US20070215195A1 - Elongated photovoltaic cells in tubular casings - Google Patents

Elongated photovoltaic cells in tubular casings Download PDF

Info

Publication number
US20070215195A1
US20070215195A1 US11/378,847 US37884706A US2007215195A1 US 20070215195 A1 US20070215195 A1 US 20070215195A1 US 37884706 A US37884706 A US 37884706A US 2007215195 A1 US2007215195 A1 US 2007215195A1
Authority
US
United States
Prior art keywords
solar cell
layer
cell unit
tubular casing
glass
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
US11/378,847
Other languages
English (en)
Inventor
Benyamin Buller
Chris Gronet
Ratson Morad
Markus Beck
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.)
Solyndra Inc
Original Assignee
Solyndra Inc
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 Solyndra Inc filed Critical Solyndra Inc
Priority to US11/378,847 priority Critical patent/US20070215195A1/en
Assigned to SOLYNDRA, INC. reassignment SOLYNDRA, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BECK, MARKUS E., BULLER, BENYAMIN, GRONET CHRIS M., MORAD, RATSON
Priority to KR1020137022483A priority patent/KR20130101159A/ko
Priority to EP07867021A priority patent/EP1999798A2/en
Priority to KR1020087025428A priority patent/KR20080112313A/ko
Priority to CN2007800180661A priority patent/CN101449386B/zh
Priority to DE202007018756U priority patent/DE202007018756U1/de
Priority to PCT/US2007/006615 priority patent/WO2008060315A2/en
Priority to JP2009501465A priority patent/JP2009530852A/ja
Assigned to HSH NORDBANK AG, NEW YORK BRANCH, AS COLLATERAL AGENT reassignment HSH NORDBANK AG, NEW YORK BRANCH, AS COLLATERAL AGENT SECURITY AGREEMENT Assignors: SOLYNDRA, INC.
Priority to US11/800,089 priority patent/US20070215197A1/en
Priority to US11/821,524 priority patent/US8742252B2/en
Publication of US20070215195A1 publication Critical patent/US20070215195A1/en
Priority to US12/012,462 priority patent/US20080302415A1/en
Priority to US12/115,485 priority patent/US20080302418A1/en
Priority to US12/207,463 priority patent/US20090007963A1/en
Priority to US12/235,195 priority patent/US20090014055A1/en
Assigned to SOLYNDRA, INC. reassignment SOLYNDRA, INC. TERMINATION OF SECURITY INTEREST IN PATENTS Assignors: HSH NORDBANK AG, NEW YORK BRANCH
Assigned to ARGONAUT VENTURES I, L.L.C. reassignment ARGONAUT VENTURES I, L.L.C. SECURITY AGREEMENT Assignors: SOLYNDRA, INC.
Assigned to SOLYNDRA LLC reassignment SOLYNDRA LLC ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SOLYNDRA, INC.
Assigned to U.S. BANK NATIONAL ASSOCIATION reassignment U.S. BANK NATIONAL ASSOCIATION SECURITY AGREEMENT Assignors: SOLYNDRA LLC (FORMERLY KNOWN AS SOLYNDRA FAB 2 LLC)
Assigned to U.S. BANK NATIONAL ASSOCIATION reassignment U.S. BANK NATIONAL ASSOCIATION SECURITY AGREEMENT Assignors: SOLYNDRA LLC
Priority to JP2013077328A priority patent/JP2013175746A/ja
Assigned to SOLYNDRA RESIDUAL TRUST reassignment SOLYNDRA RESIDUAL TRUST ORDER CONFIRMING DEBTOR'S AMENDED JOINT CHAPTER 11 PLAN Assignors: SOLYNDRA LLC
Assigned to SOLYNDRA RESIDUAL TRUST reassignment SOLYNDRA RESIDUAL TRUST BANKRUPTCY COURT/ORDER CONFIRMING DEBTORS' AMENDED JOINT CHAPTER 11 PLAN Assignors: SOLYNDRA LLC
Assigned to SOLYNDRA RESIDUAL TRUST reassignment SOLYNDRA RESIDUAL TRUST ORDER CONFIRMING DEBTOR'S AMENDED JOINT CHAPTER 11 PLAN Assignors: SOLYNDRA LLC
Abandoned legal-status Critical Current

Links

Images

Classifications

    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01L—SEMICONDUCTOR DEVICES NOT COVERED BY CLASS H10
    • H01L31/00—Semiconductor devices sensitive to infrared radiation, light, electromagnetic radiation of shorter wavelength or corpuscular radiation and specially adapted either for the conversion of the energy of such radiation into electrical energy or for the control of electrical energy by such radiation; Processes or apparatus specially adapted for the manufacture or treatment thereof or of parts thereof; Details thereof
    • H01L31/0248—Semiconductor devices sensitive to infrared radiation, light, electromagnetic radiation of shorter wavelength or corpuscular radiation and specially adapted either for the conversion of the energy of such radiation into electrical energy or for the control of electrical energy by such radiation; Processes or apparatus specially adapted for the manufacture or treatment thereof or of parts thereof; Details thereof characterised by their semiconductor bodies
    • H01L31/0352—Semiconductor devices sensitive to infrared radiation, light, electromagnetic radiation of shorter wavelength or corpuscular radiation and specially adapted either for the conversion of the energy of such radiation into electrical energy or for the control of electrical energy by such radiation; Processes or apparatus specially adapted for the manufacture or treatment thereof or of parts thereof; Details thereof characterised by their semiconductor bodies characterised by their shape or by the shapes, relative sizes or disposition of the semiconductor regions
    • H01L31/035272—Semiconductor devices sensitive to infrared radiation, light, electromagnetic radiation of shorter wavelength or corpuscular radiation and specially adapted either for the conversion of the energy of such radiation into electrical energy or for the control of electrical energy by such radiation; Processes or apparatus specially adapted for the manufacture or treatment thereof or of parts thereof; Details thereof characterised by their semiconductor bodies characterised by their shape or by the shapes, relative sizes or disposition of the semiconductor regions characterised by at least one potential jump barrier or surface barrier
    • H01L31/035281—Shape of the body
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01L—SEMICONDUCTOR DEVICES NOT COVERED BY CLASS H10
    • H01L31/00—Semiconductor devices sensitive to infrared radiation, light, electromagnetic radiation of shorter wavelength or corpuscular radiation and specially adapted either for the conversion of the energy of such radiation into electrical energy or for the control of electrical energy by such radiation; Processes or apparatus specially adapted for the manufacture or treatment thereof or of parts thereof; Details thereof
    • H01L31/04—Semiconductor devices sensitive to infrared radiation, light, electromagnetic radiation of shorter wavelength or corpuscular radiation and specially adapted either for the conversion of the energy of such radiation into electrical energy or for the control of electrical energy by such radiation; Processes or apparatus specially adapted for the manufacture or treatment thereof or of parts thereof; Details thereof adapted as photovoltaic [PV] conversion devices
    • 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
    • Y02E10/50—Photovoltaic [PV] energy
    • 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
    • Y02E10/50—Photovoltaic [PV] energy
    • Y02E10/52—PV systems with concentrators
    • 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
    • Y02E10/50—Photovoltaic [PV] energy
    • Y02E10/541—CuInSe2 material PV cells
    • 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
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P70/00—Climate change mitigation technologies in the production process for final industrial or consumer products
    • Y02P70/50—Manufacturing or production processes characterised by the final manufactured product

