Patent Application
20110067688
This disclosure relates to a solar concentrator system for solar energy plants.
Solar energy is emerging as one of the most promising sustainable energy sources. A solar energy plant takes solar energy and converts it to useful energy and/or products. A solar electrical plant takes solar energy and converts it to electrical energy. Solar energy has impressive potential: the entire world could theoretically be supplied with its current needs for electricity from solar power stations covering only approximately 1% of the earth.
As illustrated in
Concentrated solar thermal-electrical plants are solar power plants that make use of solar irradiation (primarily in the infrared (IR) range) to generate electricity. Each square meter of land in the United States Southwest receives approximately 5 to 8 kilowatt hours (kWh) of solar irradiation each solar day, depending on season and weather conditions. A report entitled Assessment of Parabolic Trough and Power Tower Solar Technology Cost and Performance Forecasts by Sargent and Lundy LLC Consulting Group, National Renewable Energy Laboratory, Chicago, Ill., (October 2003), herein referred to as “the Sargent and Lundy report,” made a cost analysis that implies the currently operating large scale solar concentrating and collecting systems produce electricity (per kWh) at a cost (including finance costs for construction) of roughly between two and five times of the current commercial market price of electricity (per kWh). The detailed amortized cost analysis of these current solar concentrator systems, according to the report, implies a very long payback period, approaching a given system's expected functional lifetime.
Solar photovoltaic (PV) plants make use of photovoltaic (PV) cells to generate electricity. The most efficient PV plants make use of concentrated solar radiation primarily in the ultraviolet (UV) and visual (VIS) ranges. Compared to the key components of solar thermal systems, PV cells generally degrade more rapidly, making them at this time a less preferable choice for large-scale electrical generation than solar thermal-electrical plants. However, solar PV plants have distinct advantages, such as their capability to provide electrical power in remote areas, and their potential portability.
Solar concentrator systems typically consist of various key optical components: a primary concentrator, possibly a secondary concentrator, a solar receiver containing some form of solar absorber and/or an energy storage system.
Known large-scale solar concentrator systems can generally be partitioned into four types of categories based on the shape or configuration of their primary concentrating surfaces. These are power tower systems, trough systems, compact linear Fresnel reflector systems, and dish systems. Power tower collectors are comprised of an array of heliostats, which individually track to concentrate solar radiation to a central, and usually raised receiver. The primary concentrators of trough systems have curved trough shape or a faceted approximation, which concentrate solar radiation to their focal line. The primary concentrators of compact linear Fresnel reflector systems are flat reflective strips, which are rotated to concentrate solar radiation to their focal line. The primary concentrators of dish systems have curved dish shape or a faceted approximation, which concentrate solar radiation to a single focal point. There are numerous currently operational examples of power tower, trough and dish systems.
Though the classification above is useful for describing the geometry of concentrating systems, when determining the cost efficiency of the systems, it is preferable to categorize solar systems based on whether key parts (e.g., primary concentrators, secondary concentrators, and solar collectors) are immobile or mobile. As stated above, one limiting factor of solar system design is the high initial cost of construction. Much of this construction cost comes from either or both the mechanisms for tracking and control of mobile concentrators and the structural elements necessary for supporting primary collectors in configurations that are exposed to the wind and other weather elements.
In any solar concentrator system, the primary concentrators, which are the component that receives direct solar radiation, typically have the largest surface area of any component, and thus their design is a large component in terms of costs of the overall system. Most primary concentrators are not horizontal, and are highly exposed to wind forces, often requiring costly structural support structures. Furthermore, most large-scale solar concentrators contain primary concentrators that are tracking, that is, they move to follow the daily movement of sun. In trough concentrator systems, this may manifest in one dimensionally tracking troughs, while in power tower systems, it may involve two dimensionally tracking heliostats. In both cases, these tracking primary concentrators generally make up a large portion of the total cost of the system due to their tracking mechanisms and the structural support structures needed to help them withstand wind and other weather conditions. The Sargent and Lundy report made a component cost breakdown for a 2004 trough system and estimated that thirty-five percent of the cost was due to the metal support structure and drive, which together comprise the tracking and control system for the primary concentrators. The primary concentrators of compact linear Fresnel reflector systems can be placed on the ground at near horizontal position, but the primary concentrators are required to track, increasing their complexity and construction costs.
There are also prior solar concentrator systems that include secondary reflectors, which may or may not track. For example, in some systems the primary and secondary concentrators are fixed in relation to each other but move as a unit to track, which still necessitates moving parts and a support structure.
Solar receivers have an important component, absorbers, whose function is to receive the concentrated solar energy for the purpose of storage or energy conversion. Generally absorbers have low cost compared to the cost of the solar concentrator system. The locations of the absorbers may vary in solar collectors; a concentrating solar system is defined to have localized absorbers if a distinct absorber is required for each primary concentrator element, whereas a concentrating solar system has centralized absorbers if multiple concentrators direct solar energy to a small number of absorbers. The use of localized absorbers often results in a more complex and costly heat transport and conversion system. Furthermore, the efficiency of heat energy conversion is increased with a higher temperature differential. Since localized absorbers generally have a lesser concentration of solar radiation and their temperature is lower, making these systems less efficient, and therefore less preferable. The lower concentration of solar radiation, and the lower temperatures that follow, also increase the emittance of localized absorbers; test results show that absorbers which used black chrome and Luz Cermet receiver tubes, for example, have a thermal emittance (the quantity emitted per unit area, which corresponds to thermal loss) of only nine percent at temperatures above 400 degrees Fahrenheit (The Sargent and Lundy report, §4.2.2). Presently, the majority of concentrators on the market have localized absorbers. Such localized absorber systems, in some examples, include large scale trough concentrators, large dish concentrators, and almost all smaller scale concentrators. Solar power towers are one of the few centralized absorber systems.
In addition to absorbers, solar receivers generally also include a means for storage of the energy collected by the absorbers. The energy storage period may be temporary or may be for a longer period beyond the period of the solar day. In the case of solar-thermal solar concentrator systems, energy storage can be achieved by a material or medium for storage of the heat energy, which may be temporary or may be for a longer period.
Since solar energy can only be collected for a portion of the solar day (typically approximately 8 hours a day), it follows that without a means for energy storage, the generator would only be able to produce electricity for that portion of the solar day. During this window of time, the generator would have to convert all of the collected solar radiation. In typical practice, by using an energy storage medium, the generator can potentially run up to three times longer, providing approximately one third the power over a twenty-four hour period. In solar energy systems with energy storage, the receiver can serve to absorb the energy from focused solar radiation and store in thermal energy storage substances, phase change materials, or chemical energy storage substances.
Bulk thermal storage mediums store energy by simply heating the medium. Thermal energy storage substances include, in some examples, liquid sulfur, molten salt, fluoride-salt, and various mineral oils.
Phase-change materials make use of a change in state (e.g., from solid to liquid, or from liquid to gas) for energy storage. For example, various materials include water, which can be used to store and release heat by evaporating into steam and condensing back to liquid start, or alternatively various salts can be used to store and release heat by melting and solidifying, respectively.
Chemical storage mediums make use of chemical reactions to store and release heat. Chemical storage mediums, in some examples, include metal hydrides, such as magnesium hydride, which store energy by dissociation to the base metal and hydrogen gas.
In summary, energy storage systems add to the initial cost of a solar power plant, but provide for extended daily periods of electrical output beyond the period of solar exposure, allowing electrical generators to be used extended periods of up to a full twenty-four hours rather than the approximately (depending on latitude and season) eight hours of usable direct sunlight, with only a very small decrease the efficiency. This would at first appear to significantly lower the amortization costs for the electrical generators by a factor of three per kWh (as they are used for three times as long at a third of the power). However, as detailed in the Sargent and Lundy report §4.3, the cost for energy storage was approximately 150% of the cost for the electrical generators, which implies a total of approximately 250% increased cost of constructing the power (storage and conversion) block, so the effective decrease in power-block cost by the use of energy storage is approximately 2.5/3 or about 83%.
The portion of a solar energy system that transforms solar energy to other useful products or energy, such as electricity, is termed the power-block. The power-block, as referred to herein, includes generators that transform solar energy to electricity as well as possibly energy storage devices.
