that purpose.
  • solar receivers their size and the complexity of their installation makes the renewal of the absorbing coating and the curing thereof difficult, due to the need to dismount and displace the receiver from the top of the tower to ovens which sizes may be adjusted to the size of the receiver.
  • this invention proposes a methodology to apply coating to tower solar receivers by using solar technology for the curing that allows carrying out the entire process in situ, that is to say, at the solar plant with the receiver installed at the top of the tower, avoiding the need to dismount the solar component for its coating at a workshop and subsequent transfer to the plant, and therefore, the deterioration of the coating during said processes until its installation.
  • Tower solar receivers receive concentrated solar radiation by means of a heliostat field. These receivers, through which a heated working fluid circulates, require the application of an absorbing coating on their surfaces. This coating, in addition to increasing the absorptivity of the surface, also protects the receiver against environmental factors and corrosion.
  • the absorbing coatings currently used in the receivers are silicon-based coatings, which provide them with good resistance to high temperatures, having black pigments that grant the absorbing property.
  • the solution to the low durability problem presented by the products used to coat tower solar receivers is found in the methodology used in its application.
  • the procedure proposed in this invention allows overcoming the main problems, such as the appearance of cracks in the coating that penetrate to the surface of the tubes, leaving it exposed and susceptible to the start of corrosion processes, and the flaking of the coating in certain zones, which decreases the efficiency of the plant in a considerable manner given that the heat absorption of the receiver is reduced.
  • the steps corresponding to the preparation of the material and the application of the coating are carried out by zone in an alternating or intercalated manner, that is to say, the blasting of an zone of the receiver is carried out and then the coating is applied to that same zone, the receiver being divided into a different number of zones depending on its size.
  • the curing is carried out by supplying steam to the inside of the receiver tubes.
  • This steam can come from an auxiliary boiler, from a prior solar heating step, etc.
  • it is indispensable to guarantee a constant and continuous input of heat to the receiver until reaching the temperature recommended by the coating manufacturer for this operation.
  • the curing step also integrates the solar field within the process as an auxiliary support system, which would be used in the case the failure of the steam input to the inside of the receiver tubes.
  • Carrying out the curing by circulating steam through the inside of the receiver tubes offers a fundamental advantage with respect to the systems carrying out the curing from the outside, given that, in this manner, the curing of the coating is produced from the innermost layers (those in contact with the receiver) towards the outermost layers. This way, the evaporation and expulsion of the volatile components of the internal layers takes place prior to the curing of the external layers, which means said volatile components are released into the atmosphere without any problems.
  • the first layers to harden are the external ones, which means that the volatile components of the internal layers cannot be released into the atmosphere when they start to evaporate due to the heat input, and remain inside the coating as occluded bubbles, increasing the porosity of said coating.
  • These occluded bubbles which cause imperfections and inhomogeneities in the coating, lead to defects such as perforations, craters, or cracks, which cause the subsequent oxidation or reduction of the absorption in the receiver, as explained above.
  • the vitrification of the coating is carried out by means of increasing the temperature of the coated surface that has already been cured.
  • the coating is exposed to conditions that are similar to the operating conditions of the receiver, increasing its temperature to more than 400° C. This temperature increase is obtained by means of the circulation of steam through the inside of the tubes, plus the application of concentrated solar radiation on the receiver coming from the heliostat field.
  • the step of controlled cooling of the receiver until reaching room temperature is fundamental in the coating process to avoid the immediate formation of cracks, which are produced if the newly applied coating is submitted to sudden temperature changes.
  • the heliostats are first defocused such that they cease to concentrate heat on the surface of the receiver. Then, a series of recirculation pumps of the receiver are connected, which cause the circulation of a fluid at a controlled temperature through the inside of the receiver tubes until reaching 100° C. Then, they are turned off and the air is left to cool completely.
  • FIG. 1 a general scheme of the solar plant with central-tower technology.
  • FIG. 2 a general scheme of a panel of a tower solar receiver.
  • the procedure comprises the following steps:
  • both the surface preparation and the application of the coating must be carried out by dividing the surface of the receiver into several zones, which, in the case of the preferred embodiment, is established as four zones ( 19 , 20 , 21 , 22 ). Applying the coating after blasting each zone is possible with this division by intercalating both procedures in order to minimize the time between the blasting and coating of the entire receiver.
  • the surface of the receiver ( 9 ), located at the top of a tower ( 4 ), is treated to increase the anchoring of the coating to said surface.
  • the prior coating is eliminated, as applicable, as well as the impurities that could affect the quality of the coating to be deposited (oxides and other products of corrosion).
  • This surface preparation guarantees that the surface is free from grease, dust, oils, dirt, prior coatings, oxides, products of corrosion, and any other type of deposited foreign matter.
  • the process used to prepare the surface is blasting, by means of the use of a pressurized abrasive (sand) to eliminate any matter embedded in the zone to be treated. Then, any residue of the material used in the blasting process must be eliminated with the application of pressurized air on the treated surface.