Definitions

  • This invention relates to solar cell assemblies for converting solar energy into electrical energy and more particularly to improved solar cell assemblies.
  • Solar cells are typically fabricated as separate physical entities with light gathering surface areas on the order of 4-6 cm 2 or larger. For this reason, it is standard practice for power generating applications to mount the cells in a flat array on a supporting substrate or panel so that their light gathering surfaces provide an approximation of a single large light gathering surface. Also, since each cell itself generates only a small amount of power, the required voltage and/or current is realized by interconnecting the cells of the array in a series and/or parallel matrix.
  • FIG. 1 A conventional prior art solar cell structure is shown in FIG. 1 . Because of the large range in the thickness of the different layers, they are depicted schematically. Moreover, FIG. 1 is highly schematic so that it represents the features of both “thick-film” solar cells and “thin-film” solar cells.
  • solar cells that use an indirect band gap material to absorb light are typically configured as “thick-film” solar cells because a thick film of the absorber layer is required to absorb a sufficient amount of light.
  • Solar cells that use a direct band gap material to absorb light are typically configured as “thin-film” solar cells because only a thin layer of the direct band-gap material is needed to absorb a sufficient amount of light.
  • Layer 102 is the substrate. Glass or metal is a common substrate. In thin-film solar cells, substrate 102 can be-a polymer-based backing, metal, or glass. In some instances, there is an encapsulation layer (not shown) coating substrate 102 . Layer 104 is the back electrical contact for the solar cell.
  • Layer 106 is the semiconductor absorber layer. Back electrical contact 104 makes ohmic contact with absorber layer 106 . In many but not all cases, absorber layer 106 is a p-type semiconductor. Absorber layer 106 is thick enough to absorb light. Layer 108 is the semiconductor junction partner-that, together with semiconductor absorber layer 106 , completes the formation of a p-n junction. A p-n junction is a common type of junction found in solar cells. In p-n junction based solar cells, when semiconductor absorber layer 106 is a p-type doped material, junction partner 108 is an n-type doped material.
  • junction partner 108 is a p-type doped material. Generally, junction partner 108 is much thinner than absorber layer 106 . For example, in some instances junction partner 108 has a thickness of about 0.05 microns. Junction partner 108 is highly transparent to solar radiation. Junction partner 108 is also known as the window layer, since it lets the light pass down to absorber layer 106 .
  • absorber layer 106 and window layer 108 can be made from the same semiconductor material but have different carrier types (dopants) and/or carrier concentrations in order to give the two layers their distinct p-type and n-type properties.
  • dopants copper-indium-gallium-diselenide
  • CdS copper-indium-gallium-diselenide
  • junction partner 108 Other materials that can be used for junction partner 108 include, but are not limited to, In 2 Se 3 , In 2 S 3 , ZnS, ZnSe, CdlnS, CdZnS, ZnIn 2 Se 4 , Zn 1-x Mg x O, CdS, SnO 2 , ZnO, ZrO 2 and doped ZnO.
  • Layer 110 is the counter electrode, which completes the functioning cell. Counter electrode 110 is used to draw current away from the junction since junction partner 108 is generally too resistive to serve this function. As such, counter electrode 110 should be highly conductive and transparent to light. Counter electrode 110 can in fact be a comb-like structure of metal printed onto layer 108 rather than forming a discrete layer. Counter electrode 110 is typically a transparent conductive oxide (TCO) such as doped zinc oxide (e.g., aluminum doped zinc oxide, gallium doped zinc oxide, boron dope zinc oxide), indium-tin-oxide (ITO), tin oxide (SnO 2 ), or indium-zinc oxide.
  • TCO transparent conductive oxide
  • a bus bar network 114 is typically needed in conventional solar cells to draw off current since the TCO has too much resistance to efficiently perform this function in larger solar cells.
  • Network 114 shortens the distance charge carriers must move in the TCO layer in order to reach the metal contact, thereby reducing resistive losses.
  • the metal bus bars also termed grid lines, can be made of any reasonably conductive metal such as, for example, silver, steel or aluminum. In the design of network 114 , there is design a trade off between thicker grid lines that are more electrically conductive but block more light, and thin grid lines that are less electrically conductive but block less light.
  • the metal bars are preferably configured in a comb-like arrangement to permit light rays through TCO layer 110 .
  • Bus bar network layer 114 and TCO layer 110 act as a single metallurgical unit, functionally interfacing with a first ohmic contact to form a current collection circuit.
  • a combined silver bus bar network and indium-tin-oxide layer function as a single, transparent ITO/Ag layer.
  • Layer 112 is an antireflective coating that can allow a significant amount of extra light into the cell. Depending on the intended use of the cell, it might be deposited directly on the top conductor as illustrated in FIG. 1 . Alternatively or additionally, antireflective coating 112 made be deposited on a separate cover glass that overlays top electrode 110 . Ideally, the antireflective coating reduces the reflection of the cell to very near zero over the spectral region in which photoelectric absorption occurs, and at the same time increases the reflection in the other spectral regions to reduce heating.
  • U.S. Pat. No. 6,107,564 to Aguilera et al. hereby incorporated by reference herein in its entirety, describes representative antireflective coatings that are known in the art.
  • Solar cells typically produce only a small voltage. For example, silicon based solar cells produce a voltage of about 0.6 volts (V). Thus, solar cells are interconnected in series or parallel in order to achieve greater voltages. When connected in series, voltages of individual cells add together while current remains the same. Thus, solar cells arranged in series reduce the amount of current flow through such cells, compared to analogous solar cells arrange in parallel, thereby improving efficiency. As illustrated in FIG. 1 , the arrangement of solar cells in series is accomplished using interconnects 116 . In general, an interconnect 116 places the first electrode of one solar cell in electrical communication with the counter-electrode of an adjoining solar cell.
  • conventional solar cells are typically in the form of a plate structure. Although such cells are highly efficient when they are smaller, larger planar solar cells have reduced efficiency because it is harder to make the semiconductor films that form the junction in such solar cells uniform. Furthermore, the occurrence of pinholes and similar flaws increase in larger planar solar cells. These features can cause shunts across the junction.
  • U.S. Pat. No. 6,762,359 B2 to Asia et al. discloses a solar cell 210 including a p-type layer 12 and an n-type layer 14 .
  • a first electrode 32 is provided on one side of the solar cell. Electrode 32 is in electrical contact with n-type layer 14 of solar cell 210 .
  • Second electrode 60 is on the opposing side of the solar cell. Electrode 60 is in electrical contact with the p-type layer of the solar cell.
  • Light-transmitting layers 200 and 202 form one side of device 210 while layer 62 forms the other side. Electrodes 32 and 60 are separated by insulators 40 and 50 .
  • the solar cell has a tubular shape rather than the spherical shape illustrated in FIG. 2 . While device 210 is functional, it is unsatisfactory. Electrode 60 has to pierce absorber 12 in order to make an electrical contact. This results in a net loss in absorber area, making the solar cell less efficient. Furthermore, such a junction is difficult to make relative to other solar cell designs.
  • U.S. Pat. No. 3,976,508 to Mlavsky discloses a tubular solar cell comprising a cylindrical silicon tube 2 of n-type conductivity that has been subjected to diffusion of boron into its outer surface to form an outer p-conductivity type region 4 and thus a p-n junction 6 .
  • the inner surface of the cylindrical tube is provided with a first electrode in the form of an adherent metal conductive film 8 that forms an ohmic contact with the tube.
  • Film 8 covers the entire inner surface of the tube and consists of a selected metal or metal alloy having relatively high conductivity, e.g., gold, nickel, aluminum, copper or the like, as disclosed in U.S. Pat. Nos.
  • the outer surface is provided with a second electrode in the form of a grid consisting of a plurality of circumferentially extending conductors 10 that are connected together by one or more longitudinally-extending conductors 12 .
  • the opposite ends of the outer surface of the hollow tube are provided with two circumferentially-extending terminal conductors 14 and 16 that intercept the longitudinally-extending conductors 12 .
  • the spacing of the circumferentially-extending conductors 10 and the longitudinally-extending conductors 12 is such as to leave areas 18 of the outer surface of the tube exposed to solar radiation.
  • Conductors 12 , 14 and 16 are made wider than the circumferentially-extending conductors 10 since they carry a greater current than any of the latter.
  • conductors are made of an adherent metal film like the inner electrode 8 and form ohmic contacts with the outer surface of the tube. While the solar cell disclosed in FIG. 2 is functional, it is also unsatisfactory. Conductors 12 , 14 , and 16 are not transparent to light and therefore the amount of light that the solar cell receives is reduced.
  • U.S. Pat. No. 3,990,914 to Weinstein and Lee discloses another form of tubular solar cell. Like Mlavsky, the Weinsten and Lee solar cell has a hollow core. However, unlike Mlavsky, Weinstein and Lee dispose the solar cell on a glass tubular support member. The Weinstein and Lee solar cell has the drawback of being bulky and expensive to build.
  • Japanese Patent Application Kokai Publication Number S59-125670, Toppan Printing Company, published Jul. 20, 1984 discloses a rod-shaped solar cell.
  • the rod shaped solar cell is depicted in cross-section in FIG. 2C .
  • a conducting metal is used as core 1 of the cell.
  • a light-activated amorphous silicon semiconductor layer 3 is provided on core 1 .
  • An electrically conductive transparent conductive layer 4 is built up on top of semiconductor layer 3 .
  • the transparent conductive layer 4 can be made of materials such as indium oxide, tin oxide or indium tin oxide (ITO) and the like. As illustrated in FIG.
  • a layer 5 made of a good electrical conductor, is provided on the lower portion of the solar cell.
  • This good conductive layer 5 is not particularly necessary but helps to lower the contact resistance between the rod and a conductive substrate 7 that serves as a counter-electrode.
  • conductive layer 5 serves as a current collector that supplements the conductivity of counter-electrode 7 illustrated in FIG. 2D .
  • rod-shaped solar cells 6 are multiply arranged in a row parallel with each other, and counter-electrode layer 7 is provided on the surface of the rods that is not irradiated by light so as to electrically make contact with each transparent conductive layer 4 .
  • the rod-shaped solar cells 6 are arranged in parallel and both ends of the solar cells are hardened with resin or a similar material in order to fix the rods in place.
  • S59-125670 addresses many of the drawbacks associated with planar solar cells.
  • S59-125670 has a number of significant drawbacks that limit the efficiency of the disclosed devices.
  • a full side of each rod is not exposed to light and can thus serve as a leakage path.
  • Such a leakage path reduces the efficiency of the solar cell. For example, any such dark junction areas will result in a leakage that will detract from the photocurrent of the cell.
  • Another disadvantage with the design disclosed in FIGS. 2C and 2D is that the rods are arranged in parallel rather than in series. Thus, the current levels in such devices will be large, relative to a corresponding serially arranged model, and therefore subject to resistive losses.
  • Twin Solar German Unexamined Patent Application DE 43 39 547 A1 to Twin Solar-Technik Anlagens-GmbH, published May 24, 1995, also discloses a plurality of rod-shaped solar cells 2 arranged in a parallel manner inside a transparent sheet 28 , which forms the body of the solar cell.
  • Transparent sheet 28 allows light in from both faces 47 A and 47 B.
  • Transparent sheet 28 is installed at a distance from a wall 27 in such a manner as to provide an air gap 26 through which liquid coolant can flow.
  • Twin Solar devices have the drawback that they are not truly bifacial.
  • face 47 A of the Twin Solar device is capable of receiving direct light.
  • direct light is light that has not passed through any media other than air. For example, light that has passed through a transparent substrate, into a solar cell assembly and exited the assembly, is no longer direct light once it exits the solar cell assembly. Light that has merely reflected off of a surface, however, is direct light provided that it has not passed through a solar cell assembly.
  • face 47 B is not configured to receive direct light. This is because all light received by face 47 B must first traverse the body of the solar cell apparatus after entering the solar cell apparatus through face 47 A. Such light must then traverse cooling chamber 26 , reflect off back wall 42 , and finally re-enter the solar cell through face 47 B. The solar cell assembly is therefore inefficient because direct light cannot enter both sides of the assembly.
  • a solar cell unit comprising a cylindrical shaped solar cell and a transparent tubular casing.
  • the cylindrical shaped solar cell comprises a back-electrode, a semiconductor junction layer circumferentially disposed on the back-electrode, and a transparent conductive layer disposed on the semiconductor junction.
  • the transparent tubular casing is circumferentially sealed onto the cylindrically shaped solar cell so that there is no air between the transparent tubular casing and the cylindrically shaped solar cell in the solar cell unit.
  • the transparent tubular casing is made of plastic or glass.
  • the cylindrically shaped solar cell further comprises a cylindrical substrate and the back-electrode is circumferentially disposed on the cylindrical substrate.
  • the cylindrical substrate can be made of a wide variety of materials including plastic, metal, or glass.
  • the cylindrical substrate is hollowed (e.g., a tube). Therefore, fluids such as air, nitrogen, or helium can be passed through the cylindrical substrate in many embodiments of the present invention. In some embodiments, however, the cylindrical substrate is solid.
  • the semiconductor junction comprises a homojunction, a heterojunction, a heteroface junction, a buried homojunction, a p-i-n junction, or a tandem junction.
  • the conductor junction comprises an absorber layer and a junction partner layer and the junction partner layer is circumferentially disposed on the absorber layer.
  • the absorber layer is copper-indium-gallium-diselenide and the junction partner layer is In 2 Se 3 , In 2 S 3 , ZnS, ZnSe, CdlnS, CdZnS, ZnIn 2 Se 4 , Zn 1-x Mg x O, CdS, SnO 2 , ZnO, ZrO 2 , or doped ZnO.
  • the cylindrical shaped solar cell further comprises an intrinsic layer circumferentially disposed on the semiconductor junction.
  • the transparent conductive layer is disposed on the intrinsic layer rather than the semiconductor junction.
  • the solar cell unit further comprises a filler layer circumferentially disposed on the transparent conductive layer.
  • the transparent tubular casing is circumferentially disposed on the filler layer thereby circumferentially sealing the tubular shaped solar cell.
  • a water resistant layer is circumferentially disposed on the transparent conductive layer.
  • the transparent tubular casing is circumferentially disposed on the water resistant layer thereby circumferentially sealing the cylindrical shaped solar cell.
  • a water resistant layer is circumferentially disposed on the transparent conductive layer and a filler layer circumferentially is disposed on the water resistant layer.
  • the transparent tubular casing is circumferentially disposed on the filler layer thereby circumferentially sealing the cylindrical shaped solar cell.
  • the solar cell unit further comprises a filler layer circumferentially disposed on the transparent conductive layer and a water resistant layer circumferentially disposed on the water resistant layer.
  • the transparent tubular casing is circumferentially disposed on the water resistant layer thereby circumferentially sealing the cylindrical shaped solar cell.
  • the solar cell unit further comprises an antireflective coating circumferentially disposed on the transparent tubular casing.
  • the cylindrically shaped solar cell further comprises at least one electrode strip, where each electrode strip in the at least one electrode strip is overlayed on the transparent conductive layer of the solar cell along the long cylindrical axis of the solar cell.
  • the at least one electrode strip comprises a plurality of electrode strips that are positioned at spaced intervals on the transparent conductive layer such that the plurality of electrode strips run parallel or approximately parallel to each other along the cylindrical axis of the solar cell.
  • the plurality of electrode strips can be spaced out at, for example, sixty degree intervals on a surface of the transparent conductive layer of the solar cell.
  • the electrode strips in the plurality of electrode strips can be spaced out at any type of even interval or uneven interval on the surface of the transparent conductive layer of the solar cell.
  • a length of the cylindrical shaped solar cell is between 0.3 meters and 2 meters.
  • an outer surface of the transparent tubular casing is textured.
  • a solar cell assembly comprising a plurality of solar cell units.
  • Each solar cell unit in the plurality of solar cell units has the structure of any of the solar cell units described above.
  • the solar cell units in the plurality of solar cell units are arranged in coplanar rows to form the solar cell assembly.
  • the solar assembly further comprises an albedo surface positioned to reflect sunlight into the plurality of solar cell units.
  • the albedo surface has an albedo that exceeds 95%.
  • the albedo surface is a Lambertian, diffuse, or involute reflector surface.
  • a first solar cell unit and a second solar cell unit in the plurality of solar cell units is electrically arranged in series or in parallel.
  • Still another aspect of the present invention comprises a solar cell assembly comprising a plurality of solar cell units and a plurality of internal reflectors.
  • Each of the solar cell units in the plurality of solar cell units has the structure of any of the solar cell units described above.
  • the plurality of internal reflectors are arranged in coplanar rows in which internal reflectors in the plurality of solar cell units abut solar cell units in the plurality of solar cell units thereby forming the solar cell assembly.
  • an internal reflector in the plurality of internal reflectors has a hollow core.
  • an internal reflector in the plurality of internal reflectors comprises a plastic casing with a layer of reflective material deposited on the plastic casing.
  • an internal reflector in the plurality of internal reflectors is a single piece made out of a reflective material.
  • a cross-sectional shape of an internal reflector in the plurality of internal reflectors is astroid.
  • a cross-sectional shape of an internal reflector in the plurality of internal reflectors is four-sided and a side of the four-sided cross-sectional shape is linear, parabolic, concave, circular or elliptical.
  • a cross-sectional shape of an internal reflector in the plurality of internal reflectors is four-sided and a side of the four-sided cross-sectional shape defines a diffuse surface on the internal reflector.
  • Still another aspect of the invention provides a solar cell unit comprising a cylindrical shaped solar cell, a filler layer, and a transparent tubular casing.
  • the cylindrical shaped solar cell comprises a cylindrical substrate, a back-electrode circumferentially disposed on the cylindrical substrate, a semiconductor junction circumferentially disposed on the back-electrode, and a transparent conductive layer disposed on the semiconductor junction.
  • the cylindrical substrate can be a hollowed cylinder (e.g., tube) or a solid cylinder.
  • the filler layer is circumferentially disposed on the transparent conductive layer and the transparent tubular casing is circumferentially disposed onto the filler layer.
  • the semiconductor junction comprises an absorber layer and a junction partner layer and the junction partner layer is circumferentially disposed on the absorber layer while the absorber layer is circumferentially disposed on the back-electrode.
  • the solar cell unit further comprises an antireflective coating circumferentially disposed on the transparent tubular casing.
  • a solar cell unit comprising a cylindrical shaped solar cell, a water resistant layer, a filler layer, and a transparent tubular casing.
  • the cylindrical shaped solar cell comprises a cylindrical substrate, a back-electrode circumferentially disposed on the cylindrical substrate, a semiconductor junction circumferentially disposed on the back-electrode, and a transparent conductive layer disposed on the semiconductor junction.
  • the cylindrical substrate can be a solid cylinder or a hollowed cylinder (e.g., a tube).
  • the water resistant layer is circumferentially disposed on the transparent conductive layer.
  • the filler layer circumferentially disposed on the water resistant layer.
  • the transparent tubular casing is circumferentially disposed onto is filler layer.
  • Still another aspect of the invention provides a solar cell unit comprising a cylindrical shaped solar cell, a filler layer, a water resistant layer, and a transparent tubular casing.
  • the cylindrical shaped solar cell comprises a cylindrical substrate, a back-electrode circumferentially disposed on the cylindrical substrate, a semiconductor junction circumferentially disposed on the back-electrode, and a transparent conductive layer disposed on the semiconductor junction.
  • the cylindrical substrate can be solid or hollowed (e.g., a tube).
  • the filler layer is circumferentially disposed on the transparent conductive layer.
  • the water resistant layer is circumferentially disposed on the filler layer.
  • the transparent tubular casing is circumferentially disposed onto the water resistant layer.
  • FIG. 1 illustrates interconnected solar cells in accordance with the prior art.
  • FIG. 2A illustrates a spherical solar cell including a p-type inner layer and an n-type outer layer in accordance with the prior art.
  • FIG. 2B illustrates a tubular photovoltaic element comprising a cylindrical silicon tube of n-type conductivity that has been subjected to diffusion of boron into its outer surface to form an outer p-conductivity type region and thus a tubular solar cell in accordance with the prior art.
  • FIG. 2C is a cross-sectional view of an elongated solar cell in accordance with the prior art.
  • FIG. 2D is a cross-sectional view of a solar cell assembly in which a plurality of elongated solar cells are affixed to an electrically conductive substrate in accordance with the prior art.
  • FIG. 2E is a cross-sectional view of a solar cell assembly disposed a distance away from a reflecting wall in accordance with the prior art.
  • FIG. 3A illustrates a photovoltaic element with tubular casing, in accordance with an embodiment of the present invention.
  • FIG. 3B illustrates a cross-sectional view of an elongated solar cell in a transparent tubular casing, in accordance with an embodiment of the present invention.
  • FIG. 3C illustrates the multi-layer components of an elongated solar cell in accordance with an embodiment of the present invention.
  • FIG. 3D illustrates a transparent tubular casing, in accordance with an embodiment of the present invention.
  • FIG. 4A is a cross-sectional view of elongated solar cells in tubular casing that are electrically arranged in series and geometrically arranged in a parallel or near parallel manner, in accordance with an embodiment of the present invention.
  • FIG. 4B is a cross-sectional view taken about line 4 B- 4 B of FIG. 4A depicting the serial electrical arrangement of solar cells in an assembly, in accordance with an embodiment of the present invention.
  • FIG. 4C is a blow-up perspective view of region 4 C of FIG. 4B , illustrating various layers in elongated solar cells, in accordance with one embodiment of the present invention.
  • FIG. 4D is a cross-sectional view of an elongated solar cell taken about line 4 D- 4 D of FIG. 4B , in accordance with an embodiment of the present invention.
  • FIGS. 5A-5D illustrate semiconductor junctions that are used in various elongated solar cells in various embodiments of the present invention.
  • FIG. 6A illustrates an extrusion blow molding method, in accordance with the prior art.
  • FIG. 6B illustrates an injection blow molding method, in accordance with the prior art.
  • FIG. 6C illustrates a stretch blow molding method, in accordance with the prior art.
  • FIG. 7A is a cross-sectional view of elongated solar cells electrically arranged in series in an assembly where counter-electrodes abut individual solar cells, in accordance with another embodiment of the present invention.
  • FIG. 7B is a cross-sectional view taken about line 7 B- 7 B of FIG. 7A that depicts the serial arrangement of the cylindrical solar cells in an assembly, in accordance with an embodiment of the present invention.
  • FIG. 7C is a perspective view an array of alternating tubular casings, in accordance with an embodiment of the present invention.
  • FIG. 8 is a cross-sectional view of elongated solar cells electrically arranged in series in an assembly where counter-electrodes abut individual solar cells and the outer TCO is cut, in accordance with another embodiment of the present invention.
  • FIG. 9 is a cross-sectional view of elongated solar cells electrically arranged in series in an assembly in which the inner metal electrode is hollowed, in accordance with an embodiment of the present invention.
  • FIG. 10 is a cross-sectional view of elongated solar cells electrically arranged in series in an assembly in which a groove pierces the counter-electrodes, transparent conducting oxide layer, and junction layers of the solar cells, in accordance with an embodiment of the present invention.
  • FIG. 11 illustrates a static concentrator for use in some embodiments of the present invention.
  • FIG. 12 illustrates a static concentrator used in some embodiments of the present invention.
  • FIG. 13 illustrates a cross-sectional view of a solar cell in accordance with an embodiment of the present invention.
  • FIG. 14 illustrate molded tubular casing in accordance with some embodiments of the present invention.
  • FIG. 15 illustrates a perspective view of an elongated solar cell architecture with protruding electrode attachments, in accordance with an embodiment of the present invention.
  • FIG. 16 illustrates a perspective view of a solar cell architecture in accordance with an embodiment of the present invention.
  • FIG. 17A illustrates light reflection on a specular surface, in accordance with the prior art.
  • FIG. 17B illustrates light reflection on a diffuse surface, in accordance with the prior art.
  • FIG. 17C illustrates light reflection on a Lambertian surface, in accordance with the prior art.