The efficiency (the ratio of the energy output to the energy input) and cost of the means for energy conversion from concentrated solar energy into electricity is critical. The maximum Carnot efficiency of a reversible system for conversion of heat energy to mechanical power, for example, is lower bounded by 1−r, where r is the ratio of the cooled (ambient) temperature to the heated temperature (where both temperatures given are in degrees Kelvin). In practice, the efficiency of typical nonreversible systems for conversion of heat energy to electrical power has been empirically found to limit (for large generator systems) to approximately 1−r1/2. In either formula, the key quantity r is minimized when the heat differential between the cooled (ambient) temperature and the heated temperature is maximized.
Most concentrated solar thermal-electrical plants use turbines as means for converting thermal energy into electricity. Turbines can have efficiencies of up to 33% (depending on the size of the generator), and this can rise to as high as 42% efficiency if a reheat turbine cycle is used. The estimated yearly electrical income per kWh for concentrated solar thermal-electrical plants is less than the initial cost of purchase of steam turbines per kWh. However, this cost encompasses only the steam turbine, not the entire heat conversion system. This entire power-block is comprised of the steam turbine, cooling towers and piping systems. In prior art trough solar plants; the power-block can make up approximately 14% of the total cost (The Sargent and Lundy Report, §4.3).
Another variety of solar system includes cogeneration systems that, in addition to generating electrical energy from heat, also make further productive use of the waste heat, for example for steam or hot water heating of buildings. Such cogeneration systems can thus make productive use of upwards of between 85% and 90% of the input heat energy.
Certain embodiments make use of an array of passive primary concentrators positioned on the ground, that provide primary concentrated solar radiation from below to an array of tracking secondary concentrators, which then further concentrate the solar radiation to one or more centralized solar energy receivers.
The solar concentrator system may include apparatus for collection of solar radiation, concentration, and the absorbance of the concentrated solar energy. Some embodiments of the solar concentrator system include a large field of inexpensive, passive horizontal primary concentrators, overhead tracking secondary concentrators, and one or more receivers, which convert solar radiation into usable products or energy, such as electricity. A power-block may store and convert the concentrated solar energy to useful products.
A field used for collection of solar radiation from the sun is termed the primary concentrating field; in some embodiments, the primary concentrating field is fixed on the ground (immobile) and may be constructed out of an inexpensive material, such as concrete. The field may be subdivided into units, called primary concentrators. In certain embodiments, the primary concentrators are linear optical concentrators. In other words, the primary concentrators focus light to a region of focus, generally of uniform height above their surface, which will be termed the primary concentrator's focal line. In certain embodiments, due to in part to off-axis aberrations, optical surface defects and other effects, this focal line may broaden to a narrow horizontal strip. Each primary concentrator may have an optical surface with a saw-tooth cross section which provides an initial concentration of direct solar radiation. In other embodiments, the optical surface of the primary concentrators has a parabolic cross section. The optical surface may be purely reflective. In some embodiments, the optical surface may include both refractive and reflective elements. In certain embodiments, the optical surface of the primary concentrators includes a series of elongated convex cross section. In some embodiments, the optical surface includes a plurality of reflective optical elements.
In certain embodiments, the primary concentrators are stationary and, as the sun moves throughout the day, the primary concentrators' focal line moves across the focal plane in a west to east direction. In other embodiments, the focal line of the primary concentrators moves across the focal plane in an east to west direction. The optical surfaces of the primary and secondary concentrators may provide high optical efficiency, in particular high spectral reflectance. In some embodiments, the optical surfaces of the primary concentrators are mirror films that are very durable, and inexpensive to replace. In some embodiments, the optical surfaces of the secondary concentrators are extremely durable metallic surfaces with protective coating, insuring a long lifetime.
Each secondary concentrator may have one or two optical surfaces, each of which may be a linear optical concentrator. In some embodiments, the optical surfaces of the secondary concentrators are purely reflective. In other embodiments, the optical surfaces of the secondary concentrators include both refractive and reflective elements. In an embodiment, the optical surfaces are reflective and concave in cross section. In alternative embodiments, the optical surfaces of the secondary concentrators may include refractive as well as reflective elements. In some embodiments, the optical surfaces have a saw-tooth cross section. In other embodiments, the optical surfaces are parabolic in cross section.
The array of secondary concentrators may further concentrate the solar radiation and direct it to one or more receivers. In certain embodiments, the array of secondary concentrators is positioned to direct concentrated solar radiation to the receiver or receivers without obstructing one another. Each secondary concentrator may be suspended above the solar collecting field so that at any given time, the focal line (this is the hypothetical line at which parallel rays emitted from the receiver would be focused by the active optical surface of the secondary concentrator) of an optical surface of the secondary concentrator coincides with the focal line of the primary concentrator associated with the secondary concentrator. In some embodiments, to maintain the active optical surface of the secondary concentrator coincident with the focal line of the primary concentrator, the secondary concentrator can be moved throughout the solar day. In other words, adjustments of the secondary concentrator can be used to track the focal line of initially concentrated solar radiation reflected from the primary concentrator. In other embodiments, simultaneous tracking movements may be made to insure the fully concentrated solar radiation departing from the secondary concentrator is always directed toward one of the receivers. The secondary concentrators may track on an east-west axis parallel to the plane of the ground. In some embodiments, the secondary concentrators rotate vertically during tracking. In other embodiments, the secondary concentrators rotate during east-west tracking of the focal line. In some embodiments, the secondary concentrators suspended overhead on cables that allow movement of the secondary concentrators while tracking the focal line of the primary concentrator.
In certain embodiments, the receivers are located centrally in the primary concentrating field. In other embodiments, the receivers are located outside the field. In alternative embodiments, the receivers are able to adjust their locations depending on the time of year.
The solar concentrator system may be used in conjunction with a heat storing apparatus. In some embodiments, the heat storing apparatus includes a bulk heat storage medium (e.g., water, oils, sulfur, or concrete). In certain embodiments, the heat storing apparatus is a phase change medium (e.g., via the melting of salts or water/steam conversion). In alternative embodiments, the heat storing apparatus is a chemical heat storage system (e.g., metallic hydride reactions liberating hydrogen).
In selected applications, the solar concentrator system may be used in conjunction with an apparatus for converting the solar radiation collected from the field into usable energy. In some embodiments, high concentration solar cells are used to convert solar radiation into energy. In other embodiments, a smelting or hydrogen production apparatus are used to convert the solar radiation into energy. In alternative embodiments, a steam turbine converts the solar radiation into energy or heat.
In selected large-scale utility applications, for example using multiple solar concentrator systems combined in a compact scalable fashion, apparatus for storing solar radiation and conversion into usable energy may be shared amongst two or more solar concentrator systems.
A solar concentrator system including immobile primary concentrators, tracking secondary concentrators and centralized receivers to which solar radiation is directed may use an array of passive primary concentrators positioned on the ground, such that primary concentrated solar radiation can be provided from below to the array of tracking secondary concentrators. The array of tracking secondary concentrators may then further concentrate the solar radiation to the two centralized receivers. The design of the solar concentrator system may provide a dramatic reduction in costs for construction and maintenance while maintaining a high energy-efficiency, longevity, and broad applicability. In particular, two aspects of the solar concentrator system may provide a dramatic reduction in costs for construction and maintenance. First, a key item of cost advantage can include the use of immobile primary concentrators positioned on the ground, which therefore do not require costly large-scale structural support. Secondly, the use of tracking secondary concentrators suspended overhead on cables can also provide a significant cost-savings for construction. Additionally, the design of these two features may reduce of other recurring costs (such as maintenance). The high energy-efficiency design of the solar concentrator system, in combination with the reduction in costs for construction and maintenance, may imply a short payback period for combination of the initial costs and the recurring costs to be amortized.
The optical surfaces of the primary and secondary concentrators may provide high optical efficiency, in particular high spectral reflectance. The use of centralized receivers, to which solar radiation is directed, can significantly increase the energy-efficiency of the system, since heat does not need to be transported, and heat storage systems can be easily configured at the centralized receivers.