  • a pressurized abrasive sand
  • a scaffold allowing the operatives executing the work to come near the receiver, such that they can be located in front of the surface to be treated, is necessary for the blasting and for the application of the coating.
  • the scaffold also helps the worker to be at a constant distance form the receiver, thus favoring the homogeneity of the processes in the entire surface of the receiver.
  • the blasting process which uses fine silica sand, allows obtaining an optimal anchoring profile for the coating. Said profile is verified after completing the surface preparation process.
  • zone 1 After completing the blasting of zone 1 ( 19 ), the number of layers of coating recommended by the manufacturer is applied, using airless spraying equipment and respecting the drying time required between each layer, also defined by the manufacturer.
  • Airless spraying is used for the application of the coating. With this method, the coating is propelled through a hole at a very high pressure. It presents the advantages of being able to avoid the use of a solvent to decrease the viscosity of the product, or, as applicable, to use it in very small quantities; on the other hand, it results in thicker films than with other methods, greater coverage, and an enhanced application in hard-to-access zones.
  • the thickness of the obtained film which must be within the range specified by the coating manufacturer, is verified. Measurements at several points of the zone are taken by using a dry layer thickness measurer, obtaining an average value.
  • the curing of the receiver is carried out by increasing the temperature of the surface of the receiver tubes until reaching the curing temperature (according to the specifications of the coating), and by maintaining said conditions during the period of time recommended by the coating manufacturer.
  • the curing system consists of the following: i) temperature increase system for the receiver with the passage of the working fluid; and ii) support system to guarantee a constant supply of thermal energy to the surface of the receiver.
  • Temperature increase system for the receiver with the passage of the working fluid the temperature of the external surface of the tubes is increased until reaching the curing temperature, by causing the passage of saturated steam coming from the auxiliary boiler ( 2 ), or from any other source, through the inside of said tubes until reaching the correct temperature. Said temperature is reached in 2 hours and must be maintained during the period of time stipulated by the manufacturer.
  • the heliostat field ( 12 ) in order to ensure a constant input of heat after the start of the curing process, without the receiver experiencing temperature drops, the heliostat field ( 12 ) shall be kept operative and in stand-by, such that it can be used according to the temperature needs at the surface of the receiver. If the curing temperature required is higher than the one that can be reached at the receiver due to the operating limits of the boiler (approximately 320° C.), or if the input of steam is interrupted, the heliostats must be focused in a controlled manner until reaching said curing temperature. A vitrification step can be carried out after the curing.
  • Superheated steam tower solar receivers operate at maximum steam temperature of approximately 540° C. Given the way in which the concentration of solar radiation on the surface of receiver is carried out, maintaining a constant temperature during the operation is impossible. In this case, some coating manufacturers recommend carrying out the vitrification operation to increase the protection of the coating against thermal shock.
  • the vitrification operation of the coating applied to the tower solar receiver is carried out by passing saturated steam, coming from the reboiler ( 5 ), through the inside of the tubes, and by focusing the heliostats ( 12 ) of the solar fields in a controlled manner towards the receiver in a heat input ratio of 5 MWt every 10 minutes, until reaching the vitrification temperature, thus achieving a temperature increase of 50° C./h. Once the maximum radiation input point is reached, and with it, the vitrification temperature, said condition is maintained during the period of time recommended by the coating manufacturer.
  • the integration of the solar field to the procedure allows increasing the temperature of the surface of the receiver beyond the limits of the boiler.
  • the coating is subject to conditions that are similar to the operating conditions in a controlled manner, thus guaranteeing that the film that is formed will withstand the operating conditions of the receiver.
  • the defocusing of the heliostats shall be also carried out at a specific defocusing ratio that will allow a reduction of 5 MWt in the heat input every 10 minutes.
  • the recirculation pumps ( 8 ) of the receiver are turned on, until reaching a temperature below 100° C. at the surface thereof. Once the pumps are turned off, the receiver is allowed to cool to room temperature.
  • This procedure is applicable and adaptable to any commercial coating requiring high temperatures for its curing and vitrification, and that is intended to be used as absorbing coating for a tower solar receiver. It may also be used at any scale, in tower receivers at a pilot scale and at a commercial scale.
  • One of the advantages of the proposed procedure is that is allows carrying out the entire coating process in situ, thus avoiding the difficult dismounting operation to apply the coating at other facilities and carrying out the curing process with a conventional procedure (the panels of the receiver are taken to large furnaces, wherein the temperature increase is made in a controlled manner).
  • the panels of the receiver are taken to large furnaces, wherein the temperature increase is made in a controlled manner.
  • the layers of coating that are closest to the surface of the receiver are cured before the outermost layers of coating, thus avoiding the formation of occluded bubbles of solvent and imperfections in the innermost layers of the coating.
  • the coating develops surface conditions that are favorable with respect to the operating conditions, thus increasing the durability thereof.
  • the methodology being used allows minimizing the risk of obtaining a partial curing with undesirable properties in the formed film, given it guarantees a constant input of heat to the receiver during the entire curing step.