  • FIG. 18A illustrates a circle and an involute of the circle, in accordance with the prior art
  • FIG. 18B illustrates a cross-sectional view of a solar cell architecture in accordance with an embodiment of the present invention.
  • FIG. 19 illustrates a cross-sectional view of an array of alternating tubular casings and internal reflectors, in accordance with an embodiment of the present invention.
  • FIG. 20A illustrates a suction loading assembly method in accordance with the present invention.
  • FIG. 20B illustrates a pressure loading assembly method in accordance with the present invention.
  • FIG. 20C illustrates a pour-and-slide loading assembly method in accordance with the present invention.
  • FIG. 21 illustrates a partial cross-sectional view of an elongated solar cell in a transparent tubular casing, in accordance with an embodiment of the present invention.
  • FIG. 22 illustrates Q-type silicone, silsequioxane, D-type silicon, and M-type silicon, in accordance with the prior art.
  • the solar cells of the present invention have an elongated cylindrical shape.
  • the present invention provides individually circumferentially covered cylindrical solar cell units 300 that are illustrated in perspective view in FIG. 3A and cross-sectional view in FIG. 3B .
  • a solar cell unit 300 an elongated cylindrical solar cell 402 ( FIG. 3C ) is circumferentially covered by a transparent tubular casing 310 ( FIG. 3D ).
  • solar cell unit 300 comprises a solar cell 402 coated with a transparent tubular casing 310 .
  • only one end of elongated solar cell 402 is exposed by transparent tubular casing 310 in order to form an electrical connection with adjacent solar cells 402 or other circuitry.
  • both ends of elongated solar cell 402 are exposed by transparent tubular casing 310 in order to form an electrical connection with adjacent solar cells 402 or other circuitry.
  • cylindrical means objects having a cylindrical or approximately cylindrical shape. In fact, cylindrical objects can have irregular shapes so long as the object, taken as a whole, is roughly cylindrical. Such cylindrical shapes can be solid (e.g., a rod) or hollowed (e.g., a tube).
  • tubular means objects having a tubular or approximately tubular shape. In fact, tubular objects can have irregular shapes so long as the object, taken as a whole, is roughly tubular.
  • exemplary solar cells 402 are provided in this section as well as Sections 5.2 through 5.8. For instance, examples of semiconductor junctions that can be used in solar cells 402 are discussed in Section 5.2. Exemplary systems and methods for manufacturing transparent tubular casing 310 are described in Section 5.1.2. Systems and methods for coating solar cells 402 with transparent tubular casing 310 in order to form solar cell units 300 are found in Section 5.1.3. Solar cell units 300 can be assembled into solar cell assemblies of various sizes and shapes to generate electricity and potentially heat water or other fluids.
  • FIG. 3B illustrates the cross-sectional view of an exemplary embodiment of solar cell unit 300 .
  • Other exemplary embodiments of solar cells e.g., 402 in FIG. 4A
  • Substrate 403 serves as a substrate for solar cell 402 .
  • substrate 403 is made of a plastic, metal, metal alloy, or glass.
  • Substrate 403 is cylindrical shaped.
  • substrate 403 has a hollow core, as illustrated in FIG. 3B .
  • substrate 403 has a solid core.
  • the shape of substrate 403 is only approximately that of a cylindrical object, meaning that a cross-section taken at a right angle to the long axis of substrate 403 defines an ellipse rather than a circle. As the term is used herein, such approximately shaped objects are still considered cylindrically shaped in the present invention.
  • substrate 403 is made of a urethane polymer, an acrylic polymer, a fluoropolymer, polybenzamidazole, polyimide, polytetrafluoroethylene, polyetheretherketone, polyamide-imide, glass-based phenolic, polystyrene, cross-linked polystyrene, polyester, polycarbonate, polyethylene, polyethylene, acrylonitrile-butadiene-styrene, polytetrafluoro-ethylene, polymethacrylate, nylon 6,6, cellulose acetate butyrate, cellulose acetate, rigid vinyl, plasticized vinyl, or polypropylene.
  • a urethane polymer an acrylic polymer, a fluoropolymer, polybenzamidazole, polyimide, polytetrafluoroethylene, polyetheretherketone, polyamide-imide, glass-based phenolic, polystyrene, cross-linked polystyrene, polyester, polycarbonate, polyethylene, polyethylene,
  • substrate 403 is made of aluminosilicate glass, borosilicate glass (e.g., Pyrex, Duran, Simax, etc.), dichroic glass, germanium/semiconductor glass, glass ceramic, silicate/fused silica glass, soda lime glass, quartz glass, chalcogenide/sulphide glass, fluoride glass, pyrex glass, a glass-based phenolic, cereated glass, or flint glass.
  • substrate 403 is a solid cylindrical shape. Such solid cylindrical substrates 403 can be made out of a plastic, glass, metal, or metal alloy.
  • Back-electrode 404 A back-electrode 404 is circumferentially disposed on substrate 403 . Back-electrode 404 serves as the first electrode in the assembly. In general, back-electrode 404 is made out of any material such that it can support the photovoltaic current generated by solar cell unit 300 with negligible resistive losses. In some embodiments, back-electrode 404 is composed of any conductive material, such as aluminum, molybdenum, tungsten, vanadium, rhodium, niobium, chromium, tantalum, titanium, steel, nickel, platinum, silver, gold, an alloy thereof, or any combination thereof.
  • conductive material such as aluminum, molybdenum, tungsten, vanadium, rhodium, niobium, chromium, tantalum, titanium, steel, nickel, platinum, silver, gold, an alloy thereof, or any combination thereof.
  • back-electrode 404 is composed of any conductive material, such as indium tin oxide, titanium nitride, tin oxide, fluorine doped tin oxide, doped zinc oxide, aluminum doped zinc oxide, gallium doped zinc oxide, boron dope zinc oxide indium-zinc oxide, a metal-carbon black-filled oxide, a graphite-carbon black-filled oxide, a carbon black-carbon black-filled oxide, a superconductive carbon black-filled oxide, an epoxy, a conductive glass, or a conductive plastic.
  • a conductive plastic is one that, through compounding techniques, contains conductive fillers which, in turn, impart their conductive properties to the plastic.
  • the conductive plastics used in the present invention to form back-electrode 404 contain fillers that form sufficient conductive current-carrying paths through the plastic matrix to support the photovoltaic current generated by solar cell unit 300 with negligible resistive losses.
  • the plastic matrix of the conductive plastic is typically insulating, but the composite produced exhibits the conductive properties of the filler.
  • Semiconductor junction 410 is formed around back-electrode 404 .
  • Semiconductor junction 410 is any photovoltaic homojunction, heterojunction, heteroface junction, buried homojunction, a p-i-n junction or a tandem junction having an absorber layer that is a direct band-gap absorber (e.g., crystalline silicon) or an indirect band-gap absorber (e.g., amorphous silicon).
  • a direct band-gap absorber e.g., crystalline silicon
  • an indirect band-gap absorber e.g., amorphous silicon
  • junctions 410 are described in Chapter 1 of Bube, Photovoltaic Materials, 1998, Imperial College Press, London, as well as Lugue and Hegedus, 2003 , Handbook of Photovoltaic Science and Engineering , John Wiley & Sons, Ltd., West Wales, England, each of which is hereby incorporated by reference herein in its entirety. Details of exemplary types of semiconductors junctions 410 in accordance with the present invention are disclosed in Section 5.2, below. In addition to the exemplary junctions disclosed in Section 5.2, below, junctions 410 can be multijunctions in which light traverses into the core of junction 410 through multiple junctions that, preferably, have successfully smaller band gaps.
  • semiconductor junction 410 include a copper-indium-gallium-diselenide (CIGS) absorber layer.
  • CGS copper-indium-gallium-diselenide
  • Optional intrinsic layer 415 there is a thin intrinsic layer (i-layer) 415 circumferentially coating semiconductor junction 410 .
  • the i-layer 415 can be formed using any undoped transparent oxide including, but not limited to, zinc oxide, metal oxide, or any transparent material that is highly insulating. In some embodiments, i-layer 415 is highly pure zinc oxide.
  • Transparent conductive layer 412 is circumferentially disposed on the semiconductor junction layers 410 thereby completing the circuit.
  • a thin i-layer 415 is circumferentially disposed on semiconductor junction 410 .
  • transparent conductive layer 412 is circumferentially disposed on i-layer 415 .
  • transparent conductive layer 412 is made of tin oxide SnO x (with or without fluorine doping), indium-tin oxide (ITO), doped zinc oxide (e.g., aluminum doped zinc oxide, gallium doped zinc oxide, boron dope zinc oxide), indium-zinc oxide or any combination thereof.
  • transparent conductive layer 412 is either p-doped or n-doped.
  • transparent conductive layer is made of carbon nanotubes. Carbon nanotubes are commercially available, for example from Eikos (Franklin, Mass.) and are described in U.S. Pat. No. 6,988,925, which is hereby incorporated by reference herein in its entirety.
  • transparent conductive layer 412 can be p-doped.
  • transparent conductive layer 412 can be n-doped.
  • transparent conductive layer 412 is preferably made of a material that has very low resistance, suitable optical transmission properties (e.g., greater than 90%), and a deposition temperature that will not damage underlying layers of semiconductor junction 410 and/or optional i-layer 415 .
  • transparent conductive layer 412 is an electrically conductive polymer material such as a conductive polytiophene, a conductive polyaniline, a conductive polypyrrole, a PSS-doped PEDOT (e.g., Bayrton), or a derivative of any of the foregoing.
  • transparent conductive layer 412 comprises more than one layer, including a first layer comprising tin oxide SnO x (with or without fluorine doping), indium-tin oxide (ITO), indium-zinc oxide, doped zinc oxide (e.g., aluminum doped zinc oxide, gallium doped zinc oxide, boron dope zinc oxide) or a combination thereof and a second layer comprising a conductive polytiophene, a conductive polyaniline, a conductive polypyrrole, a PSS-doped PEDOT (e.g., Bayrton), or a derivative of any of the foregoing.
  • a first layer comprising tin oxide SnO x (with or without fluorine doping), indium-tin oxide (ITO), indium-zinc oxide, doped zinc oxide (e.g., aluminum doped zinc oxide, gallium doped zinc oxide, boron dope zinc oxide) or a combination thereof
  • a second layer comprising a conductive polytiophen
  • electrode strips 420 are disposed on transparent conductive layer 412 in order to facilitate electrical current flow.
  • electrode strips 420 are thin strips of electrically conducting material that run lengthwise along the long axis (cylindrical axis) of the cylindrically shaped solar cell, as depicted in FIG. 4A .
  • optional electrode strips are positioned at spaced intervals on the surface of transparent conductive layer 412 . For instance, FIG. 3B , electrode strips 420 run parallel to each other and are spaced out at ninety degree intervals along the cylindrical axis of the solar cell.
  • electrode strips 420 are spaced out at five degree, ten degree, fifteen degree, twenty degree, thirty degree, forty degree, fifty degree, sixty degree, ninety degree or 180 degree intervals on the surface of transparent conductive layer 412 . In some embodiments, there is a single electrode strip 420 on the surface of transparent conductive layer 412 . In some embodiments, there is no electrode strip 420 on the surface of transparent conductive layer 412 . In some embodiments, there is two, three, four, five, six, seven, eight, nine, ten, eleven, twelve, fifteen or more, or thirty or more electrode strips on transparent conductive layer 412 , all running parallel, or near parallel, to each down the long (cylindrical) axis of the solar cell.
  • electrode strips 420 are evenly spaced about the circumference of transparent conductive layer 412 , for example, as depicted in FIG. 3B . In alternative embodiments, electrode strips 420 are not evenly spaced about the circumference of transparent conductive layer 412 . In some embodiments, electrode strips 420 are only on one face of the solar cell. Elements 403 , 404 , 410 , 415 (optional), and 412 of FIG. 3B collectively comprise solar cell 402 of FIG. 3A . In some embodiments, electrode strips 420 are made of conductive epoxy, conductive ink, copper or an alloy thereof, aluminum or an alloy thereof, nickel or an alloy thereof, silver or an alloy thereof, gold or an alloy thereof, a conductive glue, or a conductive plastic.
  • Electrodes strips that run along the long (cylindrical) axis of the solar cell and these electrode strips are interconnected to each other by grid lines.
  • These grid lines can be thicker than, thinner than, or the same width as the electrode strips.
  • These grid lines can be made of the same or different electrically material as the electrode strips.
  • electrode strips 420 are deposited on transparent conductive layer 412 using ink jet printing.
  • conductive ink that can be used for such strips include, but are not limited to silver loaded or nickel loaded conductive ink.
  • epoxies as well as anisotropic conductive adhesives can be used to construct electrode strips 420 .
  • such inks or epoxies are thermally cured in order to form electrode strips 420 .
  • Optional filler layer 330 is optional filler layer 330 .
  • the addition of counter-electrode strips or leads 420 often renders the shape of the circular solar cells irregular. Care is taken to exclude air from the solar cell unit to avoid oxidation. Accordingly, in some embodiments of the present invention, as depicted in FIG.
  • a filler layer 330 of sealant such as ethyl vinyl acetate (EVA), silicone, silicone gel, epoxy, polydimethyl siloxane (PDMS), RTV silicone rubber, polyvinyl butyral (PVB), thermoplastic polyurethane (TPU), a polycarbonate, an acrylic, a fluoropolymer, and/or a urethane is coated over transparent conductive layer 412 to seal out air and, optionally, to provide complementary fitting to a transparent tubular casing 310 .
  • sealant such as ethyl vinyl acetate (EVA), silicone, silicone gel, epoxy, polydimethyl siloxane (PDMS), RTV silicone rubber, polyvinyl butyral (PVB), thermoplastic polyurethane (TPU), a polycarbonate, an acrylic, a fluoropolymer, and/or a urethane is coated over transparent conductive layer 412 to seal out air and, optionally, to provide complementary fitting to a transparent tubular casing 310
  • Transparent tubular casing 310 is circumferentially disposed on transparent conductive layer 412 and/or optional filler layer 330 .
  • tubular casing 310 is made of plastic or glass.
  • elongated solar cells 402 after being properly modified for future packaging as described below, are sealed in the transparent tubular casing 310 .
  • transparent tubular casing 310 fits over the outermost layer of elongated solar cell 402 .
  • elongated solar cell 402 is inside transparent tubular casing 310 such that adjacent elongated solar cells 402 do not form electric contact with each other except at the ends of the solar cells.
  • transparent tubular casing 310 can be used to construct transparent tubular casing 310 such they exclude oxygen and water from the system as well as to provide complementary fitting to the underlying solar cell 402 .
  • transparent tubular casing 310 for example as depicted in FIG. 14 , can be used to cover elongated solar cells 402 .
  • transparent tubular casing 310 is made of a urethane polymer, an acrylic polymer, polymethylmethacrylate (PMMA), a fluoropolymer, silicone, poly-dimethyl siloxane (PDMS), silicone gel, epoxy, ethyl vinyl acetate (EVA), perfluoroalkoxy fluorocarbon (PFA), nylon/polyamide, cross-linked polyethylene (PEX), polyolefin, polypropylene (PP), polyethylene terephtalate glycol (PETG), polytetrafluoroethylene (PTFE), thermoplastic copolymer (for example, ETFE®, which is a derived from the polymerization of ethylene and tetrafluoroethylene: TEFLON® monomers), polyurethane/urethane, polyvinyl chloride (PVC), polyvinylidene fluoride (PVDF), Tygon®, vinyl, Viton®, or any combination or variation thereof. Additional suitable materials for optional filler layer
  • transparent tubular casing 310 comprises a plurality of transparent tubular casing layers.
  • each transparent tubular casing is composed of a different material.
  • transparent tubular casing 310 comprises a first transparent tubular casing layer and a second transparent tubular casing layer.
  • the first transparent tubular casing layer is disposed on the transparent conductive layer 412 , optional filler layer 330 or the water resistant layer.
  • the second transparent tubular casing layer is disposed on the first transparent tubular casing layer.
  • each transparent tubular casing layer has different properties.
  • the outer transparent tubular casing layer has excellent UV shielding properties whereas the inner transparent tubular casing layer has good water proofing characteristics.
  • the use of multiple transparent tubular casing layers can be used to reduce costs and/or improve the overall properties of transparent tubular casing 310 .
  • one transparent tubular casing layer may be made of an expensive material that has a desired physical property.
  • the thickness of the expensive transparent tubular casing layer may be reduced, thereby achieving a savings in material costs.
  • one transparent tubular casing layer may have excellent optical properties (e.g., index of refraction, etc.) but be very heavy. By using one or more additional transparent tubular casing layers, the thickness of the heavy transparent tubular casing layer may be reduced, thereby reducing the overall weight of transparent tubular casing 310 .
  • Optional water resistant layer In some embodiments, one or more layers of water resistant layer are coated over solar cell 402 to prevent the damaging effects of water molecules. In some embodiments, this water resistant layer is circumferentially coated onto transparent conductive layer 412 prior to depositing optional filler layer 330 and encasing the solar cell 402 in transparent tubular casing 310 . In some embodiments, such water resistant layers are circumferentially coated onto optional filler layer 330 prior to encasing the solar cell 402 in transparent tubular casing 310 . In some embodiments, such water resistant layers are circumferentially coated onto transparent tubular casing 310 itself.
  • this water resistant layer is made of clear silicone, SiN, SiO x N y , SiO x , or Al 2 O 3 , where x and y are integers.
  • water resistant layer is made of a Q-type silicone, a silsequioxane, a D-type silicon, or an M-type silicon.
  • an optional antireflective coating is also circumferentially disposed on transparent tubular casing 310 to maximize solar cell efficiency.
  • a single layer serves the dual purpose of a water resistant layer and an anti-reflective coating.
  • antireflective coating made of MgF 2 , silicone nitrate, titanium nitrate, silicon monoxide (SiO), or silicon oxide nitrite.
  • there is more than one layer of antireflective coating there is more than one layer of antireflective coating.
  • there is more than one layer of antireflective coating and each layer is made of the same material.
  • there is more than one layer of antireflective coating and each layer is made of a different material.
  • some of the layers of multi-layered solar cells 402 are constructed using cylindrical magnetron sputtering techniques. In some embodiments, some of the layers of multi-layered solar cells 402 are constructed using conventional sputtering methods or reactive sputtering methods on long tubes or strips. Sputtering coating methods for long tubes and strips are disclosed in for example, Hoshi et al., 1983, “Thin Film Coating Techniques on Wires and Inner Walls of Small Tubes via Cylindrical Magnetron Sputtering,” Electrical Engineering in Japan 103:73-80; Lincoln and Magnoliaensderfer, 1980, “Adapting Conventional Sputtering Equipment for Coating Long Tubes and Strips,” J. Vac. Sci. Technol.
  • a fluorescent material (e.g., luminescent material, phosphorescent material) is coated on a surface of a layer of solar cell 300 .
  • the fluorescent material is coated on the luminal surface and/or the exterior surface of transparent tubular casing 310 .
  • the fluorescent material is coated on the outside surface of transparent conductive oxide 412 .
  • solar cell 300 includes an optional filler layer 300 and the fluorescent material is coated on the optional filler layer.
  • solar cell 300 includes a water resistant layer and the fluorescent material is coated on the water resistant layer. In some embodiments, more than one surface of a solar cell 300 is coated with optional fluorescent material.
  • the fluorescent material absorbs blue and/or ultraviolet light, which some semiconductor junctions 410 of the present invention do not use to convert to electricity, and the fluorescent material emits light in visible and/or infrared light which is useful for electrical generation in some solar cells 300 of the present invention.
  • Fluorescent, luminescent, or phosphorescent materials can absorb light in the blue or UV range and emit visible light.
  • Phosphorescent materials, or phosphors usually comprise a suitable host material and an activator material.
  • the host materials are typically oxides, sulfides, selenides, halides or silicates of zinc, cadmium, manganese, aluminum, silicon, or various rare earth metals.
  • the activators are added to prolong the emission time.
  • phosphorescent materials are incorporated in the systems and methods of the present invention to enhance light absorption by solar cell 300 .
  • the phosphorescent material is directly added to the material used to make optional transparent tubular casing 310 .
  • the phosphorescent materials are mixed with a binder for use as transparent paints to coat various outer or inner layers of solar cell 300 , as described above.
  • Exemplary phosphors include, but are not limited to, copper-activated zinc sulfide (ZnS:Cu) and silver-activated zinc sulfide (ZnS:Ag).
  • Other exemplary phosphorescent materials include, but are not limited to, zinc sulfide and cadmium sulfide (ZnS:CdS), strontium aluminate activated by europium (SrAlO 3 :Eu), strontium titanium activated by praseodymium and aluminum (SrTiO3:Pr, Al), calcium sulfide with strontium sulfide with bismuth ((Ca,Sr)S:Bi), copper and magnesium activated zinc sulfide (ZnS:Cu,Mg), or any combination thereof.
  • optical brighteners are used in the optional fluorescent layers of the present invention.
  • Optical brighteners also known as optical brightening agents, fluorescent brightening agents or fluorescent whitening agents
  • Optical brighteners are dyes that absorb light in the ultraviolet and violet region of the electromagnetic spectrum, and re-emit light in the blue region.
  • Such compounds include stilbenes (e.g., trans-1,2-diphenylethylene or (E)-1,2-diphenylethene).
  • Another exemplary optical brightener that can be used in the optional fluorescent layers of the present invention is umbelliferone (7-hydroxycoumarin), which also absorbs energy in the UV portion of the spectrum. This energy is then re-emitted in the blue portion of the visible spectrum.
  • Circumferentially disposed In the present invention, layers of material are successively circumferentially disposed on a cylindrical substrate 403 in order to form a solar cell.
  • the term circumferentially disposed is not intended to imply that each such layer of material is necessarily deposited on an underlying layer. In fact, the present invention teaches methods by which such layers are molded or otherwise formed on an underlying layer. Nevertheless, the term circumferentially disposed means that an overlying layer is disposed on an underlying layer such that there is no annular space between the overlying layer and the underlying layer. Furthermore, as used herein, the term circumferentially disposed means that an overlying layer is disposed on at least fifty percent of the perimeter of the underlying layer. Furthermore, as used herein, the term circumferentially disposed means that an overlying layer is disposed along at least half of the length of the underlying layer.
  • circumferentially sealed is not intended to imply that an overlying layer or structure is necessarily deposited on an underlying layer or structure. In fact, the present invention teaches methods by which such layers or structures (e.g., transparent tubular casing 310 ) are molded or otherwise formed on an underlying layer or structure. Nevertheless, the term circumferentially sealed means that an overlying layer or structure is disposed on an underlying layer or structure such that there is no annular space between the overlying layer or structure and the underlying layer or structure. Furthermore, as used herein, the term circumferentially sealed means that an overlying layer is disposed on the full perimeter of the underlying layer.
  • a layer or structure circumferentially seals an underlying layer or structure when it is circumferentially disposed around the full perimeter of the underlying layer or structure and along the full length of the underlying layer or structure.
  • the present invention contemplates embodiments in which a circumferentially sealing layer or structure does not extend along the full length of an underlying layer or structure.
  • FIG. 4A illustrates a cross-sectional view of the arrangement of three solar cell units 300 arranged in a coplanar fashion in order to form a solar cell assembly 400 .
  • FIG. 4B provides a cross-sectional view with respect to line 4 B- 4 B of FIG. 4A .
  • back-electrode 404 is depicted as a solid cylindrical substrate.
  • back-electrode is a thin layer of electrically conducting material circumferentially disposed on substrate 403 as depicted in FIG. 3B . All other layers in FIG. 4 are as illustrated in FIG. 3B .
  • optional filler layer 330 in the embodiments depicted in FIG. 4 is optional.
  • each elongated cell 402 has a length that is great compared to the diameter d of its cross-section.
  • An advantage of the architecture shown in FIG. 4A is that there is no front side contact that shades solar cells 402 . Such a front side contact is found in known devices (e.g., elements 10 of FIG. 2B ).
  • Another advantage of the architecture shown in FIG. 4A is that elongated cells 402 are electrically connected in series rather than in parallel. In such a series configuration, the voltage of each elongated cell 402 is summed. This serves to increase the voltage across the system, thereby keeping the current down, relative to comparable parallel architectures, and minimizes resistive losses.
  • a serial electrical arrangement is maintained by arranging all or a portion of the elongated solar cells 402 as illustrated in FIGS. 4A and 4B .
  • Another advantage of the architecture shown in FIG. 4A is that the resistance loss across the system is low. This is because each electrode component of the circuit is made of highly conductive material.
  • conductive core 404 of each solar cell 402 is made of a conductive material such as metal.
  • the back-electrode layer 404 is highly conductive. Regardless of whether back-electrode 404 is in a solid configuration as depicted in FIG.
  • conductive core 404 ( FIG. 4 ) and/or thicker back-electrode 404 ( FIG. 3B ) ensure low resistance, transparent conductive layers encompassing such larger conductive cores 404 must carry current further to contacts (counter-electrode strips or leads) 420 .
  • diameter d is between 0.5 millimeters (mm) and 20 mm in some embodiments of the present invention.
  • counter-electrode strips 420 are composed of a conductive epoxy (e.g., silver epoxy) or conductive ink and the like.