A high longevity may be provided by the ground-based positioning of the primary concentrators, allowing limited exposure to weather-related degradation such as wind loads. The low aspect and simplicity of the cable suspension of the secondary concentrators may also provide features that extend the lifetime of the solar concentrator system. The optical surfaces of the primary concentrators, in another example, can be constructed of mirror film that is very durable yet inexpensive to replace. The optical surfaces of the secondary concentrators, in another example can be constructed of extremely durable metallic surfaces with protective coating, insuring a long lifetime.
To provide the broadest base of application, the solar concentrator system can provides concentrating of a wide spectrum of solar radiation, including both IR (for example for solar-thermal electrical plant applications), as well as UV and VIS (for example for PV electrical power plant applications).
Like reference symbols in the various drawings indicate like elements.
A solar concentrator system includes an apparatus for the collection of solar radiation, concentration, and the absorbance of the concentrated solar energy. As shown in
A solar collecting field configured to receive direct solar radiation can be designed to minimize construction and maintenance costs while providing highly efficient concentration of solar energy. In certain embodiments, the collecting field is positioned on a flat, horizontal plane and is rectangular in shape. The collecting field is oriented so that two opposing sides, where solar receivers are located, are positioned for example on the east and west sides of the field. The solar radiation in the initial part of the solar day will be concentrated to the east solar receivers and in the later part of the solar day solar radiation will be concentrated to the west solar receivers. The solar receivers are rectangular in shape with a midline at a fixed height H. In some embodiments, the two opposing sides are positioned generally on the east and west sides of the field. In other embodiments, the two opposing sides are positioned generally on the north and south sides of the field. In certain embodiments, there is exactly one solar receiver on each of the solar receiver sides. In other embodiments, there are between approximately two and approximately nine solar receivers on each of the solar receiver sides, preferably between three and seven, more preferably five.
In certain embodiments, the solar collecting field is horizontal and composed of an array of primary concentrators. Each primary concentrator is rectangular in shape. Each primary concentrator has as its upper surface an optical surface that provides an initial concentration of direct solar radiation. The surface of each primary concentrator has a saw-tooth contour, with troughs that run in the in a north-south direction. In other embodiments, the troughs run in an east-west direction. In certain embodiments, the optical surface of the primary concentrators includes a series of elongated convex forms. The initial concentration of solar radiation provided by the primary concentrator, and directed above it, will be termed the primary concentrated solar radiation. The optical surface of each primary concentrator, in some implementations, is purely reflective. In other embodiments, the primary concentrator is both reflective and refractive. In certain embodiments, the primary concentrators are stationary. When the primary concentrators are stationary the primary concentrated solar radiation moves in a west to east direction above the primary concentrators when the sun moves across the sky. In certain embodiments, the primary concentrated solar radiation moves in an east to west direction above the primary concentrators.
In some implementations, the primary concentrators have a saw-tooth contour on their optical surfaces consisting of a series of elongated strip-shaped facets which are concave and run linearly in a north-south direction. In some embodiments, the optical surfaces run linearly in an east-west direction. In alternative embodiments, the series of elongated strip-shaped facets are flat. The primary concentrators, in some implementations, are bidirectional. In other embodiments, the primary concentrators are unidirectional. As illustrated in
In alternative embodiments, the optical surface of each primary concentrator is parabolic in cross section.
In some embodiments, the primary concentrators are slightly slanted so the troughs of the primary concentrators can serve as a runoff system. For example, runoff from the troughs of the primary concentrators can be fed into an additional water drainage system in the case of heavy rains.
In certain embodiments, the solar collection field 9 contains a first half and a second half. Each half includes multiple bidirectional primary concentrators 3b generally sloped in the same direction. For example, the first half can be positioned on the west side of the solar collection field 9 and have a downward slope toward the western longitudinal edge of the solar collection field 9 and the second half can be positioned on the east side of the solar collection field 9 and have a downward slope toward the eastern longitudinal edge of the solar collection field 9. In other embodiments, the first and the second halves slope generally downward toward the center of the solar collection field 9. In some embodiments, the first half is positioned on the north side of the solar collection field 9 and the second half is positioned on the south side of the solar collection field 9.
Since the function of each primary concentrator, such as unidirectional primary concentrator 3a and bidirectional primary concentrator 3b, is to collect and initially concentrate the direct solar radiation from the sun, the primary concentrators comprise the vast majority of the bulk of materials of the solar concentrator system. In some embodiments, depending on the ground contour of the site, there may be the need for minimal gravel grading of the ground to insure it is sufficiently flat. Each primary concentrator can be constructed from one or more low cost structural blocks. The structural blocks can be composed of concrete. In another example, the structural blocks can be made from plastic. In some embodiments, the blocks are made from a metallic material. In other embodiments, the blocks are made from wood or a wood compound. In certain embodiments, the material used to create the blocks is optically clear. In still other embodiments, the structural blocks are made from a plant product other than wood. These blocks can be preformed offsite or cast on site using molds. Each mold, for example, creates one block. In other embodiments, a single mold creates multiple blocks at a time. In certain embodiments, the blocks are formed offsite at a manufacturing plant and transported to the solar collection field. In certain embodiments, a sheet of wire mesh may be cast inside of these blocks to add structural support. On the upper surface of each primary concentrator, for example, can be one or more layers of a material such as plastic, which aids in defining the shape of the optical surface, smoothes the upper surface, and also provides sheathing protection from weathering. A highly reflective metallic film, in some implementations, is adhered to the uppermost surface of the primary concentrator. The spectral reflectance of an optical surface is the percent of incoming radiation that is directly reflected, and neither absorbed nor diffused in some other direction. Mirror films designed for solar concentration applications generally are designed to be inexpensive, durable, and have a high reflectance; for example ReflecTech, Inc. of Picayune, Miss. produces a mirror film which has 94% spectral reflectance, and has been demonstrated to be durable without significant damage in the outside environment in Colorado for over ten years.
The optical surface of each primary concentrator can be designed to form a linear concentrator so that for any given position of the sun, the concentrated solar radiation is focused (roughly) into a single line segment, for example the focal line of the secondary concentrators. In certain embodiments, the optics of each primary concentrator are designed so that this focal line is at all times horizontal, is oriented north-south, and moves in a plane (the primary concentrator's focal plane) predicatively through the course of the day. In other embodiments, the focal line has an east-west orientation.
Each north-south row of primary concentrators, in some implementations, has co-planar focal planes. Each east-west row of primary concentrators, for example, can be configured to have no slant in the north-south direction (since the focal lines are horizontal and run north-south).
An extended focal line, for example, is the line extending the focal line segment for a single primary concentrator over the collection field to the north and south. Over the day, the extended focal line of the primary concentrators drifts from west to east.
If, for example, the focal planes of all the primary concentrators were co-planar and horizontal, at a fixed height above the plane, then the focal line of all primary concentrators would simply remain at this fixed distance above the primary concentrator at all times of the day. In an alternative embodiment, each east-west row of primary concentrators has a focal plane with distinct slants slightly away from horizontal. A reason for this is that each east-west row of secondary concentrators may be hung via east-west cables that change in height and slant in the east-west direction, requiring the design of distinct optical surfaces for each primary concentrator along a east-west row, so their focal plane's east-west angle of slant is approximately the same as the average (e.g., averaged over the east-west extent of the primary concentrator) local angle of slant of the support cables above them.
The primary concentrator can be designed to have a high optical efficiency and low cost by use of reflective film and concrete base structure. The primary concentrator's solar efficiency (which here is determined by the spectral reflectance of the primary concentrator), for example, ranges from approximately 85-99%, preferably 90-97%, more preferably 92-96% for the surfaces exposed to direct solar radiation. In some embodiments, the spectral reflectance of the primary concentrator is approximately 94%. The most exposed portion of the primary concentrator is the mirror film, which has a demonstrated expected outdoor life of over ten years; therefore, the primary concentrator can be expected to last for at least this period with out serious repairs, and these repairs would be mostly limited to simply the replacement or repair the reflective film.
A secondary concentrator can be associated with each primary concentrator. Each secondary concentrator, in some implementations, can be oriented north-south parallel with the axis of the troughs of its corresponding primary concentrator. In some embodiments, the focal lines of the primary concentrators move in an east to west direction. As the sun moves during the day, the current position of the focal line of the solar radiation concentrated by each primary concentrator translates in a west to east direction. The function of each secondary concentrator is to direct the solar radiation concentrated by the primary concentrator to a receiver.