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Thermal Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Application Of Or Painting With Fluid Materials (AREA)
US13/977,674 2010-12-30 2011-12-29 Method for in situ coating a tower solar receiver Abandoned US20130344238A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
ES201001652A ES2386051B1 (es) 2010-12-30 2010-12-30 Metodo de recubrimiento in situ de receptor solar de torre
ESP201001652 2010-12-30
PCT/ES2011/000381 WO2012089869A1 (es) 2010-12-30 2011-12-29 Método de recubrimiento in situ de receptor solar de torre

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US20130344238A1 true US20130344238A1 (en) 2013-12-26

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US13/977,674 Abandoned US20130344238A1 (en) 2010-12-30 2011-12-29 Method for in situ coating a tower solar receiver

Country Status (9)

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US (1) US20130344238A1 (es)
EP (1) EP2667114A4 (es)
CN (1) CN103502746A (es)
CL (1) CL2013001921A1 (es)
ES (1) ES2386051B1 (es)
MA (1) MA34809B1 (es)
MX (1) MX2013007483A (es)
WO (1) WO2012089869A1 (es)
ZA (1) ZA201304665B (es)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018011319A1 (en) * 2016-07-15 2018-01-18 General Electric Technology Gmbh Metal-ceramic coating for heat exchanger tubes of a central solar receiver and methods of preparing the same

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
ES2574553B1 (es) * 2014-12-18 2017-04-05 Arraela, S.L. Procedimiento para la realización de un recubrimiento para bases sometidas a la incidencia de energía en el espectro de 10-7 < lambda < 10-4 m. y recubrimiento obtenido por dicho procedimiento

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US6701711B1 (en) * 2002-11-11 2004-03-09 The Boeing Company Molten salt receiver cooling system
US20090297721A1 (en) * 2008-05-30 2009-12-03 Alstom Technology Ltd. Method for coating a solar collector
US20110138811A1 (en) * 2009-12-14 2011-06-16 Cheng-Yi Lu Solar receiver and solar power system having coated conduit

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US6701711B1 (en) * 2002-11-11 2004-03-09 The Boeing Company Molten salt receiver cooling system
US20090297721A1 (en) * 2008-05-30 2009-12-03 Alstom Technology Ltd. Method for coating a solar collector
US20110138811A1 (en) * 2009-12-14 2011-06-16 Cheng-Yi Lu Solar receiver and solar power system having coated conduit

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018011319A1 (en) * 2016-07-15 2018-01-18 General Electric Technology Gmbh Metal-ceramic coating for heat exchanger tubes of a central solar receiver and methods of preparing the same
US10126021B2 (en) 2016-07-15 2018-11-13 General Electric Technology Gmbh Metal-ceramic coating for heat exchanger tubes of a central solar receiver and methods of preparing the same

Also Published As

Publication number Publication date
EP2667114A4 (en) 2016-01-06
ES2386051B1 (es) 2013-03-25
WO2012089869A1 (es) 2012-07-05
ZA201304665B (en) 2014-03-26
CN103502746A (zh) 2014-01-08
EP2667114A1 (en) 2013-11-27
ES2386051A1 (es) 2012-08-07
MX2013007483A (es) 2013-12-06
CL2013001921A1 (es) 2014-04-11
MA34809B1 (fr) 2014-01-02

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Owner name: ABENGOA SOLAR NEW TECHNOLOGIES, S.A., SPAIN

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:CLAVIJO RIVERA, ERIKA PATRICIA;MARTINEZ SANZ, NOELIA;FERNANDEZ QUERO, VALERIO;AND OTHERS;SIGNING DATES FROM 20130619 TO 20130629;REEL/FRAME:034890/0179

STCB Information on status: application discontinuation

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