  • counter-electrode strips 420 are formed by depositing a thin metallic layer on a suitable substrate and then patterning the layer into a series of parallel strips. Each counter-electrode strip 420 is affixed to a solar cell 402 with a conductive epoxy along the length of a solar cell 402 , as shown in FIG. 4D .
  • counter-electrode strips 420 are formed directly on solar cells 402 . In other embodiments, counter-electrode strips 420 are formed on the outer transparent conductive layer 412 , as illustrated in FIG. 3B . In some embodiments, connections between counter-electrode strip 420 to electrodes 433 are established in series as depicted in FIG. 4B .
  • Still another advantage of the architecture illustrated in FIG. 4A is that the path length through the absorber layer (e.g., layer 502 , 510 , 520 , or 540 of FIG. 5 ) of semiconductor junction 410 is, on average, longer than the path length through of the same type of absorber layer having the same width but in a planar configuration.
  • the elongated architecture illustrated in FIG. 4A allows for the design of thinner absorption layers relative to analogous planar solar cell counterparts.
  • the thinner absorption layer absorbs the light because of the increased path length through the layer. Because the absorption layer is thinner relative to comparable planar solar cells, there is less resistance and, hence, an overall increase in efficiency in the cell relative to analogous planar solar cells. Additional advantages of having a thinner absorption layer that still absorbs sufficient amounts of light is that such absorption layers require less material and are thus cheaper. Furthermore, thinner absorption layers are faster to make, thereby further lowering production costs.
  • elongated solar cells 402 illustrated in FIG. 4A have a relatively small surface area, relative to comparable planar solar cells, and they possess radial symmetry. Each of these properties allow for the controlled deposition of doped semiconductor layers necessary to form semiconductor junction 410 .
  • the smaller surface area, relative to conventional flat panel solar cells, means that it is easier to present a uniform vapor across the surface during deposition of the layers that form semiconductor junction 410 .
  • the radial symmetry can be exploited during the manufacture of the cells in order to ensure uniform composition (e.g., uniform material composition, uniform dopant concentration, etc.) and/or uniform thickness of individual layers of semiconductor junction 410 .
  • the conductive core 404 upon which layers are deposited to make solar cells 402 can be rotated along its longitudinal axis during such deposition in order to ensure uniform material composition and/or uniform thickness.
  • the cross-sectional shape of solar cells 402 is generally circular in FIG. 4B .
  • solar cell 402 bodies with a quadrilateral cross-section or an elliptical shaped cross-section and the like are used.
  • there is no limit on the cross-sectional shape of solar cells 402 in the present invention so long as the solar cells 402 maintain a general overall rod-like shape in which their length is much larger than their diameter and they possess some form of cross-sectional radial symmetry or approximate cross-sectional radial symmetry.
  • a first and second elongated solar cell (rod-shaped solar cell) 402 are electrically connected in series by an electrical contact 433 that connects the back-electrode 404 (first electrode) of the first elongated solar cell 402 to the corresponding counter-electrode strip 420 of the second elongated solar cell 402 .
  • elongated solar cells 402 are the basic unit that respectively forms the semiconductor layer 410 , the transparent conductive layer 412 , and the metal conductive core 404 of the elongated solar cell 402 .
  • the elongated solar cells 402 are multiply arranged in a row parallel or nearly parallel with respect to each other and rest upon independent leads (counter-electrodes) 420 that are electrically isolated from each other.
  • elongated solar cells 402 can receive direct light through transparent tubular casing 310 .
  • not all elongated solar cells 402 in assembly 400 are electrically arranged in series.
  • a first and second elongated solar cell can be electrically connected in parallel, and are thereby paired, by using a first electrical contact (e.g., an electrically conducting wire, etc., not shown) that joins the conductive core 404 of a first elongated solar cell to the second elongated solar cell.
  • transparent conductive 412 of the first elongated solar cell 402 is electrically connected to transparent conductive layer 412 of the second elongated solar cell 402 either by contacting the transparent conductive layers of the two elongated solar cells either directly or through a second electrical contact (not shown).
  • the pairs of elongated solar cells are then electrically arranged in series.
  • three, four, five, six, seven, eight, nine, ten, eleven or more elongated solar cells 402 are electrically arranged in parallel. These parallel groups of elongated solar cells 402 are then electrically arranged in series.
  • FIG. 4C is an enlargement of region 4 C of FIG. 4B in which a portion of back-electrode 404 and transparent conductive layer 412 have been cut away to illustrate the positional relationship between counter-electrode strip 420 , electrode 433 , back-electrode 404 , semiconductor layer 410 , and transparent conductive layer 412 . Furthermore, FIG. 4C illustrates how electrical contact 433 joins back-electrode 404 of one elongated solar cell 402 to counter-electrode 420 of another solar cell 402 .
  • FIG. 4 is a cross-sectional view of an elongated solar 402 cell taken about line 4 D- 4 D of FIG. 4B , it is possible to completely seal far-end 455 of solar cell 402 with transparent tubular casing 310 in the manner illustrated.
  • the layers in this seal are identical to the layers circumferentially disposed lengthwise on conductive core 404 , namely, in order of deposition on conductive core 404 and/or substrate 403 , semiconductor junction 410 , optional thin intrinsic layer (i-layer) 415 , and transparent conductive layer 412 .
  • end 455 can receive sunlight and therefore contribute to the electrical generating properties of the solar cell 402 .
  • transparent tubular casing 310 open at both ends of solar cell 402 such that electrical contacts can be extended from either end of the solar cell.
  • FIG. 4D also illustrates how, in some embodiments, the various layers deposited on conductive core 404 are tapered at end 466 where electrical contacts 433 are found.
  • a terminal portion of back-electrode 404 is exposed, as illustrated in FIG. 4D .
  • semiconductor junction 410 , optional i-layer 415 , and transparent conductive layer 412 are stripped away from a terminal portion of conductive core 404 .
  • a terminal portion of semiconductor junction 410 is exposed as illustrated in FIG. 4D . That is, optional i-layer 415 and transparent conductive layer 412 are stripped away from a terminal portion of semiconductor junction 410 .
  • elongated solar cell 402 is positioned on counter-electrode strip 420 which, in turn, is positioned against electrically resistant transparent tubular casing 310 .
  • counter-electrode strip 420 make contact with electrically resistant transparent tubular casing 310 .
  • elongated solar cells 402 and their corresponding counter-electrode strips 420 are sealed within transparent conductive layer 412 such that there is no unfavorable electrical contact.
  • elongated solar cells 402 and corresponding electrode strips 420 are fixedly held in place by a sealant such as ethyl vinyl acetate or silicone.
  • counter-electrode strips 420 are replaced with metal wires that are attached to the sides of solar cell 402 .
  • solar cells 402 implement a segmented design to eliminate the requirement of additional wire- or strip-like counter-electrodes.
  • FIG. 4D further provides a perspective view of electrical contacts 433 that serially connect elongated solar cells 402 .
  • a first electrical contact 433 - 1 electrically interfaces with counter-electrode 420
  • a second electrical contact 433 - 2 electrically interfaces with back-electrode 404 (the first electrode of elongated solar cell 402 ).
  • First electrical contact 433 - 1 serially connects the counter-electrode of elongated solar cell 402 to the back-electrode 404 of another elongated solar cell.
  • Second electrical contact 433 - 2 serially connects the back-electrode 404 of elongated solar cell 402 to the counter-electrode 420 of another elongated solar cell 402 , as shown in FIG. 4B .
  • Such an electrical configuration is possible regardless of whether back-electrode 404 is itself a solid cylindrical substrate or is a layer of electrically conducting material on a substrate 403 as depicted in FIG. 3B .
  • Each solar cell 402 is coated by a transparent tubular casing 310 .
  • FIG. 4D provides an encapsulated solar cell 402 where an optional filler layer 330 and a transparent tubular casing 310 cover the solar cell, leaving only one end 466 to establish electrical contracts.
  • the optional filler layer 330 and transparent tubular casing 310 are configured such that both ends (e.g., 455 and 466 in FIG. 4D ) of the elongated solar cell 402 are available to establish electrical contacts.
  • FIG. 7A illustrates a solar cell assembly 700 in accordance with another embodiment of the present invention.
  • Solar cell assembly 700 comprises a plurality of elongated solar cells 402 , each encapsulated in transparent tubular casing 310 .
  • Each elongated solar cell 402 in the plurality of elongated solar cells has a back-electrode 404 configured as a first electrode.
  • back electrode 404 is a solid cylindrical electrically conducting substrates.
  • back-electrode 404 is a thin film of electrically conducting material deposited on a hollowed tubular shaped substrate as in the case of FIG. 3B .
  • a semiconductor junction 410 is circumferentially disposed on the conductive core 402 and a transparent conductive layer 412 is circumferentially disposed on semiconductor junction 410 .
  • the plurality of elongated solar cells 402 are geometrically arranged in a parallel or a near parallel manner thereby forming a planar array having a first face (facing side 733 of assembly 700 ) and a second face (facing side 766 of assembly 700 ).
  • the plurality of elongated solar cells is arranged such that one or more elongated solar cells in the plurality of elongated solar cells do not contact adjacent elongated solar cells.
  • the plurality of elongated solar cells is arranged such that each of the elongated solar cells in the plurality of elongated solar cells does not directly contact (through transparent conductive layer 412 ) adjacent elongated solar cells 402 . In some embodiments, the plurality of elongated solar cells is arranged such that each of the elongated solar cells in the plurality of elongated solar cells does directly contact the outer transparent tubular casing 310 of adjacent elongated solar cells 402 .
  • first groove 777 - 1 and a second groove 777 - 2 that each runs lengthwise on opposing sides of solar cell 402 .
  • FIG. 7A some but not all grooves 777 are labeled.
  • the maximum length that current must travel in transparent conductive layer 412 before it reaches a counter-electrode 420 is a quarter of the circumference of the transparent conductive layer.
  • the maximum length that current must travel in transparent conductive layer 412 before it reaches a counter-electrode 420 is a full half of the circumference of the transparent conductive layer 412 .
  • the present invention encompasses grooves 777 that have a broad range of depths and shape characteristics and is by no means limited to the shape of the grooves 777 illustrated in FIG. 7A .
  • each groove 777 is patterned so that there is a tight fit between the contours of the groove 777 and the counter-electrode 420 .
  • each respective elongated solar cell 402 in the plurality of elongated solar cells is bound to at least a first corresponding metal counter-electrode 420 in the plurality of metal counter-electrodes such that the first metal counter-electrode lies in a groove 777 that runs lengthwise along the respective elongated solar cell.
  • each respective elongated solar cell 402 is bound to a second corresponding metal counter-electrode 420 such that the second metal counter-electrode lies in a second groove 777 that runs lengthwise along the respective elongated solar cell 402 .
  • the first groove 777 and the second groove 777 are on opposite or substantially opposite sides of the respective elongated solar cell 402 and run along the long axis of the cell.
  • transparent tubular casing 310 such as the transparent tubular casing 310 depicted in FIG. 14 , is used to encase elongated solar cells 402 .
  • an optional filler layer 330 is circumferentially disposed between solar cell 402 and transparent tubular casing 310 in the manner illustrated in FIG. 7A in some embodiments of the present invention.
  • filler layer 330 prevents the seepage of oxygen and water into solar cells 402 .
  • filler layer 330 comprises EVA or silicone.
  • the individually encased solar cells 402 are assembled into a planar array as depicted in FIG. 7A .
  • the plurality of elongated solar cells 402 are configured to receive direct light from both face 733 and face 766 of the planar array.
  • FIG. 7B provides a cross-sectional view with respect to line 7 B- 7 B of FIG. 7A .
  • Solar cells 402 are electrically connected to other in series by arranging the solar cells such that they do not touch each other, as illustrated in FIGS. 7A and 7B and by the use of electrical contacts as described below in conjunction with FIG. 7B .
  • the individual solar cells are shown separate from each other to reveal the encasing by transparent tubular casing 310 , no actual separation distance between solar cells 402 is required since transparent tubular casing 310 shields the individual solar cells 402 of solar cell unit 300 from any unfavorable electrical contacts.
  • tight space or no space packing is not a required for individually shielded solar cell unit 300 .
  • the presence of the transparent tubular casing 310 provides more versatility in the solar cell assembly.
  • the distance between adjacent solar cell units 300 is 0 microns or greater, 0.1 microns or greater, 0.5 microns or greater, or between 1 and 5 microns, or optimally correlated with the size and dimensions of the solar cell units 300 .
  • serial electrical contact between solar cells 402 is made by electrical contacts 788 that electrically connect the back-electrode 404 of one elongated solar cell 402 to the corresponding counter-electrodes 120 of a different solar cell 402 .
  • FIG. 7B further illustrates a cutaway of metal conductive core 404 and semiconductor junction 410 in one solar cell 402 to further illustrate the architecture of solar cells 402 .
  • the solar cell assembly illustrated in FIG. 7 has several advantages. First, the planar arrangement of the solar cells 402 leaves almost zero percent shading in the assembly. For instance, the assembly can receive direct sunlight from both face 733 and face 766 . Second, in embodiments where individually encapsulated solar cells 402 are aligned parallel to each other with no or little space separation, the structure is completely self-supporting. Still another advantage of the assembly is ease of manufacture. Unlike solar cells such as that depicted in FIG. 2B , no complicated grid or transparent conductive oxide on glass is required. For example, to assemble a solar cell 402 and its corresponding counter-electrodes 420 together to complete the circuit illustrated in FIG. 7A , counter-electrode 420 , when it is in the form of a wire, can be covered with conductive epoxy and dropped in the groove 777 of solar cell 402 and allowed to cure.
  • conductive core 404 , junction 410 , and transparent conductive layer 412 are flush with each other at end 789 of elongated solar cells 402 .
  • conductive core protrudes a bit with respect to junction 410 and transparent conductive layer 412 as illustrated.
  • Junction 410 also protrudes a bit at end 799 with respect to transparent conductive layer 412 .
  • the protrusion of conductive core 404 at end 799 means that the sides of a terminal portion of the conductive core 404 are exposed (e.g., not covered by junction 410 and transparent conductive layer 412 ).
  • this configuration is to reduce the chances of shorting counter-electrode 420 (or the epoxy used to mount the counter-electrode in groove 777 ) with transparent conductive layer 412 .
  • all or a portion of the exposed surface area of counter-electrodes 420 are shielded with an electrically insulating material in order to reduce the chances of electrical shortening.
  • the exposed surface area of counter-electrodes 420 in the boxed regions of FIG. 7B is shielded with an electrically insulating material.
  • counter-electrode 420 can have much higher conductivity without shadowing.
  • counter-electrode 420 can have a substantial cross-sectional size (e.g., 1 mm in diameter when solar cell 402 has a 6 mm diameter).
  • counter-electrode 420 can carry a significant amount of current so that the wires can be as long as possible, thus enabling the fabrication of larger panels.
  • the series connections between solar cells 402 can be between pairs of solar cells 402 in the manner depicted in FIG. 7B .
  • the invention is not so limited.
  • two or more solar cells 402 are grouped together (e.g., electrically connected in a parallel fashion) to form a group of solar cells and then such groups of solar cells are serially connected to each other. Therefore, the serial connections between solar cells can be between groups of solar cells where such groups have any number of solar cells 402 (e.g., 2, 3, 4, 5, 6, etc.).
  • FIG. 7B illustrates a preferred embodiment in which each contact 788 serially connects only a pair of solar cells 402 .
  • FIG. 7B Yet another advantage of the assembly illustrated in FIG. 7B is that transparent tubular casing 310 is circumferentially disposed on solar cells 402 .
  • an optional filler layer 330 lies between the outer surface of solar cell 402 and the inner surface of transparent tubular casing 310 .
  • FIG. 7B only depicts electrical circuitry at one end of adjacent solar cell units 300 , it is possible for electrical circuitry to be established at both ends of solar cell units 300 or between the two ends of solar cell units 300 .
  • each individual solar cell 402 is encapsulated by transparent tubular casing 310 .
  • transparent tubular casing 310 is at least partial transparent and made of non-conductive material such as plastics or glass. Accordingly, solar cell assemblies made according to the present design do not require insulator lengthwise between each solar cell 402 .
  • Yet another embodiment of solar cell assembly 700 is that there is no extra absorption loss from a transparent conductive layer or a metal grid on one side of the assembly. Further, assembly 700 has the same performance or absorber area exposed on both sides 733 and 766 . This makes assembly 700 symmetrical.
  • Still another advantage of assembly 700 is that all electrical contacts 788 end at the same level (e.g., in the plane of line 7 B- 7 B of FIG. 7A ). As such, they are easier to connect and weld with very little substrate area wasted at the end. This simplifies construction of the solar cells 402 while at the same time serves to increase the overall efficiency of solar cell assembly 700 . This increase in efficiency arises because the welds can be smaller.
  • Intrinsic layer 415 can be made of an undoped transparent oxide such as zinc oxide, metal oxide, or any transparent metal that is highly insulating.
  • the semiconductor junction 410 of solar cells 402 in assembly 700 comprise an inner coaxial layer and an outer coaxial layer where the outer coaxial layer comprises a first conductivity type and the inner coaxial layer comprises a second, opposite, conductivity type.
  • the inner coaxial layer comprises copper-indium-gallium-diselenide (CIGS) whereas the outer coaxial layer comprises In 2 Se 3 , In 2 S 3 , ZnS, ZnSe, CdlnS, CdZnS, ZnIn 2 Se 4 , Zn 1-x Mg x O, CdS, SnO 2 , ZnO, ZrO 2 , or doped ZnO.
  • conductive cores 404 in solar cells 402 are hollowed.
  • FIG. 8 illustrates a solar cell assembly 800 of the present invention that is identical to solar cell assembly 700 of the present invention with the exception that transparent conductive layer 412 is interrupted by breaks 810 that run along the long axis of solar cells 402 and cut completely through transparent conductive layer 412 .
  • transparent conductive layer 412 is interrupted by breaks 810 that run along the long axis of solar cells 402 and cut completely through transparent conductive layer 412 .
  • the effect of such breaks 810 is that they electrically isolate the two counter-electrodes 420 associated with each solar cell 402 in solar cell assembly 800 .
  • breaks 800 can be made. For example, a laser or an HCl etch can be used.
  • not all elongated solar cells 402 in assembly 800 are electrically arranged in series.
  • a first and second elongated solar cell can be electrically connected in parallel, and are thereby paired, by using a first electrical contact (e.g., an electrically conducting wire, etc., not shown) that joins the conductive core 404 of a first elongated solar cell to the second elongated solar cell.
  • transparent conductive layer 412 of the first elongated solar cell 402 is electrically connected to transparent conductive layer 412 of the second elongated solar cell 402 either by contacting the transparent conductive layers of the two elongated solar cells either directly or through a second electrical contact (not shown).
  • the pairs of elongated solar cells are then electrically arranged in series.
  • three, four, five, six, seven, eight, nine, ten, eleven or more elongated solar cells 402 are electrically arranged in parallel. These parallel groups of elongated solar cells 402 are then electrically arranged in series.
  • transparent tubular casing 310 is used to encase elongated solar cells 402 .
  • a filler layer 330 may be used to prevent oxidation of the solar cell 402 .
  • filler layer 330 (for example EVA) prevents seepage of oxygen and water into solar cells 402 .
  • Filler layer is disposed between solar cell 402 and the inner layer of transparent tubular casing 310 .
  • the individually encapsulated solar cells 402 are assembled into a planar array as depicted in FIG. 8 .
  • FIG. 9 illustrates a solar cell assembly 900 of the present invention in which back-electrodes 404 are hollowed.
  • back-electrode 404 can be hollowed in any of the embodiments of the present invention.
  • One advantage a hollowed back-electrode 404 design is that it reduces the overall weight of the solar cell assembly.
  • Back-electrode 404 is hollowed when there is a channel that extends lengthwise through all or a portion of back-electrode 404 .
  • back-electrode 404 is metal tubing.
  • back-electrode 404 is a thin layer of electrically conducting material, e.g. molybdenum, that is deposited on a substrate 403 as illustrated in FIG. 3B .
  • not all elongated solar cells 402 in assembly 900 are electrically arranged in series.
  • the pairs of elongated solar cells are then electrically arranged in series.
  • three, four, five, six, seven, eight, nine, ten, eleven or more elongated solar cells 402 are electrically arranged in parallel. These parallel groups of elongated solar cells 402 are then electrically arranged in series.
  • a transparent tubular casing 310 can be used to circumferentially cover elongated solar cells 402 . Because it is important to exclude air from the solar cell unit 402 , additional sealant may be used to prevent oxidation of the solar cell 402 .
  • an optional filler layer 330 (for example, EVA or silicone, etc.) may be used to prevent seepage of oxygen and water into solar cells 402 .
  • the individually encased solar cells 402 are assembled into a planar array as depicted in FIG. 9 .
  • FIG. 9 FIG.
  • FIG. 10 illustrates a solar cell assembly 1000 of the present invention in which counter-electrodes 420 , transparent conductive layers 412 , and junctions 410 are pierced, in the manner illustrated, in order to form two discrete junctions in parallel.
  • transparent tubular casing 310 may be used to encase elongated solar cells 402 with or without optional filler layer 330 .
  • FIG. 15 illustrates an elongated solar cell 402 in accordance with the present invention.
  • a transparent tubular casing 310 encases the elongated solar cell 402 , leaving only ends of electrodes 420 exposed to establish suitable electrical connections.
  • the ends of the elongated solar cell 402 are stripped and conductive layer 404 is exposed.
  • back-electrode 404 serves as the first electrode in the assembly and transparent conductive layer 412 on the exterior surface of each elongated solar cell 402 serves as the counter-electrode.
  • protruding counter-electrodes 420 and electrodes 440 which are attached to the elongated solar cell 402 , provide convenient electrical connection.
  • first groove 677 - 1 and a second groove 677 - 2 that each runs lengthwise on opposing sides of elongated solar cell 402 .
  • counter-electrodes 420 are fitted into grooves 677 in the manner illustrated in FIG. 15 .
  • such counter-electrodes 420 are glued into grooves 677 using a conductive ink or conductive glue.
  • a conductive ink or conductive glue for example, CuPro-Cote (available from Lessemf.com, Albany, N.Y.), which is a sprayable metallic coating system using a non-oxidizing copper as a conductor, can be used.
  • counter-electrodes 420 are fitted in to grooves 677 and then a bead of conductive ink or conductive glue is applied.
  • the present invention encompasses grooves 677 that have a broad range of depths and shape characteristics and is by no means limited to the shape of the grooves 677 illustrated in FIG. 15 .
  • any type of groove 677 that runs along the long axis of a first solar cell 402 and that can accommodate all or part of counter-electrode 420 is within the scope of the present invention.
  • Counter-electrodes 420 conduct current from the combined layer 410 /( 415 )/ 412 .
  • counter-electrodes 420 are sheathed as shown in FIG. 15 so that they are electrically isolated from conductive layer 404 .
  • the ends of protruding counter-electrodes 420 are unsheathed so they can form electric contact with additional devices.
  • a second set of electrodes 440 are attached to the exposed back-electrode 404 .
  • the second set of electrodes 440 conduct current from back-electrode 404 .
  • an embodiment in accordance with the present invention has two electrodes 440 attached at two opposing ends of each elongated solar cell 402 .
  • electrodes 440 are glued onto back-electrode 404 using a conductive ink or conductive glue.
  • a conductive ink or conductive glue for example, CuPro-Cote can be used.
  • electrodes 440 are glued to layer 404 and then a bead of conductive ink or conductive glue is applied.
  • electrodes 440 in the present invention have a broad range of lengths and widths and shape characteristics and are by no means limited to the shape of 440 illustrated in FIG. 15 .
  • the two electrodes 440 on opposite ends of the elongated solar cell 402 are not on the same side of the solar cell cylinder.
  • the first electrode 440 is on the bottom side of the elongated solar cell 402 while the second electrode 440 is on the top side of the elongated solar cell 402 .
  • Such an arrangement facilitates the connection of the solar cells in a serial manner.
  • the two electrodes 440 can be on the same side of elongated solar cell 402 .
  • each electrode 440 is made of a thin strip of conductive material that is attached to conductive layer 404 / 1304 ( FIG. 15 ). In some embodiments, each electrode 440 is made of a conductive ribbon of metal (e.g., copper, aluminum, gold, silver, molybdenum, or an alloy thereof) or a conductive ink. As will be explained in conjunction with subsequent drawings, counter-electrode 420 and electrodes 440 are used to electrically connect elongated solar cells 402 , preferably in series.