In an alternative configuration, as shown in
In one embodiment, the optical surfaces of the secondary concentrators are polished aluminum, with a multilayer dielectric film overcoat multilayer dielectric film overcoat (the dielectric materials may include silicon monoxide or magnesium fluoride) for protection of the optical surfaces.
In certain embodiments, the secondary concentrator has two optical surfaces, each of which behave as linear optical concentrators and which have a reflecting element. In some embodiments, each secondary concentrator has one optical surface. In alternative embodiments, the optical surfaces have reflecting and refracting elements. In some embodiments, these optical surfaces are purely reflective and concave in cross section. In other embodiments, the optical surface is parabolic in cross section.
A secondary concentrator with one optical surface can be referred to as a singleton secondary concentrator; where as a secondary concentrator with two optical surfaces (one will face east, the other west) can be referred to as a double secondary concentrator.
An optical surface of a secondary concentrator can be described as operationally-reflective if it directs primary solar radiation (incoming from the primary concentrator) back in the same general east or west direction from which it came; that is if the optical surface faces generally east, the operationally-reflective secondary concentrator directs radiation from the east back to the east, and if the optical surface faces generally west, the operationally-reflective secondary concentrator directs radiation from the west back to the west. Otherwise, the optical surface can be described as operationally-refractive where, when the optical surface is facing generally east, the operationally-refractive secondary concentrator directs radiation from the east to the west, and when the optical surface is facing generally west, the operationally-refractive secondary concentrator directs radiation from the west to the east. Note that this terminology only relates to the effect of the optical elements; the actual optical elements in each case may combine reflective and refractive parts.
In some embodiments, the secondary concentrators have an apparatus for providing vertical elevation (e.g., an elevating secondary concentrator). In certain embodiments, the secondary concentrators have an apparatus for rotation (e.g., a rotating secondary concentrator).
As mentioned above, each secondary concentrator can be associated with one of the primary concentrators and suspended above it. In certain embodiments, the suspension is implemented using a tensile structure supported by a support structure. A tensile structure, for example, includes elements carrying tension without substantial compression or flexibility. In one example, a system of cables can be used as the tensile structure with support poles as the support structure. In some implementations, the support structure includes a combination of one or more compressive, flexible, or tensile substructures. In some embodiments, the system of cables and support poles includes a tracking apparatus (which will be addressed later). In other embodiments, the secondary concentrators are suspended from a tensile structure. In one example, there are two support cables associated with each east-west row of primary concentrators. These support cables can run parallel to the east-west axis as well as perpendicular to the troughs in the primary concentrators. The support poles, in this case, can be implemented as vertical structural elements whose purpose is to suspend the support cables. The support poles can be positioned in rows along the east and west edges of the solar collecting field. Each support pole can be associated with one or more east-west rows of primary concentrators and can support the support cables associated with these primary concentrators. The apparatus for fixing the support poles into the ground, in some implementations, may include further side cables to provide support. The secondary concentrators can be suspended from these support cables by devices such as rollers that allow the secondary concentrators to move freely along the east-west axis. In other embodiments, there are between two and six support cables for each row of primary concentrators, preferably between two and four.
The Type 1 secondary concentrator 154 can include two concave trough shaped reflective optical surfaces 38 and 39. In other embodiments, the optical surfaces 38 and 39 of the type 1 secondary concentrator 154 have flat faces. The type 1 secondary concentrator 154, for example, includes the eastward-facing optical surface 38 and the westward-facing optical surface 39. The support system for the Type 1 secondary concentrator 154, in the illustrated embodiment, includes an immobile support cable 30, a trolley attachment 31 to the support cable 30, a plate 32 (e.g., a disk) directly attached to the end of the Type 1 secondary concentrator 154, and a translational tracking cable 33 used to enable the west to east translational tracking direction of the Type 1 secondary concentrator 154 during the day. An assembly 35 discourages the rotation and vertical elevation of the plate 32 attached to both the support cable 30 (e.g., through the trolley attachment 31) and the Type 1 secondary concentrator 154.
As shown in
The number, dimensions, and placement of the individual teeth of the saw-tooth designs illustrated in
In certain embodiments, the optical surface of a secondary concentrator is designed to be operationally-refractive for generally eastward-facing optical surfaces. For example, the operationally-refractive eastward-facing surface can direct radiation from the east to the west. Conversely, if the operationally-refractive optical surface faces generally west, the optical surface can direct radiation from the west to the east. As shown in
Although described in relation to singleton secondary concentrators, the optical surface options described in relation to
In some embodiments, the secondary concentrators use a heat radiator system, where linear radiating heat fins are affixed on their backside, to prevent the secondary concentrator from over heating.
In certain embodiments, the reflective optical surfaces of secondary concentrators make use of polished aluminum, which has the one of the highest known reflectance ratings of any metal in the far IR (e.g., 3000-10000 nanometer) and UV (e.g., 200-400 nanometer) frequency ranges. In alternative embodiments, the reflective optical surfaces of secondary concentrators make use of various coatings depending on the targeted frequency range of the solar concentrated radiation to be concentrated. For solar concentration applications in the near infrared (IR) frequency ranges (e.g., 700-3000 nanometers), a combination of one or more metallic films composed of aluminum, silver, gold, and/or copper, or a combination of these can be used, optionally with protective overcoats. For applications In the VIS (visible) range (e.g., 400-700 nanometers), some embodiments use aluminum, silver, and/or tin, or a combination of thereof, optionally with protective overcoats. The protective overcoats, for example, can consist of multilayer dielectric films such as disilicon trioxide (Si2O3), SiO and/or MgF3.
In certain embodiments, the support cables are kept taut such that the support cables appear essentially horizontal, at a fixed height. This implies that the focal planes of all the primary concentrators connected to the support cables can be held substantially co-planar and horizontal, at a fixed height above the plane, so the focal line of all primary concentrators remain at substantially a fixed distance above the primary concentrator at all times of the day.
In some embodiments, the support cables are not quite horizontal. Even the strongest cables will slightly droop due to gravity; in particular, cables of uniform thickness in the presence of gravity are known to droop to form catenary curves, whose curvature and slope, for example, can depend on the structural properties of the support cables and the force applied to them. This gravity-induced catenary curvature can be significant enough to affect optical design. Pulling the support cables extremely taut to avoid this affect on optical design may not be feasible or cost effective.
Furthermore, support poles and/or stabilization lines may affect the curvature and height of support cables.
In some embodiments, changing the curvature and height of the east-west support cables (e.g., via support poles and/or stabilization lines) provides for vertical tracking changes dependent on the east-west position x by inducing height changes (e.g., with the height of the support cables being lower on the extreme east and west sides of the collection field) along the length of these east-west support cables. This can be used, for example, to change the angle that concentrated solar radiation is directed from the secondary concentrator to the receivers during east-west tracking. An example is provided below in relation to
In some embodiments, a north-south row of secondary concentrators may be joined along their longitudinal axis to allow for coordinated translational tracking. In some embodiments, a row of secondary concentrators can be joined along their longitudinal axis to allow for coordinated rotational tracking. In further embodiments, a row of secondary concentrators can be joined along their longitudinal axis to allow for coordinated translational and rotational tracking. In certain embodiments, a linked north-south row of secondary concentrators, suspended by cables in a way that allows neither rotational nor elevational travel, can be joined along their longitudinal axis to allow for coordinated west to east translational tracking. In some embodiments, a linked north-south row of Type 2 secondary concentrators, suspended by horizontal cables, can be attached in a way that allows elevation but not rotation and joined along their longitudinal axis to allow for coordinated tracking. In other embodiments, a linked north-south row of Type 1 secondary concentrators, suspended by horizontal cables, may be attached in a way that allows rotation but not elevation and joined along their longitudinal axis to allow for coordinated tracking.