  • a transparent tubular casing 310 seals a solar cell unit 402 to provide support and protection to the solar cell.
  • the size and dimensions of transparent tubular casing 310 are determined by the size and dimension of individual solar cells 402 in a solar cell assembly unit 402 .
  • Transparent tubular casing 310 may be made of glass, plastic or any other suitable material.
  • transparent tubular casing 310 examples include, but are not limited to, glass (e.g., soda lime glass), acrylics such as polymethylmethacrylate, polycarbonate, fluoropolymer (e.g., Tefzel or Teflon), polyethylene terephthalate (PET), Tedlar, or some other suitable transparent material.
  • glass e.g., soda lime glass
  • acrylics such as polymethylmethacrylate, polycarbonate, fluoropolymer (e.g., Tefzel or Teflon), polyethylene terephthalate (PET), Tedlar, or some other suitable transparent material.
  • PET polyethylene terephthalate
  • Tedlar or some other suitable transparent material.
  • transparent tubular casing 310 is constructed using blow molding.
  • Blow molding involves clamping the ends of a softened tube of polymers, which can be either extruded or reheated, inflating the polymer against the mold walls with a blow pin, and cooling the product by conduction or evaporation of volatile fluids in the container.
  • Three general types of blow molding are extrusion blow molding, injection blow molding, and stretch blow molding. Extrusion blow molding is used to make items of weight greater than twelve ounces. Injection blow molding achieves accurate wall thickness. Stretch blow molding is typically used for difficult to blow crystalline and crystallizable polymers such as polypropylene and polyethylene terephthalate.
  • U.S. Pat. No. 237,168 describes a process for blow molding (e.g., 602 in FIG. 6A ).
  • Other forms of blow molding include low density polyethylene (LDPE) blow molding, high density polyethylene (HDPE) blow molding and polypropylene (PP) blow molding
  • the extrusion blow molding method comprises a Parison (e.g., 602 in FIG. 6A ) and mold halves that close onto the Parison (e.g., 604 in FIG. 6A ).
  • EBM extrusion blow molding
  • material is melted and extruded into a hollow tube (e.g., a Parison as depicted in FIG. 6A ).
  • the Parison is then captured by closing it into a cooled metal mold. Air is then blown into the Parison, inflating it into the shape of the hollow bottle, container or part. After the material has cooled sufficiently, the mold is opened and the part is ejected.
  • EBM processes consist of either continuous or intermittent extrusion of the Parison 602 .
  • the types of EBM equipment may be categorized accordingly.
  • Typical continuous extrusion equipments usually comprise rotary wheel blow molding systems and a shuttle machinery that transports the finished products from the Parison.
  • Exemplary intermittent extrusion machinery comprises a reciprocating screw machinery and an accumulator head machinery.
  • Basic polymers, such as PP, HDPE, PVC and PET are increasingly being coextruded with high barrier resins, such as EVOH or Nylon, to provide permeation resistance to water, oxygen, CO 2 or other substances.
  • blow molding is a low pressure process, with typical blow air pressures of 25 to 150 psi. This low pressure process allows the production of economical low-force clamping stations, while parts can still be produced with surface finishes ranging from high gloss to textured. The resulting low stresses in the molded parts also help make the containers resistant to strain and environmental stress cracking.
  • IBM injection blow molding
  • material is injection molded onto a core pin (e.g., 612 in FIG. 6B ); then the core pin is rotated to a blow molding station (e.g., 614 in FIG. 6B ) to be inflated and cooled.
  • the process is divided in to three steps: injection, blowing and ejection.
  • a typical IBM machine is based on an extruder barrel and screw assembly which melts the polymer. The molten polymer is fed into a manifold where it is injected through nozzles into a hollow, heated preform mold (e.g., 614 in FIG. 6B ).
  • the preform mold forms the external shape and is clamped around a mandrel (the core rod, e.g., 612 in FIG. 6B ) which forms the internal shape of the preform.
  • the preform consists of a fully formed bottle/jar neck with a thick tube of polymer attached, which will form the body.
  • the preform mold opens and the core rod is rotated and clamped into the hollow, chilled blow mold.
  • the core rod 612 opens and allows compressed air into the preform 614 , which inflates it to the finished article shape.
  • the blow mold opens and the core rod is rotated to the ejection position.
  • the finished article is stripped off the core rod and leak-tested prior to packing.
  • the preform and blow mold can have many cavities, typically three to sixteen depending on the article size and the required output. There are three sets of core rods, which allow concurrent preform injection, blow molding and ejection.
  • a typical SBM system comprises a stretch blow pin (e.g., 622 in FIG. 6C ), an air entrance (e.g., 624 in FIG. 6C ), mold vents (e.g., 626 in FIG. 6C ), a preform (e.g., 628 in FIG. 6C ), and cooling channels (e.g., 632 in FIG. 6C ).
  • These preforms are produced with the necks of the bottles, including threads (the “finish”) on one end.
  • preforms are packaged, and fed later, after cooling, into an EBM blow molding machine.
  • the preforms are heated, typically using infrared heaters, above their glass transition temperature, then blown using high pressure air into bottles using metal blow molds.
  • the preform is stretched with a core rod as part of the process (e.g., as in position 630 in FIG. 6C ).
  • the stretching of some polymers, such as PET (polyethylene terepthalate) results in strain hardening of the resin and thus allows the bottles to resist deforming under the pressures formed by carbonated beverages, which typically approach 60 psi.
  • FIG. 6C shows what happens inside the blow mold.
  • the preform is first stretched mechanically with a stretch rod. As the rod travels down low-pressure air of 5 to 25 bar (70 to 350 psi) is introduced blowing a ‘bubble’. Once the stretch rod is fully extended, high-pressure air of up to 40 bar (580 psi) blows the expanded bubble into the shape of the blow mold.
  • transparent tubular casing 310 is made of plastic rather than glass. Production of transparent tubular casing 310 in such embodiments differs from glass transparent tubular casing 310 production even though the basic molding mechanisms remain the same.
  • a typical plastic transparent tubular casing 310 manufacturing process comprises the following steps: extrusion, heading, decorating, and capping, with the latter two steps being optional.
  • transparent tubular casing 310 is made using extrusion molding.
  • a mixture of resin is placed into an extruder hopper.
  • the extruder is temperature controlled as the resin is fed through to ensure proper melt of the resin.
  • the material is extruded through a set of sizing dies that are encapsulated within a right angle cross section attached to the extruder.
  • the forming die controls the shape of transparent tubular casing 310 .
  • the formed plastic sleeve cools under blown air or in a water bath and hardens on a moving belt. After cooling step, the formed plastic sleeve is ready for cutting to a given length by a rotating knife.
  • the forming die controls the shape of the transparent tubular casing 310 .
  • the forming dies are custom-made such that the shape of transparent tubular casing 310 complements the shape of the solar cell unit 402 .
  • the forming die also controls the wall thickness of the transparent tubular casing 310 .
  • transparent tubular casing 310 has a wall thickness of 2 mm or thicker, 1 mm or thicker, 0.5 mm or thicker, 0.3 mm or thicker, or of any thickness between 0 and 0.3 mm.
  • the balance of the manufacturing process can be accomplished in one of three ways.
  • the most common method in the United States is the “downs” process of compression, molding the head onto the tube.
  • the sleeve is placed on a conveyor that takes it to the heading operation where the shoulder of the head is bound to the body of the tube while, at the same time, the thread is formed.
  • the sleeve is then placed on a mandrel and transferred down to the slug pick-up station.
  • the hot melt strip or slug is fused onto the end of the sleeve and then transferred onto the mold station.
  • Transparent tubular casing 310 with one open-end are suitable to encase solar cell embodiments as depicted in FIGS. 3, 4 , 7 , 8 , 9 , 10 or 11 .
  • Plastic tubing with both ends open may be used to encase solar cell embodiments as depicted in FIGS. 3 and 15 .
  • the headed transparent tubular casing 310 is then conveyed to the accumulator.
  • the accumulator is designed to balance the heading and decorating operation. From here, the transparent tubular casing 310 may go to the decorating operation. Inks for the press are premixed and placed in the fountains. At this point, the ink is transferred onto a plate by a series of rollers. The plate then comes in contact with a rubber blanket, picking up the ink and transferring it onto the circumference of the transparent tubular casing 310 .
  • the wet ink on the tube is cured by ultra-violet light or heat. In the embodiments in accordance with the present invention, transparency is required in the tube products so the color process is unnecessary. However, a similar method may be used to apply a protective coating to transparent tubular casing 310 .
  • a conveyor transfers the tube to the capping station where the cap is applied and torqued to the customer's specifications.
  • the capping step is unnecessary for the scope of this invention.
  • Glass is a preferred material choice for transparent tubular casing 310 relative to plastics because glass provides a complete seal against molecular water from solar cell 402 and therefore provides protection and helps to maintain the performance and prolong the lifetime of solar cell 402 .
  • glass may be made into transparent tubular casing 310 using the standard blow molding technologies.
  • techniques such as casting, extrusion, drawing, pressing, heat shrinking or other fabrication processes may also be applied to manufacture suitable glass transparent tubular casing 310 to circumferentially cover and/or encapsulate solar cells 402 . Molding technologies, in particular micromolding technologies for microfabrication, are discussed in greater detail in Madou, Fundamentals of Microfabrication , Chapter 6, pp.
  • Transparent tubular casing made of glass is made of glass.
  • transparent tubular casing 310 is made of glass.
  • glass is a transparent, relatively strong, hard-wearing, essentially inert, and biologically inactive material that can be formed with very smooth and impervious surfaces.
  • the present invention contemplates a wide variety of glasses for transparent tubular casing 310 , some of which are described in this section and others of which are know to those of skill in the relevant arts.
  • Common glass contains about 70% amorphous silicon dioxide (SiO 2 ), which is the same chemical compound found in quartz, and its polycrystalline form, sand.
  • Common glass is used in some embodiments of the present invention to make transparent tubular casing 310 .
  • common glass is brittle and will break into sharp shards.
  • the properties of common glass are modified, or even changed entirely, with the addition of other compounds or heat treatment.
  • SiO 2 has a melting point of about 2000° C., and can be made into glass for special applications (for example, fused quartz).
  • Two other substances are always added to common glass to simplify processing.
  • soda sodium carbonate Na 2 CO 3
  • potash the equivalent potassium compound, which lowers the melting point to about 1000° C.
  • soda makes the glass water-soluble, which is undesirable, so lime (calcium oxide, CaO) is the third component, added to restore insolubility.
  • the resulting glass contains about 70% silica and is called a soda-lime glass. Soda-lime glass is used in some embodiments of the present invention to make transparent tubular casing 310 .
  • soda-lime most common glass has other ingredients added to change its properties.
  • Lead glass such as lead crystal or flint glass, is more ‘brilliant’ because the increased refractive index causes noticeably more “sparkles”, while boron may be added to change the thermal and electrical properties, as in Pyrex.
  • boron may be added to change the thermal and electrical properties, as in Pyrex.
  • Adding barium also increases the refractive index.
  • Thorium oxide gives glass a high refractive index and low dispersion, and was formerly used in producing high-quality lenses, but due to its radioactivity has been replaced by lanthanum oxide in modern glasses.
  • cerium(IV) oxide can be used for glass that absorbs UV wavelengths (biologically damaging ionizing radiation). Glass having on or more of any of these additives is used in some embodiments of the present invention to make transparent tubular casing 310 .
  • glass material include but are not limited to aluminosilicate, borosilicate (e.g., Pyrex, Duran, Simax), dichroic, germanium/semiconductor, glass ceramic, silicate/fused silica, soda lime, quartz, chalcogenide/sulphide, cereated glass, and fluoride glass and transparent tubular casing 310 can be made of any of these materials.
  • aluminosilicate e.g., Pyrex, Duran, Simax
  • dichroic germanium/semiconductor
  • glass ceramic silicate/fused silica
  • soda lime soda lime
  • quartz chalcogenide/sulphide
  • cereated glass and fluoride glass and transparent tubular casing 310
  • fluoride glass and transparent tubular casing 310 can be made of any of these materials.
  • transparent tubular casing 310 is made of soda lime glass.
  • Soda lime glass is softer than borosilicate and quartz, making scribe cutting easier and faster.
  • Soda Lime glass is very low cost and easy to mass produce.
  • Soda lime glass has poor thermal shock resistance.
  • soda lime glass is best used for transparent tubular casing 310 in thermal environments where heating is very uniform and gradual. As a result, when solar cells 402 are encased by transparent tubular casing 310 made from soda lime glass, such cells are best used in environments where temperature does not drastically fluctuate.
  • transparent tubular casing 310 are made of glass material such as borosilicate glass.
  • borosilicate glass trade names for borosilicate glass include but are not limited to Pyrex® (Corning), Duran® (Schott Glass), and Simax® (Kavalier).
  • the dominant component of borosilicate glass is SiO 2 with boron and various other elements added.
  • Borosilicate glass is easier to hot work than materials such as quartz, making fabrication less costly.
  • Material cost for borosilicate glass is also considerably less than fused quartz. Compared to most glass, except fused quartz, borosilicate glass has low coefficient of expansion, three times less than soda lime glass. This makes borosilicate glass useful in thermal environments, without the risk of breakage due to thermal shock.
  • a float process can be used to make relatively low cost optical quality sheet borosilicate glass in a variety of thickness from less than 1 mm to over 30 mm thick. Relative to quartz, borosilicate glass is easily moldable. In addition, borosilicate glass has minimum devitrification when molding and flame working. This means high quality surfaces can be maintained when molding and slumping. Borosilicate glass is thermally stable up to 500° C. for continuous use. Borosilicate glass is also more resistant to non-fluorinated chemicals than household soda lime glass and mechanically stronger and harder than soda lime glass. Borosilicate is usually two to three times more expensive than soda lime glass.
  • transparent tubular casing 310 can be made with glass such as, for example, aluminosilicate, borosilicate (e.g., Pyrax®, Duran®, Simax®), dichroic, germanium/semiconductor, glass ceramic, silicate/fused silica, soda lime, quartz, chalcogenide/sulphide, cereated glass and/or fluoride glass.
  • aluminosilicate e.g., Pyrax®, Duran®, Simax®
  • dichroic germanium/semiconductor
  • glass ceramic silicate/fused silica
  • soda lime soda lime
  • quartz quartz
  • chalcogenide/sulphide cereated glass and/or fluoride glass.
  • Transparent tubular casing made of plastic is made of clear plastic.
  • Plastics are a cheaper alternative to glass.
  • plastic material is in general less stable under heat, has less favorable optical properties and does not prevent molecular water from penetrating through transparent tubular casing 310 .
  • the last factor if not rectified, damages solar cells 402 and severely reduces their lifetime.
  • the water resistant layer described in Section 5.1.1. is used to prevent water seepage into the solar cells 402 when transparent tubular casing 310 is made of plastic.
  • a wide variety of materials can be used in the production of transparent tubular casing 310 , including, but not limited to, ethyl vinyl acetate (EVA), perfluoroalkoxy fluorocarbon (PFA), nylon/polyamide, cross-linked polyethylene (PEX), polyolefin, polypropylene (PP), polyethylene terephtalate glycol (PETG), polytetrafluoroethylene (PTFE), thermoplastic copolymer (for example, ETFE®, which is a derived from the polymerization of ethylene and tetrafluoroethylene: TEFLON® monomers), polyurethane/urethane, polyvinyl chloride (PVC), polyvinylidene fluoride (PVDF), Tygon®, Vinyl, and Viton®.
  • EVA ethyl vinyl acetate
  • PFA perfluoroalkoxy fluorocarbon
  • nylon/polyamide nylon/polyamide
  • PEX polyolefin
  • PP
  • a filler layer 330 is provided to seal a solar cell unit 402 from adverse exposure to water or oxygen.
  • a filler layer 330 may be eliminated such that solar cells 402 directly contacts transparent tubular casing 310 .
  • custom-designed transparent tubular casing 310 may be used to encase the corresponding embodiments of solar cell 402 to achieve tight fitting and better protection.
  • FIG. 14 depicts exemplary embodiments of transparent tubular casing 310 that provides proper encapsulation to the solar cell embodiments depicted in FIGS. 4, 7 , 8 , 9 , 10 , 11 and 13 .
  • Rod or cylindrical shaped solar cells 402 individually encased by transparent tubular casing 310 (for example those shown in FIGS. 3, 4 , 7 , 8 , 9 , 10 , 13 , and 15 ), can be assembled into solar cell assemblies of any shape and size.
  • the assembly can be bifacial arrays 400 ( FIG. 4 ), 700 ( FIG. 7 ), 800 ( FIG. 8 ), 900 ( FIG. 9 ), or 1000 ( FIG. 10 ).
  • There is no limit to the number of solar cells 402 in this plurality e.g., 10 or more, 100 or more, 1000 or more, 10,000 or more, between 5,000 and one million solar cells 402 , etc.).
  • solar cells 402 may also be encapsulated as arrays.
  • multiple transparent tubular casings 310 may be manufactured as fused arrays. This method is advantageous in that little or no additional connection between the individual solar cells 402 is required.
  • a solar cell assembly is further completed by loading elongated solar cells 402 (for example 402 in FIG. 4A ) into all or a portion of the transparent tubular casing 310 in the array of tubular casings.
  • a solar cell 402 having a filler layer coated thereon is assembled into a transparent tubular casing 310 .
  • filler layer 330 comprises one or more of the properties of: electrical insulation, oxidation eliminating effect, water proofing, and/or physical protection of transparent conductive layer 412 of solar cell 402 during assembly of solar cell units.
  • an elongated solar cell 402 , optional filler layer 330 , and a transparent tubular casing 310 are assembled using a suction loading method illustrated in FIG. 20A .
  • Transparent tubular casing 310 made of transparent glass, plastics or other suitable material, is sealed at one end 2002 .
  • Materials that are used to form filler layer 330 for example, silicone gel, is poured into the sealed transparent tubular casing 310 .
  • An example of a silicone gel is Wacker SilGel® 612 (Wacker-Chemie GmbH, Kunststoff, Germany).
  • Wacker SilGel® 612 is a pourable, addition-curing, RTV-2 silicone rubber that vulcanizes at room temperature to a soft silicone gel. Still another example of silicone gel is Sylgard® silicone elastomer (Dow Corning). Another example of a silicone gel is Wacker Elastosil® 601 (Wacker-Chemie GmbH, Kunststoff, Germany). Wacker Elastosil® 601 is a pourable, addition-curing, RTV-2 silicone rubber. Referring to FIG. 22 , silicones can be considered a molecular hybrid between glass and organic linear polymers. As shown in FIG. 22 , if there are no R groups, only oxygen, the structure is inorganic silica glass (called a Q-type Si).
  • a resin or silsequioxane (T-type Si) material is formed. These silsequioxanes are more flexible than the Q-type materials. Finally, if two oxygen atoms are replaced by organic groups a very flexible linear polymer (D-type Si) is obtained. The last structure shown (M-type Si) has three oxygen atoms replaced by R groups, resulting in an end cap structure. Because the backbone chain flexibility is increasing as R groups are added, the modulus of the materials and their coefficients of thermal expansion (CTE) also change.
  • R group e.g. methyl, ethyl, phenyl, etc.
  • the silicone used to form filler layer is a Q-type silicone, a silsequioxane, a D-type silicon, or an M-type silicon.
  • the elongated solar cell 402 is then loaded into transparent tubular casing 310 .
  • Optional suction force may be applied at the open end 2004 of transparent tubular casing 310 to draw the filler material upwards to completely fill the space between solar cell 402 and transparent tubular casing 310 .
  • an elongated solar cell 402 , filler layer 330 , and a transparent tubular casing 310 may be assembled using the pressure loading method illustrated in FIG. 20B .
  • Transparent tubular casing 310 made of transparent glass, plastics or other suitable material, is dipped in container 2008 containing optional filler layer material (e.g., silicone gel) used to form optional filler layer 330 .
  • optional filler layer material e.g., silicone gel
  • an elongated solar cell 402 , filler layer 330 and a transparent tubular casing 310 is assembled using the pour-and-slide loading method depicted in FIG. 20C .
  • a transparent tubular casing 310 made of transparent glass, plastics or other suitable material, is sealed at one end 2002 .
  • a container 2010 containing filler material (e.g., silicone gel), is used to pour the filler layer material into the sealed transparent tubular casing 310 while solar cell 402 is simultaneously slid into transparent tubular casing 310 .
  • the filler material that is being poured into transparent tubular casing 310 fills up the space between solar cell 402 and transparent tubular casing 310 .
  • the filler material that is being poured down the side of transparent tubular casing 310 provides lubrication to facilitate the slide-loading process.
  • a tubular casing 310 is assembled onto solar cell 402 without a filler layer 330 .
  • tubular casing 310 may directly contact solar cell 402 .
  • Tight packing and tubular casing 310 against solar cell 402 may be achieved by using one of the following methods. It will be appreciated that the methods for assembling a solar cell unit 300 described in this section can be used with solar cells 402 that are encased with a filler layer 330 . However, in such embodiments, layer 330 must be deposited onto transparent conductive layer 412 of solar cells 402 prior to integrating the solar cell 402 with a transparent tubular casing.
  • transparent tubular casing 310 heat shrinked onto solar cell 402 .
  • the heat shrink method may be used to form both plastic and glass transparent tubular casings 310 .
  • heat-shrinkable plastic tubing made of polyolefin, fluoropolymer (PVC, FEP, PTFE, Kynar® PVDF), chlorinated polyolefin (Neoprene) and highly flexible elastomer (Viton®) heat-shrinkable tubing may be used to form transparent tubular casing 310 .
  • fluoropolymers offer increased lubricity for easy sliding, and low moisture absorption for enhanced dimensional stability.
  • Transparent heat-shrinkable plastic tubing is available.
  • the heat shrink tubing is available in an expandable range of 2:1 to 3:1.
  • the heat shrink ratio of the tubing material is smaller than 2:1, for example, fluorinated ethylene-propylene (FEP) at 1.3:1.
  • FEP fluorinated ethylene-propylene
  • a heat shrink tubing suitable for the manufacture of transparent tubular casing 310 may have heat shrink ratio greater than 3:1.
  • transparent tubular casing 310 may be circumferentially disposed onto solar cell 402 by using the method of injection molding. A more detailed description of the method is already included above.
  • solar cells 402 may be used as the preformed mold and transparent tubular casing 310 (e.g., made of plastic material) is directly formed on the outer surface of solar cells 402 .
  • Plastic material does not completely seal molecular water from solar cells 402 . Because water interferes with the function of a solar cell 402 , it is therefore important to make the solar cell 402 resistant to water.
  • plastic transparent tubular casings 310 are used to cover solar cells 402 , this is accomplished by covering either the solar cell 402 or transparent tubular casing 310 with one or more layers of transparent water-resistant coating 340 ( FIG. 21 ). In some embodiments, both solar cell 402 and transparent tubular casing 310 are coated with one or more layers of transparent water-resistant coating 340 to extend the functional life time of the solar cell unit 300 . In other embodiments, an optional antireflective coating 350 is also disposed on transparent tubular casing 310 to maximize solar cell efficiency.
  • solar cell 402 is dipped in a liquid-like suspension or resin and subsequently exposed to catalyst or curing agent to form transparent tubular casing 310 through a polymerization process.
  • materials used to form transparent tubular casing 310 comprise silicone, poly-dimethyl siloxane (PDMS), silicone gel, epoxy, acrylics, and any combination or variation thereof.
  • any layer outside a solar cell 402 should not adversely affect the properties of incident radiation on the solar cell.
  • Transparency In order to establish maximized input into solar cell absorption layer (e.g., semiconductor junction 410 ), absorption of the incident radiation by any layer outside a solar cell 402 should be avoided or minimized. This transparency requirement varies as a function of the absorption properties of the underlying semiconductor junction 410 of solar cells 402 .
  • transparent tubular casing 310 and optional filler layer 330 should be as transparent as possible to the wavelengths absorbed by the semiconductor junction 410 .
  • materials used to make transparent tubular casing 310 and optional filer layer 330 should be transparent to light in the 500 nm to 1200 nm wavelength range.
  • Ultraviolet Stability Any material used to construct a layer outside solar cell 402 should be chemically stable and, in particular, stable upon exposure to UV radiation. More specifically, such material should not become less transparent upon UV exposure. Ordinary glass partially blocks UVA (wavelengths 400 and 300 nm) and it totally blocks UVC and UVB (wavelengths lower than 300 nm).
  • the UV blocking effect of glass is usually due additives, e.g. sodium carbonate, in glass.
  • additives in transparent tubular casings 310 made of glass can render the casing 310 entirely UV protective. In such embodiments, because the transparent tubular casing 310 provides complete protection from UV wavelengths, the UV stability requirements of the underlying optional filler layer 330 are reduced.
  • EVA, PVB, TPU (urethane), silicones, polycarbonates, and acrylics can be adapted to form a filler layer 330 when transparent tubular casing 310 is made of UV protective glass.
  • transparent tubular casing 310 is made of plastic material, UV stability requirement should be strictly followed.
  • transparent tubular casing 310 Plastic materials that are sensitive to UV radiation should not be used as transparent tubular casing 310 because yellowing of the material and/or optional filler layer 330 blocks radiation input into the solar cells 402 and reduces their efficiency. In addition, cracking of transparent tubular casing 310 due to UV exposure permanently damages solar cells 402 .
  • fluoropolymers like ETFE, and THV (Dyneon) are UV stable and highly transparent, while PET is transparent, but not sufficiently UV stable.
  • transparent tubular casing 310 is made of fluoropolymer based on monomers of tetrafluoroethylene, hexafluoropropylene and vinylidene fluoride.
  • PVC polyvinyl chloride
  • VVC polyvinyl chloride
  • Methods have been developed to render PVC UV-stabilized, but even UV stabilized PVC is typically not sufficiently durable (for example, yellowing and cracking of PVC product will occur over relative short term usage).
  • Urethanes are better suited, but depend on the exact chemical nature of the polymer backbone. Urethane material is stable when the polymer backbone is formed by less reactive chemical groups (e.g., aliphatic or aromatic). On the other hand when the polymer backbone is formed by more reactive groups (e.g., double bonds), yellowing of the material occurs as a result of UV-catalyzed breakdown of the double bonds. Similarly, EVA will yellow and so will PVB upon continued exposure to UV light.
  • Other options are polycarbonate (can be stabilized against UV for up to 10 years OD exposure) or acrylics (inherently UV stable).
  • an incident beam L 1 hits the surface of transparent tubular casing 310 .
  • Part of the incident beam L 1 is reflected as L 2 while the remainder of incident beam L 1 (e.g., as refracted beam L 3 in FIG. 21 ) travels through transparent tubular casing 310 .
  • the refracted beam L 3 directly hits transparent conductive layer 412 of solar cell 402 (e.g., when optional filler layer 330 is absent).
  • filler layer 330 is present, as depicted in FIG.
  • L 3 hits the outer surface of the filler layer 330 , and the processes of reflection and refraction is repeated as it was when L 1 hit the surface of transparent tubular casing 310 , with some of L 3 reflected into filler layer 330 and some of L 3 refracted by filler layer 330 .
  • Antireflective coating may be applied on the outside of transparent tubular casing 310 .
  • this antireflective coating is made of MgF 2 .
  • this antireflective coating is made of silicone nitrate or titanium nitrate.
  • this antireflective coating is made of one or more layers of silicon monoxide (SiO). For example, shiny silicon can act as a mirror and reflects more than thirty percent of the light that shines on it.
  • a single layer of SiO reduces surface reflection to about ten percent, and a second layer of SiO can lower the reflection to less than four percent.
  • Other organic antireflective materials in particular, one which prevents back reflection from the surface of or lower layers in the semiconductor device and eliminates the standing waves and reflective notching due to various optical properties of lower layers on the wafer and the photosensitive film, are disclosed in U.S. Pat. No. 6,803,172, which is hereby incorporated by reference herein in its entirety. Additional antireflective coating materials and methods are disclosed in U.S. Pat. Nos. 6,689,535; 6,673,713; 6,635,583; 6,784,094; and 6,713,234, each of which is hereby incorporated herein by reference in its entirety.
  • the outer surface of transparent tubular casing 310 may be textured to reduce reflected radiation.
  • Chemical etching creates a pattern of cones and pyramids, which capture light rays that might otherwise be deflected away from the cell. Reflected light is redirected down into the cell, where it has another chance to be absorbed.
  • Material and methods for creating an anti-reflective layer by etching or by a combination of etching and coating techniques are disclosed in U.S. Pat. Nos. 6,039,888; 6,004,722; and 6,221,776; each of which is hereby incorporated herein by reference in its entirety.
  • the first refraction process occurs when incident beam L 1 travels from air through transparent tubular casing 310 as L 3 .
  • Ambient air has a refractive index around 1 (vacuum space has a refractive index of 1, which is the smallest among all known materials), which is much smaller than the refractive index of glass material (ranging from 1.4 to 1.9 with the commonly used material having refractive indices around 1.5) or plastic material (around 1.45).
  • the refractive angle ⁇ 310 is always much smaller than the incident angle ⁇ air , i.e., the incident beam is always bent towards solar cell 402 as it travels through transparent tubular casing 310 .
  • the refractive index of the filler layer 330 (e.g., ⁇ 310 in FIG. 21 ) should be larger than the refractive index of transparent tubular casing 310 so that the refracted beam of incident beam L 3 will also be bent towards solar cell 402 . In this ideal situation, every incident beam on transparent tubular casing 310 will be bent towards solar cell 402 after two reflection processes.
  • optional filler layer 330 is made of a fluid-like material (albeit sometimes very viscous fluid-like material) such that loading of solar cells 402 into transparent tubular casing 310 may be achieved as described above.
  • efficient solar radiation absorption is achieved by choosing filler material that has refractive index close to those of transparent tubular casing 310 .
  • materials that form transparent tubular casing 310 comprise transparent materials (either glass or plastic or other suitable materials) with refractive indices around 1.5.
  • fused silica glass has a refractive index of 1.46.
  • Borosilicate glass materials have refractive indices between 1.45 and 1.55 (e.g., Pyrex® glass has a refractive index of 1.47).
  • Flint glass materials with various amounts of lead additive have refractive indices between 1.5 and 1.9.
  • Common plastic materials have refractive indices between 1.46 and 1.55.
  • Exemplary materials with the appropriate optical properties for forming filler layer 330 further comprise silicone, polydimethyl siloxane (PDMS), silicone gel, epoxy, and acrylic material. Because silicone-based adhesives and sealants have a high degree of flexibility, they lack the strength of other epoxy or acrylic resins.
  • Transparent tubular casing 310 , optional filler layer 330 , optional antireflective layer 350 , water-resistant layer 340 , or any combination thereof form a package to maximize and maintain solar cell 402 efficiency, provide physical support, and prolong the life time of solar cell units 402 .
  • glass, plastic, epoxy or acrylic resin may be used to form transparent tubular casing 310 .
  • optional antireflective 350 and/or water resistant coating 340 are circumferentially disposed on transparent tubular casing 310 .
  • filler layer 330 is formed by softer and more flexible optically suitable material such as silicone gel.
  • filler layer 330 is formed by a silicone gel such as a silicone-based adhesives or sealants.
  • filler layer 330 is formed by GE RTV 615 Silicone.
  • RTV 615 is an optically clear, two-part flowable silicone product that requires SS4120 as primer for polymerization.
  • Silicone-based adhesives or sealants are based on tough silicone elastomeric technology. The characteristics of silicone-based materials, such as adhesives and sealants, are controlled by three factors: resin mixing ratio, potting life and curing conditions.
  • silicone adhesives have a high degree of flexibility and very high temperature resistance (up to 600° F.). Silicone-based adhesives and sealants have a high degree of flexibility. Silicone-based adhesives and sealants are available in a number of technologies (or cure systems). These technologies include pressure sensitive, radiation cured, moisture cured, thermo-set and room temperature vulcanizing (RTV). In some embodiments, the silicone-based sealants use two-component addition or condensation curing systems or single component (RTV) forms. RTV forms cure easily through reaction with moisture in the air and give off acid fumes or other by-product vapors during curing.
  • technologies include pressure sensitive, radiation cured, moisture cured, thermo-set and room temperature vulcanizing (RTV).
  • RTV room temperature vulcanizing
  • the silicone-based sealants use two-component addition or condensation curing systems or single component (RTV) forms. RTV forms cure easily through reaction with moisture in the air and give off acid fumes or other by-product vapors during curing.
  • Pressure sensitive silicone adhesives adhere to most surfaces with very slight pressure and retain their tackiness. This type of material forms viscoelastic bonds that are aggressively and permanently tacky, and adheres without the need of more than finger or hand pressure.
  • radiation is used to cure silicone-based adhesives.
  • ultraviolet light, visible light or electron bean irradiation is used to initiate curing of sealants, which allows a permanent bond without heating or excessive heat generation. While UV-based curing requires one substrate to be UV transparent, the electron beam can penetrate through material that is opaque to UV light. Certain silicone adhesives and cyanoacrylates based on a moisture or water curing mechanism may need additional reagents properly attached to the solar cell 402 without affecting the proper functioning of solar cells 402 .
  • Thermo-set silicone adhesives and silicone sealants are cross-linked polymeric resins cured using heat or heat and pressure. Cured thermo-set resins do not melt and flow when heated, but they may soften. Vulcanization is a thermosetting reaction involving the use of heat and/or pressure in conjunction with a vulcanizing agent, resulting in greatly increased strength, stability and elasticity in rubber-like materials. RTV silicone rubbers are room temperature vulcanizing materials.
  • the vulcanizing agent is a cross-linking compound or catalyst. In some embodiments in accordance with the present invention, sulfur is added as the traditional vulcanizing agent.
  • epoxy or acrylic material may be applied directly over solar cell 402 to form transparent tubular casing 310 directly.
  • care is taken to ensure that the non-glass transparent tubular casing 310 is also equipped with water resistant and/or antireflective properties to ensure efficient operation over a reasonable period of usage time.
  • transparent tubular casing 310 and optional filler layer 330 An important characteristics of transparent tubular casing 310 and optional filler layer 330 is that these layers should provide complete electrical insulation. No conductive material should be used to form either transparent tubular casing 310 or optional filler layer 330 .
  • each of the layers outside solar cell 402 e.g., the combination of transparent tubular casing 310 and/or optional filler layer 330
  • the combined width of each of the layers outside solar cell 402 is: r i ⁇ r o ⁇ outer ⁇ ⁇ ring where, referring to FIG. 3B ,
  • r i is the radius of solar cell 402 , assuming that semiconductor junction 410 is a thin-film junction;
  • r o is the radius of the outermost layer of transparent tubular casing 310 and/or optional filler layer 330 ;
  • ⁇ outer ring is the refractive index of the outermost layer of transparent tubular casing 310 and/or optional filler layer 330 .
  • the refractive index of many of the materials used to make transparent tubular casing 310 and/or optional filler layer 330 is about 1.5.
  • values of r o are permissible that are less than 1.5*r i . This constraint places a boundary on allowable thickness for the combination of transparent tubular casing 310 and/or optional filler layer 330 .
  • transparent tubular casing 310 is formed on an underlying layer (e.g., is formed on transparent conductive layer 412 , filler layer 330 or a water resistant layer) by spin coating, dip coating, plastic spraying, casting, Doctor's blade or tape casting, glow discharge polymerization, or UV curing.
  • an underlying layer e.g., is formed on transparent conductive layer 412 , filler layer 330 or a water resistant layer
  • spin coating e.g., is formed on transparent conductive layer 412 , filler layer 330 or a water resistant layer
  • semiconductor junction 410 is a heterojunction between an absorber layer 502 , disposed on back-electrode 404 , and a junction partner layer 504 , disposed on absorber layer 502 .
  • Layers 502 and 504 are composed of different semiconductors with different band gaps and electron affinities such that junction partner layer 504 has a larger band gap than absorber layer 502 .
  • absorber layer 502 is p-doped and junction partner layer 504 is n-doped.
  • transparent conductive layer 412 is n + -doped.
  • absorber layer 502 is n-doped and junction partner layer 504 is p-doped.
  • transparent conductive layer 412 is p + -doped.
  • the semiconductors listed in Pandey, Handbook of Semiconductor Electrodeposition , Marcel Dekker Inc., 1996, Appendix 5, which is hereby incorporated by reference herein in its entirety, are used to form semiconductor junction 410 .
  • absorber layer 502 is a group I-III′-VI 2 compound such as copper indium di-selenide (CuInSe 2 ; also known as CIS).
  • absorber layer 502 is a group I-III-VI 2 ternary compound selected from the group consisting of CdGeAs 2 , ZnSnAs 2 , CuInTe 2 , AgInTe 2 , CuInSe 2 , CuGaTe 2 , ZnGeAs 2 , CdSnP 2 , AgInSe 2 , AgGaTe 2 , CuInS 2 , CdSiAs 2 , ZnSnP 2 , CdGeP 2 , ZnSnAs 2 , CuGaSe 2 , AgGaSe 2 , AgInS 2 , ZnGeP 2 , ZnSiAs 2 , ZnSiP 2 , CuGaSe 2 , AgGaSe 2 , AgIn
  • junction partner layer 504 is CdS, ZnS, ZnSe, or CdZnS.
  • absorber layer 502 is p-type CIS and junction partner layer 504 is n ⁇ type CdS, ZnS, ZnSe, or CdZnS.
  • Such semiconductor junctions 410 are described in Chapter 6 of Bube, Photovoltaic Materials, 1998, Imperial College Press, London, which is hereby incorporated by reference in its entirety.
  • Such semiconductor junctions 410 are described in Chapter 6 of Bube, Photovoltaic Materials, 1998, Imperial College Press, London, which is hereby incorporated by reference in its entirety.
  • absorber layer 502 is copper-indium-gallium-diselenide (CIGS). Such a layer is also known as Cu(InGa)Se 2 .
  • absorber layer 502 is copper-indium-gallium-diselenide (CIGS) and junction partner layer 504 is CdS, ZnS, ZnSe, or CdZnS.
  • absorber layer 502 is p-type CIGS and junction partner layer 504 is n-type CdS, ZnS, ZnSe, or CdZnS.
  • Such semiconductor junctions 410 are described in Chapter 13 of Handbook of Photovoltaic Science and Engineering, 2003, Luque and Hegedus (eds.), Wiley & Sons, West Wales, England, Chapter 12, which is hereby incorporated by reference in its entirety.
  • CIGS is deposited using techniques disclosed in Beck and Britt, Final Technical Report, January 2006, NREL/SR-520-39119; and Delahoy and Chen, August 2005, “Advanced CIGS Photovoltaic Technology,” subcontract report; Kapur et al., January 2005 subcontract report, NREL/SR-520-37284, “Lab to Large Scale Transition for Non-Vacuum Thin Film CIGS Solar Cells”; Simpson et al., October 2005 subcontract report, “Trajectory-Oriented and Fault-Tolerant-Based Intelligent Process Control for Flexible CIGS PV Module Manufacturing,” NREL/SR-520-38681; and Ramanathan et al., 31 st IEEE Photovoltaics Specialists
  • CIGS absorber layer 502 is grown on a molybdenum back-electrode 404 by evaporation from elemental sources in accordance with a three stage process described in Ramanthan et al., 2003, “Properties of 19.2% Efficiency ZnO/CdS/CuInGaSe 2 Thin-film Solar Cells,” Progress in Photovoltaics: Research and Applications 11, 225, which is hereby incorporated by reference herein in its entirety.
  • layer 504 is a ZnS(O,OH) buffer layer as described, for example, in Ramanathan et al., Conference Paper, “CIGS Thin-Film Solar Research at NREL: FY04 Results and Accomplishments,” NREL/CP-520-37020, January 2005, which is hereby incorporated by reference herein in its entirety.
  • layer 502 is between 0.5 ⁇ m and 2.0 ⁇ m thick. In some embodiments, the composition ratio of Cu/(In+Ga) in layer 502 is between 0.7 and 0.95. In some embodiments, the composition ratio of Ga/(In+Ga) in layer 502 is between 0.2 and 0.4. In some embodiments the CIGS absorber has a ⁇ 110> crystallographic orientation. In some embodiments the CIGS absorber has a ⁇ 112> crystallographic orientation. In some embodiments the CIGS absorber is randomly oriented.
  • semiconductor junction 410 comprises amorphous silicon. In some embodiments this is an n/n type heterojunction.
  • layer 514 comprises SnO 2 (Sb)
  • layer 512 comprises undoped amorphous silicon
  • layer 510 comprises n+ doped amorphous silicon.
  • semiconductor junction 410 is a p-i-n type junction.
  • layer 514 is p + doped amorphous silicon
  • layer 512 is undoped amorphous silicon
  • layer 510 is n + amorphous silicon.
  • Such semiconductor junctions 410 are described in Chapter 3 of Bube, Photovoltaic Materials, 1998, Imperial College Press, London, which is hereby incorporated by reference in its entirety.
  • semiconductor junction 410 is based upon thin-film polycrystalline.
  • layer 510 is a p-doped polycrystalline silicon
  • layer 512 is depleted polycrystalline silicon
  • layer 514 is n-doped polycrystalline silicon.
  • Such semiconductor junctions are described in Green, Silicon Solar Cells: Advanced Principles & Practice , Centre for Photovoltaic Devices and Systems, University of New South Wales, Sydney, 1995; and Bube, Photovoltaic Materials, 1998, Imperial College Press, London, pp. 57-66, which is hereby incorporated by reference in its entirety.
  • semiconductor junctions 410 based upon p-type microcrystalline Si:H and microcrystalline Si:C:H in an amorphous Si:H solar cell are used. Such semiconductor junctions are described in Bube, Photovoltaic Materials, 1998, Imperial College Press, London, pp. 66-67, and the references cited therein, which is hereby incorporated by reference in its entirety.
  • semiconductor junction 410 is a tandem junction. Tandem junctions are described in, for example,
  • semiconductor junctions 410 are based upon gallium arsenide (GaAs) or other III-V materials such as InP, AlSb, and CdTe.
  • GaAs is a direct-band gap material having a band gap of 1.43 eV and can absorb 97% of AM1 radiation in a thickness of about two microns.
  • Suitable type III-V junctions that can serve as semiconductor junctions 410 of the present invention are described in Chapter 4 of Bube, Photovoltaic Materials, 1998, Imperial College Press, London, which is hereby incorporated by reference in its entirety.
  • semiconductor junction 410 is a hybrid multijunction solar cell such as a GaAs/Si mechanically stacked multijunction as described by Gee and Virshup, 1988, 20 th IEEE Photovoltaic Specialist Conference , IEEE Publishing, New York, p. 754, which is hereby incorporated by reference herein in its entirety, a GaAs/CuInSe 2 MSMJ four-terminal device, consisting of a GaAs thin film top cell and a ZnCdS/CuInSe 2 thin bottom cell described by Stanbery et al., 19 th IEEE Photovoltaic Specialist Conference , IEEE Publishing, New York, p.
  • semiconductor junctions 410 are based upon II-VI compounds that can be prepared in either the n-type or the p-type form. Accordingly, in some embodiments, referring to FIG. 5C , semiconductor junction 410 is a p-n heterojunction in which layers 520 and 540 are any combination set forth in the following table or alloys thereof.
  • semiconductor junctions 410 that are made from thin film semiconductor films are preferred, the invention is not so limited. In some embodiments semiconductor junctions 410 is based upon crystalline silicon. For example, referring to FIG. 5D , in some embodiments, semiconductor junction 410 comprises a layer of p-type crystalline silicon 540 and a layer of n-type crystalline silicon 550 . Methods for manufacturing crystalline silicon semiconductor junctions 410 are described in Chapter 2 of Bube, Photovoltaic Materials, 1998, Imperial College Press, London, which is hereby incorporated by reference herein in its entirety.
  • the solar cell design of the present invention is advantageous because it can collect light through the entire circumferential surface. Accordingly, in some embodiments of the present invention, these solar cell assemblies (e.g., solar cell assembly 400 , 700 , 800 , 900 , etc.) are arranged in a reflective environment in which surfaces around the solar cell assembly have some amount of albedo.
  • Albedo is a measure of reflectivity of a surface or body. It is the ratio of electromagnetic radiation (EM radiation) reflected to the amount incident upon it. This fraction is usually expressed as a percentage from 0% to 100%.
  • surfaces in the vicinity of the solar cell assemblies of the present invention are prepared so that they have a high albedo by painting such surfaces a reflective white color.
  • other materials that have a high albedo can be used.
  • the albedo of some materials around such solar cells approach or exceed ninety percent. See, for example, Boer, 1977, Solar Energy 19, 525, which is hereby incorporated by reference herein in its entirety.
  • surfaces having any amount of albedo e.g., five percent or more, ten percent or more, twenty percent or more
  • the solar cells assemblies of the present invention are arranged in rows above a gravel surface, where the gravel has been painted white in order to improve the reflective properties of the gravel.
  • any Lambertian or diffuse reflector surface can be used to provide a high albedo surface.
  • the bifacial solar cell assemblies (panels) of the present invention have a first and second face and are placed in rows facing South in the Northern hemisphere (or facing North in the Southern hemisphere). Each of the panels is placed some distance above the ground (e.g., 100 cm above the ground).
  • the East-West separation between the panels is somewhat dependent upon the overall dimensions of the panels. By way of illustration only, panels having overall dimensions of about 106 cm ⁇ 44 cm are placed in the rows such that the East-West separation between the panels is between 10 cm and 50 cm. In one specific example the East-West separation between the panels is 25 cm.
  • the central point of the panels in the rows of panels is between 0.5 meters and 2.5 meters from the ground. In one specific example, the central point of the panels is 1.55 meters from the ground.
  • the North-South separation between the rows of panels is dependent on the dimensions of the panels. By way of illustration, in one specific example, in which the panels have overall dimensions of about 106 cm ⁇ 44 cm, the North-South separation is 2.8 meters. In some embodiments, the North-South separation is between 0.5 meters and 5 meters. In some embodiments, the North-South separation is between 1 meter and 3 meters.
  • models for computing the amount of sunlight received by solar panels as put forth in Lorenzo et al., 1985, Solar Cells 13, pp. 277-292, which is hereby incorporated by reference herein in its entirety, are used to compute the optimum horizontal tilt and East-West separation of the solar panels in the rows of solar panels that are placed in a reflective environment.
  • internal or external reflectors are implemented in the solar cell assembly to take advantage of the albedo effect and enhance light input into the solar cell assembly.
  • An exemplary embodiment of the internal reflectors (e.g., reflector 1404 ) is depicted in FIG. 16 . More description of albedo surfaces that can be used in conjunction with the present invention are disclosed in U.S. patent application Ser. No. 11/315,523, which is hereby incorporated by reference in its entirety.
  • conductive core 404 of the solar cells 402 of the present invention is made of a uniform conductive material.
  • the invention is not limited to these embodiments.
  • conductive core 404 in fact has an inner core and an outer conductive core.
  • the inner core can be referred to as a substrate 403 while the outer core can be referred to as back-electrode 404 in such embodiment.
  • the outer conductive core is circumferentially disposed on substrate 403 .
  • substrate 403 is typically nonconductive whereas the outer core is conductive.
  • Substrate 403 has an elongated shape consistent with other embodiments of the present invention.
  • substrate 403 is made of glass fibers in the form of a wire.
  • substrate 403 is an electrically conductive nonmetallic material.
  • the present invention is not limited to embodiments in which substrate 403 is electrically conductive because the outer core can function as the electrode.
  • substrate 403 is tubing (e.g., plastic or glass tubing).
  • substrate 403 is made of a material such as polybenzamidazole (e.g., Celazole®, available from Boedeker Plastics, Inc., Shiner, Tex.).
  • the inner core is made of polymide (e.g., DuPontTM Vespel®, or DuPontTM Kapton®, Wilmington, Del.).
  • the inner core is made of polytetrafluoroethylene (PTFE) or polyetheretherketone (PEEK), each of which is available from Boedeker Plastics, Inc.
  • substrate 403 is made of polyamide-imide (e.g., Torlon® PAI, Solvay Advanced Polymers, Alpharetta, Ga.).
  • substrate 403 is made of a glass-based phenolic.
  • Phenolic laminates are made by applying heat and pressure to layers of paper, canvas, linen or glass cloth impregnated with synthetic thermosetting resins. When heat and pressure are applied to the layers, a chemical reaction (polymerization) transforms the separate layers into a single laminated material with a “set” shape that cannot be softened again. Therefore, these materials are called “thermosets.”
  • thermosets A variety of resin types and cloth materials can be used to manufacture thermoset laminates with a range of mechanical, thermal, and electrical properties.
  • substrate 403 is a phenoloic laminate having a NEMA grade of G-3, G-5, G-7, G-9, G-10 or G-11. Exemplary phenolic laminates are available from Boedeker Plastics, Inc.
  • substrate 403 is made of polystyrene.
  • polystyrene examples include general purpose polystyrene and high impact polystyrene as detailed in Marks' Standard Handbook for Mechanical Engineers , ninth edition, 1987, McGraw-Hill, Inc., p. 6-174, which is hereby incorporated by reference herein in its entirety.
  • substrate 403 is made of cross-linked polystyrene.
  • cross-linked polystyrene is Rexolite® (C-Lec Plastics, Inc). Rexolite is a thermoset, in particular a rigid and translucent plastic produced by cross linking polystyrene with divinylbenzene.
  • substrate 403 is a polyester wire (e.g., a Mylar® wire).
  • Mylar® is available from DuPont Teijin Films (Wilmington, Del.).
  • substrate 403 is made of Durastone®, which is made by using polyester, vinylester, epoxid and modified epoxy resins combined with glass fibers (Roechling Engineering Plastic Pte Ltd., Singapore).
  • substrate 403 is made of polycarbonate.
  • polycarbonates can have varying amounts of glass fibers (e.g., 10%, 20%, 30%, or 40%) in order to adjust tensile strength, stiffness, compressive strength, as well as the thermal expansion coefficient of the material.
  • Exemplary polycarbonates are Zelux® M and Zelux® W, which are available from Boedeker Plastics, Inc.
  • substrate 403 is made of polyethylene.
  • substrate 403 is made of low density polyethylene (LDPE), high density polyethylene (HDPE), or ultra high molecular weight polyethylene (UHMW PE). Chemical properties of HDPE are described in Marks' Standard Handbook for Mechanical Engineers , ninth edition, 1987, McGraw-Hill, Inc., p. 6-173, which is hereby incorporated by reference herein in its entirety.
  • LDPE low density polyethylene
  • HDPE high density polyethylene
  • UHMW PE ultra high molecular weight polyethylene
  • substrate 403 is made of acrylonitrile-butadiene-styrene, polytetrafluoro-ethylene (Teflon), polymethacrylate (lucite or plexiglass), nylon 6,6, cellulose acetate butyrate, cellulose acetate, rigid vinyl, plasticized vinyl, or polypropylene. Chemical properties of these materials are described in Marks' Standard Handbook for Mechanical Engineers , ninth edition, 1987, McGraw-Hill, Inc., pp. 6-172 through 1-175, which is hereby incorporated by reference herein in its entirety.