In general terms, the array of secondary concentrators are positioned depending on the geometry of the solar collection field so that they can direct concentrated solar radiation to one or more receivers without obstructing one another. As illustrated in
The primary concentrators concentrate the primary concentrated solar radiation entering the secondary concentrators by a significant factor, for example a factor of between 10 and 30, preferably between 15 and 25. Hence optical design of the secondary concentrators can take into account the corresponding increase in optical intensity. In particular, the optical surfaces of the secondary concentrators can be designed to be able to sustain high heat flux. The optical surfaces of each secondary concentrator can be constructed from highly reflective metallic sheeting. The optical surfaces of the secondary concentrators, for example, can be made from aluminum, which has a high melting point of 660.32° C., is relatively inexpensive, has a relatively low density (2.70 g per cubic cm), and can be polished to approximately 75-99%, preferably 85-97%, more preferably 90-95% spectral reflectance. In certain embodiments, the spectral reflectance of the secondary concentrators is approximately 90%. The protective coating of the optical surfaces of the secondary concentrators can include a multilayer dielectric film overcoat.
In some embodiments, structural supporting members can be affixed to the backside of the secondary concentrators for stability in winds. In alternative embodiments, the solar concentration system includes an apparatus for protection from inclement weather, such as apparatus for lowering the secondary concentrators to a sheltered location on the ground.
The secondary concentrators are typically more complex than the primary concentrators, but they are also generally far smaller and far less massive than the primary concentrators (e.g., due the primary concentrator's initial concentration of the solar energy). The secondary concentrators are often modest when apportioned to the far larger area of the primary concentrator that each secondary concentrator services. The aluminum optical surface of the secondary concentrators can have a reflectance of approximately 90%, giving the secondary concentrator a high solar efficiency.
In certain embodiments, each secondary concentrator has one or two reflective optical surfaces, concave in cross section, which have a three-dimensional concave trough shape. In alternative embodiments, the secondary concentrators include refractive as well as reflective elements and are saw-tooth in cross section. In other embodiments, the secondary concentrators are parabolic in cross section. Each of these optical surfaces can function as a linear concentrator. That is, the optical surfaces can focus parallel incoming radiation into a line. The (receiver-directed) focal line of an optical surface of the secondary concentrator, for example, is the hypothetical line at which parallel rays emitted from the receiver would be focused by that optical surface of the secondary concentrator. By the principal of linear optical system reversibility, this implies that radiation departing at any angle from the (receiver-directed) focal line of the secondary concentrator is directed to the receiver. At any given time of the solar day, the secondary concentrator is preferably positioned so its (receiver-directed) focal line coincides with the focal line of the associated primary concentrator.
The illustrations
The east-west support cables may not be strictly horizontal, such that each east-west row of secondary concentrators hanging on the support cables may vary in height above the primary concentrators. This can impact the design of the optical surfaces of the primary concentrators. For example, as shown in
In some embodiments, each of the east-west support cables is substantially identical in shape. This can impact the design of the optical surfaces of the primary concentrators. In a particular example, each pair of primary concentrators having the same east-west position will have co-planar focal planes, and hence these primary concentrators can have the same shape optical surfaces.
In certain embodiments, the focal line of the bidirectional primary concentrator 3b is parallel to the upper portion of the surface of the bidirectional primary concentrator 3b, and runs north-south. Consider a single cylindrical secondary concentrator that tracks west to east in such a way that its (receiver-directed) focal line coincides with the focal line of the bidirectional primary concentrator 3b. Let the extended focal line be the line extending the focal line segment over the collection field to the north and south. Over the day, the extended focal line of the bidirectional primary concentrator 3b moves substantially from west to east. The illustrations in
The eastward facing optical surface 38 of the secondary concentrator is actively concentrating primary concentrated solar radiation 4 at all times of the day prior to a time te and the westward facing optical surface 39 of the secondary concentrator is actively concentrating primary concentrated solar radiation 4 at all times of the day prior to a time tw. This allows some optical surface 38, 39 of the secondary concentrator to receive and concentrate all primary concentrated solar radiation 4 from the bidirectional primary concentrator 3b during those two (early and late) time periods.
Let te be the latest time when the eastward facing optical surface 39 of the secondary concentrator receives all the primary concentrated solar radiation from the bidirectional primary concentrator 3b. Between the start time t0 to this time te, all the primary concentrated solar radiation 4 from the bidirectional primary concentrator 3b is concentrated to (and has a direct unobstructed path to) that eastward facing optical surface 38 of the secondary concentrator. As seen in
Also tw be the earliest time when the westward facing optical surface 39 of the secondary concentrator receives all the primary concentrated solar radiation 4 from the bidirectional primary concentrator 3b. Between the time tw, and the ending time t3, all the primary concentrated solar radiation 4 from the bidirectional primary concentrator 3b is concentrated to (and has a direct unobstructed path to) that westward facing optical surface 39 of the secondary concentrator. As seen in
Let tm=(te+tw)/2 be the middle of the time period from te and tw.
Note that at times between te and tw some of the primary concentrated solar radiation 4 from the bidirectional primary concentrator 3b is directed from west to the east, and some is directed from the east to west. In some embodiments, at a certain time period during the day the solar concentration system executes an east-west switch of the secondary concentrator, where the currently active optical surface of the secondary concentrator switches from an optical surface facing generally east to an optical surface facing generally west. In alternative embodiments, the active optical surface may be the same, but re-oriented, in the two respective time periods. Let the time t1 of starting an east-west switch be a time considerably after the start time t0 and (just) prior to time tm; likewise, let the time t2 to end the east-west switch be a time (just) after tm and considerably prior to the end time t3, so tm=(t1+t2)/2 (for example, let t2=2tm−t1).
The daily schedule of the secondary concentrator's tracking, in time progression, is given by the illustrations shown in
There will be some leakage loss of concentrated solar radiation from the bidirectional primary concentrator 3b if the secondary concentrator is unable to capture and further direct the primary concentrated solar radiation 4 to the receiver 7 at times between tw and te, but there would be no such loss prior to tw and after te. In certain embodiments, the solar concentration system minimizes leakage loss by maximizing the ratio of the height of the primary concentrator focal line to the east-west width of the bidirectional primary concentrator 3b. This, for example, can work to minimize the time duration between tw and te when there can be leakage loss. In other embodiments, the solar concentration system can work to minimize leakage loss by constructing the bidirectional primary concentrator 3b so that at solar noon, the extended focal line of the bidirectional primary concentrator 3b is as far as possible to the east or west of the center of the bidirectional primary concentrator 3b. This implies, for example, that the focal plane of the bidirectional primary concentrator 3b is similarly slanted either east or west, which also may entail (since the east-west slant of the focal plane and corresponding section of the support cable are likely similar to allow the focal lines of the primary and secondary concentrator to coincide) slanting the support cable above the bidirectional primary concentrator 3b at a similar angle. This, for example, insures that the time period between tw and te can be shifted away from solar noon, the period of most intense direct solar irradiation.
In certain embodiments, the concentration system is comprised of the primary and secondary concentrators, and the geometry of the tracking means can be summarized in the following:
(a) At any given time, each north-south strip of primary concentrators has a single extended focal line, and through the course of the day, that extended focal line moves from west to east.
(b) The currently active face of the secondary concentrator substantially faces the primary concentrated radiation from the primary concentrator, and
(c) The (receiver-directed) focal plane of a currently active face of the secondary concentrator substantially coincides with the focal line of the primary concentrator.
The concentration system, in some implementations, includes a tracking system and, optionally, a control system to provide for the positioning of various elements of the concentration system, such as the secondary concentrators and receivers, to increase the efficiency of the collection of solar irradiation throughout a solar day. For example, the tracking system can position and orient the secondary concentrators to increase the effectiveness of solar irradiation collection by the receivers by aligning the active optical surface of each secondary concentrator proximate to the focal line of each respective primary concentrator. Similarly, the tracking system can adjust the positioning of each secondary concentrator, in another example, to aim the secondary concentrated radiation, reflected by the secondary concentrators, substantially at a centralized receiver.
The tracking system, in some embodiments, includes a control system that determines adjustment criteria and signals positioning equipment, such as motors and actuators, to fine tune the positioning of the various system elements. In some examples, the control system can issue control signals to cause an adjustment in the positioning of secondary concentrators, centralized receivers, or components of a tensile structure such as suspension cables used to suspend the secondary concentrators. The control signals may be digital or analog depending on the type of motors and actuators used in a particular system.
In some embodiments, the tracking system includes an open-loop control system with an internal clock and a set of pre-calculated motor control parameters. For example, based upon a table lookup, at specific times throughout a solar day, the open-loop control system can effect the repositioning of one or more of the elements of the solar concentrator system. The table of parameters, in some implementations, can include variations based upon day of the year. In some implementations, information retrieved from the table of parameters can be used to calculate adjustments based upon system settings. For example, based upon a particular geographic location of the solar concentrator system (e.g., latitude, longitude, GPS coordinates, altitude, etc.) the positioning adjustments can vary.
In other embodiments, the tracking system can function with a closed-loop control system relying on both pre-derived calculated (e.g., based upon astronomical equations) as well as external monitoring devices. The external monitoring devices, for example, can include one or more sensors detecting current conditions affecting the solar concentrator system. In some examples, the external monitoring devices can sense the amount of solar energy directed to the centralized receivers (e.g., using one or more solar energy sensors), an external temperature (e.g., as measured by one or more thermometers positioned on the solar concentrator system), wind speed and wind direction (e.g., using wind speed indicators positioned at one or more locations on the solar concentrator system), or solar irradiance intensity and solar irradiance direction (e.g., as determined by one or more directional photosensors positioned on the solar concentrator system). The closed-loop control system, in some implementations, includes a table of look-up data associated with one or more of these monitored values. For example, based upon a particular wind speed a direction, the closed-loop control system may determine that an adjustment in positioning of one or more solar concentrators may be advisable. In some implementations, upon reaching such a determination, the control system employs post-processing to determine appropriate control signals to use for manipulating the system elements (e.g., actuators, motors, etc.).
The tracking and control system, in alternative embodiments, can actively monitor solar irradiation received by the various elements of the solar concentrator system. For example, based upon a measured position and intensity of the sun, the tracking and control system can automatically adjust the positioning of various elements of the solar concentrator system to optimize collection of concentrated solar radiation energy.
In some implementations, the tracking and control system periodically makes adjustments to one or more of the elements of the solar concentrator system. For example, a timer can be used in conjunction with the internal clock to determine a schedule upon which the positions of the elements of the solar concentrator system may be adjusted. In other implementations, the tracking and control system continuously provides readjustments, for example through control signals to appropriate motors and actuators, to position and orient the secondary concentrators, allowing the solar concentrator system to dynamically compensate for changes in monitored conditions so as to optimize the solar energy directed to the centralized receivers.
In a closed-loop system, in some embodiments, feedback control can be provided by conventional closed-loop control theory methods which, for example, determine the dynamic control of the solar concentrator system based on a combination of error signals, measured output, and desired output. Examples of feedback control theory methods include proportional-integral-derivative (PID) mechanisms, which determine an output by an integral calculation, and time-domain mechanisms, which model the problem in state space and solve a first-order differential equation modeling the physical system.
In some embodiments, the relationship between the primary and secondary concentrators can be achieved by west to east translational tracking of the secondary concentrator with possibly some form of vertical or rotational movement to provide compensation for the change in vertical angle to receivers during translational tracking, as well as some sort of mechanism for the east-west switch previously described.
In certain embodiments, the translational and rotational movements of each north-south row of secondary concentrators can be substantially the same, so the secondary concentrators of each north-south row are joined and move on a common axis.
Some embodiments of a tracking apparatus only provide translational tracking, without rotation of the secondary concentrators. The east-west switch, for example, can be achieved by simply moving from the portion of the secondary concentrator facing generally east to the other portion facing generally west.
In some embodiments, the secondary concentrator is positioned a considerable distance from the receivers, so the short daily translational movements by the secondary concentrator are less likely to significantly affect the angles of direction from the secondary concentrators to each receiver.
Certain embodiments of the solar concentration field use a Type 1 secondary concentrator, which is a non-rotating, non-elevating doubled secondary concentrator. The doubled secondary concentrator, for example, has two reflective optical surfaces, positioned facing generally east and west, respectively. The east facing optical surface can be used from the start of the day until the initiation of the east-west switch and, after having executed the east-west switch, the secondary concentrator can be shifted slightly west (e.g., by temporally increasing the rate of west to east translational tracking movement) to switch the incoming primary concentrated solar radiation from the east optical surface to the west optical surface.
In some embodiments, the secondary concentrators track by west to east translational movements as illustrated in
Dynamic effects, from variations in temperature and wind, may induce vertical and rotational oscillations and misalignments of the secondary concentrators and their support cables and posts, as well as transverse movements along the length of the support cables. In some embodiments, for compensation of these dynamic movements, there is an open loop control system for executing various corrections which may include secondary concentrator tracking corrections and cable tension corrections. Each correction, for example, can be based on observed variations of one or more of the following observables: wind magnitude, wind direction, temperature, solar intensity and solar angle.
During certain (e.g., early and latest) periods of the solar day, off-axis aberrations of the secondary concentrators may widen the line focus to the receiver, reducing the performance of the system. In certain embodiments, means are provided for reducing off-axis aberrations of the secondary concentrators, including optimizing the height of the secondary concentrators above the primary concentrators and optimizing the aperture width of the secondary concentrators. In certain embodiments, means are provided for compensation of off-axis aberrations of the secondary concentrator, for example by widening the absorbing region or by movement out of the horizontal plane.
In certain embodiments, the solar radiation concentrated by the primary and secondary concentrators is directed to one or more receivers. In certain embodiments, there are two receivers that collect the concentrated solar radiation, one located to the east of the collection field and one located to the west of the collection field. In some embodiments, the receiver located in the west collects primarily in the AM (prior to solar noon) concentrated solar radiation, the receiver located in the east collects primarily in the PM (after solar noon) concentrated solar radiation.
The optical surface of the receiver acts as an absorbing region that absorbs the concentrated solar radiation incoming from the secondary concentrators. In certain embodiments, the absorbing region of each receiver is rectangular shaped running north-south.
In some embodiments, the absorbing region of each of the receivers is positioned at a height above the ground larger than the height of the secondary concentrators, so that the concentrated solar radiation directed to the receivers comes from an angle below them. To insure the concentrated solar radiation from each secondary concentrator is directed upward to one of the receivers without obstruction from other secondary concentrators, in some implementations the receivers are positioned sufficiently high and the consecutive secondary concentrators are sufficiently separated in the east-west direction.
The receiver can include a medium for transport and at least temporary storage of the absorbed solar energy. In some embodiments, the energy storage media is a bulk thermal storage medium such as liquid sulfur, molten salt (e.g., saltpeter molten salt which is approximately 60% sodium nitrate and approximately 40% potassium nitrate), fluoride-salt, and/or mineral oil (e.g., Therminol VP-1 synthetic oil). In alternative embodiments, the energy storage media includes a phase-change storage medium (such as water to and from steam, or melting and solidifying salts).
Each receiver has a structural housing. The structural housing of the receiver serves to support and protect the other portions of the receiver.
In certain embodiments, within the absorbing region of each of the receiver are positioned a linear array of receiver tubes running north-south. Within each of the receiver tubes, for example, there is a metallic tube containing material used for heat storage (e.g., either bulk heat storage or phase-change heat storage material). Surrounding the interior metallic tube, in some implementations, is a vacuum gap providing insulation. On the exterior of each receiver tube, in some embodiments, is a borosilicate glass tube with an anti-reflective, anti-abrasion coating that has high radiation absorbance and low emittance. The borosilicate glass, for example, offers the same expansion coefficient as the melted down metal. This exterior can allow a high proportion of the solar radiation to penetrate to the interior metallic tube of the receiver and heat the heat transfer material within. For example, current receiver technology such as the SCHOTT PTR 70 Receiver by SCHOTT Solar of Albuquerque, N. Mex. allows over 95% absorbance and less than 10% emittance.
Through the course of the year, the north-south angle of the sun deviates to both the north and the south from its equinox position, for example by approximately 23.5 degrees in the US Southwest. Therefore, the north-south position of the solar radiation concentrated on a receiver can change through the year. In certain embodiments, the receivers are immobile, but their absorbing area is sufficiently long in north-south direction to include the entire range of positions that concentrated solar radiation is directed from over the year. This, for example, can insure the receivers can collect the concentrated solar radiation throughout the year.