  • substrate 403 Additional exemplary materials that can be used to form substrate 403 are found in Modern Plastics Encyclopedia , McGraw-Hill; Reinhold Plastics Applications Series, Reinhold Roff, Fibres, Plastics and Rubbers , Butterworth; Lee and Neville, Epoxy Resins , McGraw-Hill; Bilmetyer, Textbook of Polymer Science , Interscience; Schmidt and Marlies, Principles of high polymer theory and practice , McGraw-Hill; Beadle (ed.), Plastics , Morgan-Grampiand, Ltd., 2 vols.
  • outer core is made out of any material that can support the photovoltaic current generated by solar cell with negligible resistive losses.
  • outer core is made of any conductive metal, such as aluminum, molybdenum, steel, nickel, silver, gold, or an alloy thereof.
  • outer core is made out of a metal-, graphite-, carbon black-, or superconductive carbon black-filled oxide, epoxy, glass, or plastic.
  • outer core is made of a conductive plastic. In some embodiments, this conductive plastic is inherently conductive without any requirement for a filler.
  • inner core is made out of a conductive material and outer core is made out of molybdenum.
  • inner core is made out of a nonconductive material, such as a glass rod, and outer core is made out of molybdenum.
  • the present invention encompasses solar cell assemblies having any dimensions that fall within a broad range of dimensions.
  • the present invention encompasses solar cell assemblies having a length l between 1 cm and 50,000 cm and a width w between 1 cm and 50,000 cm.
  • the solar cell assemblies have a length l between 10 cm and 1,000 cm and a width w between 10 cm and 1,000 cm.
  • the solar cell assemblies have a length l between 40 cm and 500 cm and a width w between 40 cm and 500 cm.
  • CIGS copper-indium-gallium-diselenide
  • back-electrode 404 can be made of molybdenum.
  • back-electrode 404 comprises an inner core of polyimide and an outer core that is a thin film of molybdenum sputtered onto the polyimide core prior to CIGS deposition. On top of the molybdenum, the CIGS film, which absorbs the light, is evaporated.
  • Cadmium sulfide (CdS) is then deposited on the CIGS in order to complete semiconductor junction 410 .
  • a thin intrinsic layer (i-layer) 415 is then deposited on the semiconductor junction 410 .
  • the i-layer 415 can be formed using a material including but not limited to, zinc oxide, metal oxide or any transparent material that is highly insulating.
  • transparent conductive layer 412 is disposed on either the i-layer (when present) or the semiconductor junction 410 (when the i-layer is not present).
  • Transparent conductive layer 412 can be made of a material such as aluminum doped zinc oxide (ZnO:Al), gallium doped zinc oxide, boron dope zinc oxide, indium-zinc oxide, or indium-tin oxide.
  • a roll of molybdenum-coated polyimide film (referred to as the web) is unrolled and moved continuously into and through one or more deposition zones.
  • the web is heated to temperatures of up to ⁇ 450° C. and copper, indium, and gallium are evaporated onto it in the presence of selenium vapor. After passing out of the deposition zone(s), the web cools and is wound onto a take-up spool.
  • an absorber material is deposited onto a polyimide/molybdenum web, such as those developed by Global Solar Energy (Tucson, Ariz.), or a metal foil (e.g., the foil disclosed in Simpson et al.).
  • the absorber material is any of the absorbers disclosed herein.
  • the absorber is Cu(InGa)Se 2 .
  • the elongated core is made of a nonconductive material such as undoped plastic.
  • the elongated core is made of a conductive material such as a conductive metal, a metal-filled epoxy, glass, or resin, or a conductive plastic (e.g., a plastic containing a conducting filler).
  • semiconductor junction 410 is completed by depositing a window layer onto the absorber layer.
  • the absorber layer is Cu(InGa)Se 2
  • CdS can be used.
  • optional i-layer 415 and transparent conductive layer 412 are added to complete the solar cell.
  • the foil is wrapped around and/or glued to a wire-shaped or tube-shaped elongated core.
  • the advantage of such a fabrication method is that material that cannot withstand the deposition temperature of the absorber layer, window layer, i-layer or transparent conductive layer 412 can be used as an inner core for the solar cell.
  • This manufacturing process can be used to manufacture any of the solar cells 402 disclosed in the present invention, where the conductive core 402 comprises an inner core and an outer conductive core.
  • the inner core is any conductive or nonconductive material disclosed herein whereas the outer conductive core is the web or foil onto which the absorber layer, window layer, and transparent conductive layer were deposited prior to rolling the foil onto the inner core.
  • the web or foil is glued onto the inner core using appropriate glue.
  • An aspect of the present invention provides a method of manufacturing a solar cell comprising depositing an absorber layer on a first face of a metallic web or a conducting foil. Next, a window layer is deposited on to the absorber layer. Next, a transparent conductive layer is deposited on to the window layer. The metallic web or conducting foil is then rolled around an elongated core, thereby forming an elongated solar cell 402 .
  • the absorber layer is copper-indium-gallium-diselenide (Cu(InGa)Se 2 ) and the window layer is cadmium sulfide.
  • the metallic web is a polyimide/molybdenum web.
  • the conducting foil is steel foil or aluminum foil.
  • the elongated core is made of a conductive metal, a metal-filled epoxy, a metal-filled glass, a metal-filled resin, or a conductive plastic.
  • a transparent conducting oxide conductive film is deposited on a tubular shaped or rigid solid rod shaped core rather than wrapping a metal web or foil around the elongated core.
  • the tubular shaped or rigid solid rod shaped core can be, for example, a plastic rod, a glass rod, a glass tube, or a plastic tube.
  • Such embodiments require some form of conductor in electrical communication with the interior face or back contact of the semiconductor junction.
  • divots in the tubular shaped or rigid solid rod shaped elongated core are filled with a conductive metal in order to provide such a conductor.
  • the conductor can be inserted in the divots prior to depositing the transparent conductive layer or conductive back contact film onto the tubular shaped or rigid solid rod shaped elongated core.
  • a conductor is formed from a metal source that runs lengthwise along the side of the elongated solar cell 402 .
  • This metal can be deposited by evaporation, sputtering, screen printing, inkjet printing, metal pressing, conductive ink or glue used to attach a metal wire, or other means of metal deposition.
  • the elongated core is a glass tubing having a divot that runs lengthwise on the outer surface of the glass tubing, and the manufacturing method comprises depositing a conductor in the divot prior to the rolling step.
  • the glass tubing has a second divot that runs lengthwise on the surface of the glass tubing.
  • the first divot and the second divot are on approximate or exact opposite circumferential sides of the glass tubing.
  • the method further comprises depositing a conductor in the second divot prior to the rolling or, in embodiments in which rolling is not used, prior to the deposition of an inner transparent conductive layer or conductive film, junction, and outer transparent conductive layer onto the elongated core.
  • the elongated core is a glass rod having a first divot that runs lengthwise on the surface of the glass rod and the method comprises depositing a conductor in the first divot prior to the rolling.
  • the glass rod has a second divot that runs lengthwise on the surface of the glass rod and the first divot and the second divot are on approximate or exact opposite circumferential sides of the glass rod.
  • the method further comprises depositing a conductor in the second divot prior to the rolling or, in embodiments in which rolling is not used, prior to the deposition of an inner transparent conductive layer or conductive film, junction, and outer transparent conductive layer onto the elongated core.
  • Suitable materials for the conductor are any of the materials described as a conductor herein including, but not limited to, aluminum, molybdenum, titanium, steel, nickel, silver, gold, or an alloy thereof.
  • FIG. 13 details a cross-section of a solar cell 402 in accordance with the present invention.
  • Solar cell 402 can be manufactured using either the rolling method or deposition techniques.
  • Components that have reference numerals corresponding to other embodiments of the present invention e.g., 410 , 412 , and 420 ) are made of the same materials disclosed in such embodiments.
  • FIG. 13 there is an elongated tubing 1306 having a first and second divot running lengthwise along the tubing (perpendicular to the plane of the page) that are on circumferentially opposing sides of tubing 1306 as illustrated.
  • tubing 1306 is not conductive.
  • tubing 1306 is made of plastic or glass in some embodiments.
  • Conductive wiring 1302 is placed in the first and second divot as illustrated in FIG. 13 .
  • the conductive wiring is made of any of the conductive materials of the present invention.
  • conductive wiring 1302 is made out of aluminum, molybdenum, steel, nickel, titanium, silver, gold, or an alloy thereof.
  • 1304 is a conducting foil or metallic web
  • the conductive wiring 1302 is inserted into the divots prior to wrapping the metallic web or conducting foil 1304 around the elongated core 1306 .
  • the conductive wiring 1302 is inserted into the divots prior to depositing the transparent conductive oxide or conductive film 1304 onto elongated core 1306 .
  • the metallic web or conducting foil 1304 is wrapped around tubing 1306 .
  • metallic web or conducting foil 1304 is glued to tubing 1306 .
  • layer 1304 is not a metallic web or conducting foil.
  • layer 1304 is a transparent conductive layer. Such a layer is advantageous because it allow for thinner absorption layers in the semiconductor junction.
  • the transparent conductive layer, semiconductor junction 410 and outer transparent conductive layer 412 are deposited using deposition techniques.
  • each elongated solar cell 402 in the plurality of elongated solar cells comprises an elongated tubing 1306 , a metallic web or a conducting foil (or, alternatively, a layer of TCO) 1304 circumferentially disposed on the elongated tubing 1306 , a semiconductor junction 410 circumferentially disposed on the metallic web or the conducting foil (or, alternatively, a layer of TCO) 1304 and a transparent conductive oxide layer 412 disposed on the semiconductor junction 410 .
  • the elongated solar cells 402 in the plurality of elongated solar cells are geometrically arranged in a parallel or a near parallel manner thereby forming a planar array having a first face and a second face.
  • the plurality of elongated solar cells is arranged such that one or more elongated solar cells in the plurality of elongated solar cells are not in electrically conductive contact with adjacent elongated solar cells.
  • the elongated solar cells can be in physical contact with each other if there is an insulative layer between adjacent elongated solar cells.
  • the solar cell assembly further comprises a plurality of metal counter-electrodes.
  • Each respective elongated solar cell 402 in the plurality of elongated solar cells is bound to a first corresponding metal counter-electrode 420 in the plurality of metal counter-electrodes such that the first metal counter-electrode lies in a first groove that runs lengthwise on the respective elongated solar cell 402 .
  • the apparatus further comprises a transparent electrically insulating substrate that covers all or a portion of the face of the planar array.
  • a first and second elongated solar cell in the plurality of elongated solar cells are electrically connected in series by an electrical contact that connects the first electrode of the first elongated solar cell to the first corresponding counter-electrode of the second elongated solar cell.
  • the elongated tubing 1306 is glass tubing or plastic tubing having a one or more grooves filled with a conductor 1302 .
  • each respective elongated solar cell 402 in the plurality of elongated solar cells is bound to a second corresponding metal counter-electrode 420 in the plurality of metal counter-electrodes such that the second metal counter-electrode lies in a second groove that runs lengthwise on the respective elongated solar cell 402 and such that the first groove and the second groove are on opposite or substantially opposite circumferential sides of the respective elongated solar cell 402 .
  • the plurality of elongated solar cells 402 is configured to receive direct light from the first face and the second face of the planar array.
  • Encapsulated solar cell unit 300 may be assembled into bifacial arrays as, for example, any of assemblies 400 ( FIG. 4 ), 700 ( FIG. 7 ), 800 ( FIG. 8 ), 900 ( FIG. 9 ), or 1000 ( FIG. 10 ).
  • static concentrators are used to improve the performance of the solar cell assemblies of the present invention.
  • FIG. 11 The use of a static concentrator in one exemplary embodiment is illustrated in FIG. 11 , where static concentrator 1102 , with aperture AB, is used to increase the efficiency of bifacial solar cell assembly CD, where solar cell assembly CD is, for example, any of assemblies 400 ( FIG. 4 ), 700 ( FIG. 7 ), 800 ( FIG. 8 ), 900 ( FIG. 9 ), or 1000 ( FIG.
  • Static concentrator 1102 can be formed from any static concentrator materials known in the art such as, for example, a simple, properly bent or molded aluminum sheet, or reflector film on polyurethane.
  • Concentrator 1102 is an example of a low concentration ratio, nonimaging, compound parabolic concentrator (CPC)-type collector. Any (CPC)-type collector can be used with the solar cell assemblies of the present invention.
  • CPC compound parabolic concentrator
  • a static concentrator as illustrated in FIG. 12 is used.
  • the bifacial solar cells illustrated in FIG. 12 can be any bifacial solar cell assembly of the present invention including. but not limited to assembly 400 ( FIG. 4 ), 700 ( FIG. 7 ), 800 ( FIG. 8 ), 900 ( FIG. 9 ), or 1000 ( FIG. 10 ).
  • the static concentrator illustrated in FIG. 12 uses two sheets of cover glass on the front and rear of the module with submillimeter V-grooves that are designed to capture and reflect incident light as illustrated in the figure.
  • FIG. 16 illustrates a solar cell assembly 1600 in accordance with the present invention.
  • an internal reflector 1404 is used to enhance solar input into the solar cell system.
  • elongated solar cells 402 and an internal reflector 1404 are assembled into an alternating array as shown.
  • Elongated solar cells 402 in solar cell assembly 1600 have counter-electrodes 420 and electrodes 440 .
  • solar cell assembly 1600 comprises a plurality of elongated solar cells 402 .
  • solar cell assembly 1600 also comprises a plurality of internal reflectors 1404 .
  • the number of internal reflectors 1404 in this plurality e.g., 10 or more, 100 or more, 1000 or more, 10,000 or more, between 5,000 and one million reflector 1404 , etc..
  • internal reflectors 1404 run lengthwise along corresponding elongated solar cells 402 .
  • internal reflectors 1404 have a hollow core.
  • a hollow nonconductive core e.g. substrate 403 of FIG. 3B
  • internal reflector 1404 is a plastic casing with a layer of highly reflective material (e.g., polished aluminum, aluminum alloy, silver, nickel, steel, etc.) deposited on the plastic casing.
  • internal reflector 1404 is a single piece made out of polished aluminum, aluminum alloy, silver, nickel, steel, etc. In some embodiments, internal reflector 1404 is a metal or plastic casing onto which is layered a metal foil tape. Exemplary metal foil tapes include, but are not limited to, 3M aluminum foil tape 425 , 3M aluminum foil tape 427 , 3M aluminum foil tape 431 , and 3M aluminum foil tape 439 (3M, St. Paul, Minn.). Internal reflector 1404 can adopt a broad range of designs, only one of which is illustrated in FIG. 16 . Central to the design of reflectors 1404 found in a preferred embodiment of the present invention is the desire to reflect direct light that enters into both sides of solar cell assembly 1600 (i.e., side 1620 and side 1640 ).
  • reflectors 1404 of the present invention are designed to optimize reflection of light into adjacent elongated solar cells 402 .
  • Direct light that enters one side of solar cell assembly 1600 e.g., side 1940 , above the plane of the solar cell assembly drawn in FIG. 16
  • light that enters the other side of the solar cell e.g., side 1620 , below the plane of the solar cell assembly drawn in FIG. 16
  • this surface is Lambertian, a diffuse or an involute reflector.
  • the shape of internal reflector 1404 on side 1620 may be different than on side 1640 .
  • a cross-sectional shape of an internal reflector 1404 is astroid.
  • a cross-sectional shape of an internal reflector 1404 is four-sided and at least one side of the four-sided cross-sectional shape is linear.
  • a cross-sectional shape of an internal reflector 1404 is four-sided and at least one side of the four-sided cross-sectional shape is parabolic.
  • a cross-sectional shape of an internal reflector 1404 is four-sided and at least one side of the four-sided cross-sectional shape is concave. In some embodiments, a cross-sectional shape of an internal reflector 1404 is four-sided; and at least one side of the four-sided cross-sectional shape is circular or elliptical. In some embodiments, a cross-sectional shape of an internal reflector in the plurality of internal reflectors is four-sided and at least one side of the four-sided cross-sectional shape defines a diffuse surface on the internal reflector.
  • a cross-sectional shape of an internal reflector 1404 is four-sided and at least one side of the four-sided cross-sectional shape is the involute of a cross-sectional shape of an elongated solar cell 402 .
  • a cross-sectional shape of an internal reflector 1404 is two-sided, three-sided, four-sided, five-sided, or six-sided.
  • a cross-sectional shape of an internal reflector in the plurality of internal reflectors 1404 is four-sided and at least one side of the four-sided cross-sectional shape is faceted.
  • Modified reflectors 1404 are equipped with a strong reflective property such that incident light is effectively reflected off the side surfaces 1610 of the reflectors 1404 .
  • the reflected light off surfaces 1610 does not have directional preference.
  • the reflector surfaces 1610 are designed such that the reflected light is directed towards the elongated solar cell 402 for optimal absorbance.
  • connection between an internal reflector 1404 and an adjacent elongated solar cell is provided by an additional adaptor piece.
  • Such an adapter piece has surface features that are complementary to both the shapes of internal reflectors 1404 as well as elongated solar cells 402 in order to provide a tight fit between such components.
  • such adaptor pieces are fixed on internal reflectors 1404 .
  • the adaptor pieces are fixed on elongated solar cells 402 .
  • the connection between elongated solar cells 402 and reflectors 1404 may be strengthened by electrically conducting glue or tapes.
  • the side surface 1610 of reflector 1404 is a diffuse reflecting surface (e.g., 1610 in FIG. 16 ).
  • specular reflection is defined as the reflection off smooth surfaces such as mirrors or a calm body of water (e.g., 1702 in FIG. 17A ).
  • smooth surfaces such as mirrors or a calm body of water (e.g., 1702 in FIG. 17A ).
  • a specular surface On a specular surface, light is reflected mainly in the direction of the reflected ray and is attenuated by an amount dependent upon the physical properties of the surface.
  • the position of the observer determines the perceived illumination of the surface.
  • Specular reflection models the light reflecting properties of shiny or mirror-like surfaces. In contrast to specular reflection, reflection off rough surfaces such as clothing, paper, and the asphalt roadway leads to a different type of reflection known as diffuse reflection ( FIG. 17B ).
  • Light incident on a diffuse reflection surface is reflected equally in all directions and is attenuated by an amount dependent upon the physical properties of the surface. Since light is reflected equally in all directions the perceived illumination of the surface is not dependent on the position of the observer or receiver of the reflected light (e.g. the position of the elongated solar cell 402 ).
  • Diffuse reflection models the light reflecting properties of matt surfaces.
  • Diffuse reflection surfaces reflect off light with no directional dependence for the viewer. Whether the surface is microscopically rough or smooth has a tremendous impact upon the subsequent reflection of a beam of light. Input light from a single directional source is reflected off in all directions on a diffuse reflecting surface (e.g., 1704 in FIG. 17B ). Diffuse reflection originates from a combination of internal scattering of light, e.g., the light is absorbed and then re-emitted, and external scattering from the rough surface of the object.
  • surface 1610 of reflector 1404 is a Lambertian reflecting surface (e.g., 1706 in FIG. 17C ).
  • a Lambertian source is defined as an optical source that obeys Lambert's cosine law, i.e., that has an intensity directly proportional to the cosine of the angle from which it is viewed ( FIG. 17C ).
  • a Lambertian surface is defined as a surface that provides uniform diffusion of incident radiation such that its radiance (or luminance) is the same in all directions from which it can be measured (e.g., radiance is independent of viewing angle) with the caveat that the total area of the radiating surface is larger than the area being measured.
  • the intensity of the light emanating in a given direction from any small surface component is proportional to the cosine of the angle of the normal to the surface.
  • the brightness (luminance, radiance) of a Lambertian surface is constant regardless of the angle from which it is viewed.
  • the incident light ⁇ right arrow over (l) ⁇ strikes a Lambertian surface ( FIG. 17C ) and reflects in different directions.
  • the intensity of ⁇ right arrow over (l) ⁇ is defined as I in
  • ⁇ ( ⁇ right arrow over (v) ⁇ , ⁇ right arrow over (l) ⁇ ) k d cos ⁇ out and k d is related to the surface property.
  • the incident angle is defined as ⁇ in
  • the reflected angle is defined as ⁇ out .
  • Such a Lambertian surface does not lose any incident light radiation, but re-emits it in all the available solid angles with a 2 ⁇ radians, on the illuminated side of the surface. Moreover, a Lambertian surface emits light so that the surface appears equally bright from any direction. That is, equal projected areas radiate equal amounts of luminous flux. Though this is an ideal, many real surfaces approach it.
  • a Lambertian surface can be created with a layer of diffuse white paint. The reflectance of such a typical Lambertian surface may be 93%. In some embodiments, the reflectance of a Lambertian surface may be higher than 93%. In some embodiments, the reflectance of a Lambertian surface may be lower than 93%.
  • Lambertian surfaces have been widely used in LED design to provide optimized illumination, for example in U.S. Pat. No. 6,257,737 to Marshall, et al.; U.S. Pat. No. 6,661,521 to Stern; and U.S. Pat. No. 6,603,243 to Parkyn, et al., which are hereby incorporated by reference in their entireties.
  • Lambertian surfaces 1610 on reflector 1404 effectively reflect light in all directions. The reflected light is then directed towards the elongated solar cell 402 to enhance solar cell performance.
  • surface 1610 of the reflector 1404 is an involute surface of the elongated solar cell tube 402 .
  • the elongated solar cell tube 402 is circular or near circular.
  • Reflector surface 1610 is preferably the involute of a circle (e.g. 1804 in FIG. 18A ).
  • the involute of circle 1802 is defined as the path traced out by a point on a straight line that rolls around a circle.
  • the involute of a circle can be drawn in the following steps. First, attach a string to a point on a curve. Second, extend the string so that it is tangent to the curve at the point of attachment.
  • Involute surfaces have been implemented in numerous patent designs to optimize light reflections.
  • a flash lamp reflector U.S. Pat. No. 4,641,315 to Draggoo, hereby incorporated by reference herein in its entirety
  • concave light reflector devices U.S. Pat. No. 4,641,315 to Rose, hereby incorporated by reference herein in its entirety
  • an internal reflector 1404 is connected to two elongated solar cells 402 . Details of both reflector 1404 and solar cell 402 are omitted to highlight the intrinsic relationship between the shapes of the elongated solar cell 402 and the shape of the side surface 1610 of the internal reflector 1404 . Side surfaces 1610 are constructed such that they are the involute of the circular elongated solar cell 402 .
  • the involute-evolute design imposes optimal interactions between the side surfaces 1610 of reflectors 1404 and the adjacent elongated solar cell 402 .
  • the side surface 1610 of the reflector 1404 is an involute surface corresponding to the elongated solar cell 402 that is adjacent or attached to the reflector 1404 , light reflects effectively off the involute surface in a direction that is optimized towards the elongated solar cell 402 .
  • elongated solar cells 402 are swaged at their ends such that the diameter at the ends is less than the diameter towards the center of such cells. Electrodes 440 are placed on these swaged ends.
  • elongated conductive core 404 is any of the dual layer cores described in Section 5.4.
  • back-electrode 404 is a thin layer of metal deposited on a substrate 403 as illustrated, for example, in FIG. 3B .
  • the terminal ends of elongated solar cells 402 can be stripped down to the outer core.
  • elongated solar cell 402 is constructed out of an inner core made of a cylindrical substrate 403 and an outer core (back-electrode 404 ) made of molybdenum.
  • the end of elongated solar cell 402 can be stripped down to the molybdenum back-electrode 404 and electrode 440 can be electrically connected with back-electrode 404 .
  • each internal reflector 1404 connects to two encapsulated elongated solar cells 402 (e.g., depicted as 300 in FIGS. 15 and 16 ), for example, in the manner illustrated in FIG. 16 . Because of this, elongated solar cells 402 are effectively joined into a single composite device. In FIG. 16 , electrodes 440 extend the connection from back-electrode 404 . In some embodiments, internal reflector units 1404 are connected to encapsulated solar cells 300 via indentations on transparent tubular casing 310 . In some embodiments, the indentations on transparent tubular casing 310 are created to complement the shape of the internal reflector unit 1404 .
  • Indentations on two transparent tubular casing 310 are used to lock in one internal reflector unit 1404 that is positioned between the two encapsulated solar cells 300 .
  • adhesive materials e.g., epoxy glue, are used to fortify the connections between the internal reflector unit 1404 and the adjacent encapsulated solar cell units 300 such that solar radiation is properly reflected towards the encapsulated solar cell units 300 for absorption.
  • internal reflector unit 1404 and transparent tubular casing 310 may be created in the same molding process.
  • an array of alternating transparent tubular casing 310 and astroid reflectors 1404 e.g., shown as 1900 in FIG. 19
  • the tubular casing 310 may contain internal modifications that complement the shapes of some embodiments of the solar cell 402 .