In some embodiments, the secondary concentrator has only one optical surface, and it executes an east-west switch by making, at some period in the day, a change in orientation from facing generally east to facing generally west.
In certain embodiments, all concentrated radiation is directed toward one centralized receiver.
In alternative embodiments, the compensation for the change in Ψ (the vertical angle from horizontal to the receiver) during the secondary concentrator's translational movement, is determined by calculating Ψ as the smallest vertical angle from the horizontal that radiation that can be directed, without obstruction, from the secondary concentrator to the receiver.
Recall that, as described in relation to
Further note that the angle Ψ is at a minimum angle on a north-south strip roughly in the middle of the solar collecting field. Also recall, as described in relation to
In certain embodiments, vertical translations of the secondary concentrators can be used to change the direction of concentrated radiation to the receiver, thus providing an apparatus for the changes in angle Ψ toward the receiver during west to east translational tracking.
The exact relationship between the values of the vertical position 93 y and the angle 50 Ψ over the day, for example, depend in part on the configuration of the optical surfaces 38, 39 of the secondary concentrator.
In alternative embodiments, the secondary concentrators use guided cams for translational tracking. The cam systems, for example, can include disks or peg-like cams located at various radii to control the vertical or rotational movement of disks affixed to the ends the secondary concentrator. In some embodiments, the tracking for each north-south row of secondary concentrators is the same. For example, when a row of north-south secondary concentrators has the same tracking, the secondary concentrators can be coupled, and a single cam system can be used for each such north-south row.
Other alternative embodiments include various apparatus for tracking secondary concentrators. Like the Tracking Apparatus 1, the Tracking Apparatus 5 and 6 use only west to east translational tracking. The other Tracking Apparatus 2, 3, 4, and 7 make use of vertical elevation or rotational movements for tracking as well.
Tracking Apparatus 2 can use a single cam as an apparatus for inducing vertical translations to compensate for the change in angle Ψ during the secondary concentrator's east-west translational movement.
In alternative embodiments, each of the two optical surfaces of the double secondary concentrator 166 are shaped and positioned appropriately, so that vertical position y2 is substantially equivalent to vertical position y3 and hence there is no required vertical elevation change during the east-west switch.
In alternative embodiments, the apparatus for the coordinated translational tracking is by the action of one or more motors located at along each east-west strip of primary concentrators. Individual motors coupled with gear systems, for example, can be used for vertical and/or rotational tracking. Since the tracking needs are substantially the same for each north-south row of secondary concentrators, these can optionally be coupled, and a single motor can be used for each such north-south row.
Tracking Apparatus 3 and Tracking Apparatus 4 use rotational tracking.
The Cartesian coordinate location of a point on a rotating and translating disk can be determined with the following equations: {x=vθ+R cos(θ−θ0), y=R sin(θ−θ0}, where the angle θ0 is the starting angular position, β is the angular displacement, R is the distance from the point to the center of the disk, and v is the velocity. These equations can be used to govern the geometry of the cam guides. The cam disk is connected to the secondary concentrator, so that the secondary concentrator rotates with the cam disk (or, optionally, two or more cam disks).
For motivation of Tracking Apparatus 3 and 4,
Observe during the day up to the time of the east-west switch, since the secondary concentrator is tracking east to west toward the east receiver 7, both angle 50 Ψ as well as the counterclockwise angle θ of rotation increase, and thus rotation angle θ0 is less than rotation angle θ1. Recall that the east-west switch can induce an abrupt change in angle 50 Ψ since prior to the east-west switch the east receiver 7 it is used to determine the angle 50 Ψ, while after the east-west switch the west receiver 7 is used to determine the angle 50 Ψ. Hence the rotational angle θ should also be correspondingly reset during the east-west switch and, depending on the number and configuration of the optical surfaces 38, 39 of the secondary concentrator, this east-west switch may provoke a considerable change in the rotational angle θ. Observe that during the day after the time of the east-west switch, since the secondary concentrator is tracking east to west away from the east receiver 7, both the angle 50 Ψ as well as the counterclockwise angle θ of rotation need to decrease, and so the rotation angle θ3 is smaller than the rotation angle θ2. The exact relationship between the values of the rotation angle θ and the angle 50 Ψ over the day depend on the configuration of the optical surfaces 38, 39 of the secondary concentrator.
In some embodiments, Tracking Apparatus 3 uses a single cam for inducing rotation to compensate for the change in angle 50 Ψ during the secondary concentrator's east-west translational movement.
For this cam system to correctly operate, this total rotation change should be less than a value Π, and therefore the two optical surfaces 38, 39 of the double secondary concentrator 168 is designed so that θ2−θ0<Π. Since θ3<θ0, the total rotation deviation over the day can be bounded by θ2−θ0.
The illustrations
In some embodiments, each of the two optical surfaces 38, 39 of the double secondary concentrator 168 are rotated by the appropriate amount, so that the rotational angle θ2 is substantially equivalent to the rotational angle θ3, and hence there is no need to induce a rotational change during the east-west switch.
In certain embodiments, Tracking Apparatus 4 uses a Type 4 (rotating, non-elevating, single) secondary concentrator 170 with one optical face 38. The secondary concentrator 170, as illustrated in
The cam disk 32 then rotates further slowly counterclockwise.
In some embodiments, the Tracking Apparatus 1 makes use of west to east translational tracking of a Type 1 (non-rotating, non-elevating, double, operationally-reflective) secondary concentrator associated with each primary concentrator.
In certain embodiments, as illustrated in
Each of these refractive secondary concentrators 172a, 172b has a saw-tooth contoured operationally-refractive optical surface 38, 39 (e.g., as described in relation to
The receiver-directed focal line for the eastern-facing-refractive secondary concentrator 172a, for example, is a hypothetical line where radiation from the western receiver would be focused. The receiver-directed focal line for the western-facing-refractive secondary concentrator 172b, for example, is a hypothetical line where radiation from the eastern receiver would be focused.
The Tracking Apparatus 5 can make use of a schedule of daily west to east translational tracking similar to that described in relation to Tracking Apparatus 1 with regards to
In some embodiments, Tracking Apparatus 6 directs all concentrated radiation to only one receiver. As shown in
The eastern-facing-reflective secondary concentrator 174a can direct primary concentrated radiation, directed from the east from the primary concentrator beneath, to the eastern receiver. The optical surface 39 of the eastern-facing-reflective secondary concentrator 174a, in some examples, can be configured as either a concave contoured eastern-facing reflective optical surface or a saw-tooth contoured and operationally-reflective optical surface, as illustrated in relation to
The receiver-directed focal line for the eastern-facing-reflective secondary concentrator 174a, for example, is a hypothetical line where radiation from the eastern receiver would be focused. The receiver-directed focal line for the western-facing-refractive secondary concentrator 174b, for example, is a hypothetical line where radiation from the eastern receiver would be focused.
In some embodiments, the Tracking Apparatus 6 can make use of a schedule of daily west to east translational tracking similar to Tracking Apparatus 1, described in relation to
In other embodiments, a tracking apparatus similar to Tracking Apparatus 6 can be provided with a western-facing-reflective secondary concentrator and an eastern-facing-refractive secondary concentrator.
In some embodiments, Tracking Apparatus 7 makes use of a singleton refractive secondary concentrator. Tracking Apparatus 7 includes a singleton reflective secondary concentrator similar to a Type 4 (e.g., rotating, non-elevating, singleton, operationally-reflective) secondary concentrator as described in relation to
The Tracking Apparatus 7, in some embodiments, makes use of a schedule of daily west to east translational tracking and cam-based rotational tracking similar to Tracking Apparatus 4, described in relation to
In other embodiments, the single cam systems can include a second inner cam to allow for more rapid rotation during the east-west switch. To enable this functionality, for example, a further cam disk and cam guide can be added, with a cam peg closer to the axis of rotation, is the further cam disk being only engaged during the east-west switch while the other cam is disengaged.
Recall that the north-south position of the solar radiation concentrated on the receiver changes through the year. In some embodiments, as shown in
In some embodiments, as shown in
The effect of this particular arrangement of receiver tubes is first to partly obscure a significant portion of the surface of every second tube that is not normal to the incoming concentrated solar radiation and second to increase the proportion of the surface of the receiver tubes that receive incoming concentrated solar radiation at an angle near normal to the surface of each respective tube. Since the transmittance of the outer glass surface of each tube is highest for solar radiation that is normal to the surface, this positioning of the receiver tubes can improve the overall transmittance of concentrated solar radiation directed to the absorbing region of the receiver.
In certain embodiments, providing apparatus for energy storage increases the total cost of the manufacture of the overall system, but potentially further increases the cost efficiency, allowing the solar conversion process to occur for a period beyond the solar energy collection period. Since the one or more receivers are centralized, the heat exchanger and energy storage apparatus can also be centrally located near or within the receivers, in some embodiments, to insure rapid and efficient heat transfer. When the receiver absorbing materials cool, for example after completion of the solar day or during a day with reduced direct solar radiation, the stored heat is released.
In certain embodiments, the solar energy system includes an apparatus for bulk thermal storage of the solar energy concentrated at the receivers. In certain embodiments, the apparatus for bulk thermal storage includes the bulk heat storage materials, storage containers for the bulk material, as well as heat exchangers that provide heat transfer to and from the bulk thermal storage material, as well as insulation used to reduce heat loss. The materials used in this alternative embodiment for bulk thermal storage can include, but are not limited to, liquid sulfur, molten salt, mineral oils, and concrete. Concrete, for example, is likely the lowest cost of these bulk thermal storage materials. While conventional concrete generally consists of a mixture of an aggregate, portland cement, water, and admixtures, in certain embodiments the bulk thermal storage material consists of high-temperature concrete, for example, the MEYCO Fireshield 1350©, available from BASF SE of Ludwigshafen, Germany. The bulk thermal storage material, in this example, can be made by replacing the usual aggregate with an alternative material.
In some embodiments, the solar energy system includes an apparatus for phase-change storage of the solar energy concentrated by the centralized receivers. The heat exchangers and storage containers for the phase-change materials, for example, can be located within or just in back of the receivers and insulation can be used to reduce heat loss. The substances used for bulk thermal storage, for example, can include various salts which form eutectics with other salts and other materials which store and release heat by melting and solidifying, respectively. Examples of these phase-change materials include NaCl, NaNO3, KNO3, as well as the combination of ZnCl2 and KCl, and the combination of MgCl and NaCl.
In certain embodiments, the solar concentrator system includes an apparatus for chemical energy storage of the concentrated solar energy at the receivers. Typically, the chemicals provide that energy storage react in the presence of heat and catalysis. The reaction absorbs heat, and various chemical products are stored. After the solar day, the stored heat can be released by a reverse reaction.
An example apparatus for storage of the concentrated solar energy is illustrated in
As further illustrated in
In certain embodiments, the thermal storage is partitioned into a series of blocks of thermal storage, the blocks providing thermal storage in the form of bulk heat storage, chemical heat storage, or phase-change energy storage. The number of blocks of thermal storage currently used, in some embodiments, can be dynamically varied in accordance to the total amount of concentrated solar energy needed to be stored. There can be means, for example, for heat transport between certain of these blocks, as well as means for heat transport from the solar collecting system to these blocks and also means for heat transport from certain of these blocks to the system using the concentrated solar energy. In the initial case of no heat being currently stored, for example, only one block of heat storage may be active. Additional blocks can be activated when needed for additional heat storage, and blocks can be deactivated when no longer needed for additional heat storage.
In certain embodiments of this dynamic thermal storage system, the blocks are configured in one or more linear arrays, wherein only a consecutive subsequence of blocks is activated for energy storage at any time. There can be means for heat transport between each consecutive pair of blocks, as well as heat transport from the solar collecting system to the first block of each array of blocks as well as means for heat transport from the first block of each array to the system that uses the concentrated solar energy. In the initial case of no heat being currently stored, for example, only the first block of each array of heat storage blocks is actively used for heat storage. When needed for additional heat storage, the unique unactivated(?) block neighboring the currently activated sequence of blocks can be activated by transporting heat to it. One or more blocks at the end of this activated sequence, for example, may be deactivated by no longer transporting heat to them when they are no longer needed for heat storage.
In alternative embodiments, the solar concentrator system includes a power-block that makes use of photovoltaic panels that convert the concentrated solar energy to produce electrical energy.
In some embodiments, as shown in
In some embodiments, the solar energy system includes a power-block that makes use of pressurized hydrogen gas, for example obtained by heating a metallic hydride, to drive a gas turbine.
Within the receiver 7 is a reaction chamber consisting of an array of horizontal steam pipes 176, filled, for example, with a metallic hydride as well as catalysts. The concentrated solar heating (to disassociation temperature) of the metallic hydride (such as magnesium hydride) in the reaction chamber at the receiver 7 results in two reaction products: the base metal product and hydrogen gas H2 at the dissociation pressure.
The volume expansion, from the release of a large volume of hydrogen gas H2 product, can be used to convert the thermal energy into kinetic energy to drive the gas turbine of the gas turbine electrical power generator 145. The reaction chamber can be connected by one or more pipes to the gas turbine electrical power generator 145. Such turbines, for example, can have up to 42% efficiency depending on size.
After driving through the gas turbine electrical power generator 145, the hydrogen enters the return storage chamber 147 which also, for example, has a pipe (used after the solar energy generation has ended for the day) back to the metallic hydride reaction chamber 142.
The use of a metallic hydride/hydrogen turbine for conversion from heat energy to electrical power can provide improved efficiency over a steam turbine system, since the temperature differential between the cooled state and the heated state required for gaseous dissociation can be considerably larger in the metallic hydride/hydrogen turbine energy conversion system than a steam turbine system.
In some embodiments, the power block closes the back-flow control 148 during the period of the solar day when heat energy is generated. Then, after the solar day, when the base metal of the metallic hydride in the reaction chamber 142 has cooled, the back-flow control valve 148 can be opened to allow the hydrogen to flow back to the reaction chamber 142.
In some embodiments, an additional gas storage chamber 144 for storage of energy is added to the power block, as illustrated in
Concentrated solar thermal-electrical plants can make use of solar radiation (e.g., primarily in the infrared (IR) range) to generate electricity, where as solar photovoltaic (PV) plants make use of solar radiation primarily in the UV and VIS ranges to generate electricity.
In certain embodiments, the solar energy system includes an apparatus for separation of concentrated solar radiation in the IR range from the solar radiation in UV and VIS ranges, and apparatus for thermal-electrical generation for harvesting the solar energy in the IR range, as well photovoltaic apparatus for harvesting the solar energy in the UV and VIS ranges.
Through the use of refractive and/or reflective surfaces with optical coatings, solar radiation in the IR range can be separated from the solar radiation in UV and VIS ranges. In some embodiments, the separation of the IR range from the UV and VIS ranges is achieved at the primary concentrators. In other embodiments, the separation of the IR range from the UV and VIS ranges is achieved at the secondary concentrators. In alternative embodiments, the receivers separate solar radiation in the IR range from solar radiation in the UV and VIS ranges.
In the case where the separation is done at the receivers, each of at least two (e.g., east, west) receivers can be portioned into a pair of subreceivers A and B, one for absorbing primarily in the IR range, and the other for absorbing primarily in the UV and VIS ranges.
For example,
In some embodiments, the solar energy system includes systems for generation of electrical energy as well as a system for distribution of the remaining and/or waste thermal energy for other productive use. The further productive use of this thermal energy can include, in some examples, smelting, the heating of buildings, the enhancement of chemical reactions (e.g., heating water to enhance the production of hydrogen by electrolysis), and further generation of electrical energy by thermal-cycles with lower temperature differentials.
In certain embodiments, the solar energy system includes systems for generation of electrical energy where a portion of the electricity can be used for generation of hydrogen energy by electrolysis. The remaining and/or waste thermal energy, for example, can be used in part for heating water to enhance this production of hydrogen by electrolysis.
A number of embodiments of the invention have been described. Nevertheless, it will be understood that various modifications may be made without departing from the spirit and scope of the invention. Accordingly, other embodiments are within the scope of the following claims.
This application is a continuation-in-part of provisional application Ser. No. 61/245,250, filed Sep. 23, 2009 which is herein incorporated by reference.
| Number | Date | Country | |
|---|---|---|---|
| 61245250 | Sep 2009 | US |