Landscapes

  • Physics & Mathematics (AREA)
  • Condensed Matter Physics & Semiconductors (AREA)
  • Electromagnetism (AREA)
  • General Physics & Mathematics (AREA)
  • Engineering & Computer Science (AREA)
  • Computer Hardware Design (AREA)
  • Microelectronics & Electronic Packaging (AREA)
  • Power Engineering (AREA)
  • Photovoltaic Devices (AREA)
US11/378,847 2006-03-18 2006-03-18 Elongated photovoltaic cells in tubular casings Abandoned US20070215195A1 (en)

Priority Applications (15)

Application Number Priority Date Filing Date Title
US11/378,847 US20070215195A1 (en) 2006-03-18 2006-03-18 Elongated photovoltaic cells in tubular casings
JP2009501465A JP2009530852A (ja) 2006-03-18 2007-03-16 ケース入長形光電池
EP07867021A EP1999798A2 (en) 2006-03-18 2007-03-16 Elongated photovoltaic cells in casings
PCT/US2007/006615 WO2008060315A2 (en) 2006-03-18 2007-03-16 Elongated photovoltaic cells in casings
KR1020087025428A KR20080112313A (ko) 2006-03-18 2007-03-16 케이싱 내의 신장된 광 전지
CN2007800180661A CN101449386B (zh) 2006-03-18 2007-03-16 壳体中的细长光伏电池
DE202007018756U DE202007018756U1 (de) 2006-03-18 2007-03-16 Längliche Photovoltaikzellen in Gehäusen
KR1020137022483A KR20130101159A (ko) 2006-03-18 2007-03-16 케이싱 내의 신장된 광 전지
US11/800,089 US20070215197A1 (en) 2006-03-18 2007-05-03 Elongated photovoltaic cells in casings
US11/821,524 US8742252B2 (en) 2006-03-18 2007-06-22 Elongated photovoltaic cells in casings with a filling layer
US12/012,462 US20080302415A1 (en) 2006-03-18 2008-02-01 Elongated photovoltaic cells in casings with a filling layer
US12/115,485 US20080302418A1 (en) 2006-03-18 2008-05-05 Elongated Photovoltaic Devices in Casings
US12/207,463 US20090007963A1 (en) 2006-03-18 2008-09-09 Elongated photovoltaic cells in casings with a filling layer
US12/235,195 US20090014055A1 (en) 2006-03-18 2008-09-22 Photovoltaic Modules Having a Filling Material
JP2013077328A JP2013175746A (ja) 2006-03-18 2013-04-03 ケース入長形光電池

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US11/378,847 US20070215195A1 (en) 2006-03-18 2006-03-18 Elongated photovoltaic cells in tubular casings

Related Parent Applications (2)

Application Number Title Priority Date Filing Date
US11/437,928 Continuation-In-Part US20100326429A1 (en) 2006-03-18 2006-05-19 Hermetically sealed cylindrical solar cells
US12/039,659 Continuation-In-Part US8183458B2 (en) 2006-03-18 2008-02-28 Photovoltaic apparatus having a filler layer and method for making the same

Related Child Applications (4)

Application Number Title Priority Date Filing Date
US11/800,089 Continuation-In-Part US20070215197A1 (en) 2006-03-18 2007-05-03 Elongated photovoltaic cells in casings
US11/821,524 Continuation US8742252B2 (en) 2006-03-18 2007-06-22 Elongated photovoltaic cells in casings with a filling layer
US12/012,462 Continuation US20080302415A1 (en) 2006-03-18 2008-02-01 Elongated photovoltaic cells in casings with a filling layer
US12/207,463 Division US20090007963A1 (en) 2006-03-18 2008-09-09 Elongated photovoltaic cells in casings with a filling layer

Publications (1)

Publication Number Publication Date
US20070215195A1 true US20070215195A1 (en) 2007-09-20

Family

ID=38516505

Family Applications (4)

Application Number Title Priority Date Filing Date
US11/378,847 Abandoned US20070215195A1 (en) 2006-03-18 2006-03-18 Elongated photovoltaic cells in tubular casings
US11/821,524 Expired - Fee Related US8742252B2 (en) 2006-03-18 2007-06-22 Elongated photovoltaic cells in casings with a filling layer
US12/012,462 Abandoned US20080302415A1 (en) 2006-03-18 2008-02-01 Elongated photovoltaic cells in casings with a filling layer
US12/207,463 Abandoned US20090007963A1 (en) 2006-03-18 2008-09-09 Elongated photovoltaic cells in casings with a filling layer

Family Applications After (3)

Application Number Title Priority Date Filing Date
US11/821,524 Expired - Fee Related US8742252B2 (en) 2006-03-18 2007-06-22 Elongated photovoltaic cells in casings with a filling layer
US12/012,462 Abandoned US20080302415A1 (en) 2006-03-18 2008-02-01 Elongated photovoltaic cells in casings with a filling layer
US12/207,463 Abandoned US20090007963A1 (en) 2006-03-18 2008-09-09 Elongated photovoltaic cells in casings with a filling layer

Country Status (7)

Country Link
US (4) US20070215195A1 (zh)
EP (1) EP1999798A2 (zh)
JP (2) JP2009530852A (zh)
KR (2) KR20080112313A (zh)
CN (1) CN101449386B (zh)
DE (1) DE202007018756U1 (zh)
WO (1) WO2008060315A2 (zh)

Cited By (39)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070215197A1 (en) * 2006-03-18 2007-09-20 Benyamin Buller Elongated photovoltaic cells in casings
US20080223442A1 (en) * 2007-03-13 2008-09-18 Beck Markus E Photovoltaic apparatus having a filler layer and method for making the same
US20090014055A1 (en) * 2006-03-18 2009-01-15 Solyndra, Inc. Photovoltaic Modules Having a Filling Material
WO2009042184A2 (en) * 2007-09-26 2009-04-02 Solyndra, Inc. Photovoltaic modules having a filling material
US20090183764A1 (en) * 2008-01-18 2009-07-23 Tenksolar, Inc Detachable Louver System
US20100218814A1 (en) * 2009-09-09 2010-09-02 International Business Machines Corporation Method of controlling the composition of a photovoltaic thin film
US20100258160A1 (en) * 2008-05-08 2010-10-14 Georgia Tech Research Corporation Fiber Optic Solar Nanogenerator Cells
US20100269907A1 (en) * 2007-12-18 2010-10-28 Plansee Metall Gmbh Thin-film solar cell having a molybdenum-containing back electrode layer
US20110000534A1 (en) * 2006-03-18 2011-01-06 Solyndra, Inc. Elongated photovoltaic cells in casings with a filling layer
US20110005275A1 (en) * 2009-07-09 2011-01-13 Reiner Bartsch Process for production of glass tubes having at least one tube end section of reduced stress
US20110028008A1 (en) * 2009-08-03 2011-02-03 Array Converter, Inc. Programmable structure for passing parameters to a controller
CN102157617A (zh) * 2011-01-31 2011-08-17 常州大学 一种硅基纳米线太阳电池的制备方法
US20110203645A1 (en) * 2008-10-31 2011-08-25 Asahi Glass Company, Limited Solar cell
US20110209746A1 (en) * 2009-09-06 2011-09-01 Hanzhong Zhang Tubular Photovoltaic Device and Method of Making
WO2011133361A1 (en) * 2010-04-21 2011-10-27 EncoreSolar, Inc. Method of fabricating solar cells with electrodeposited compound interface layers
CN102254966A (zh) * 2011-06-23 2011-11-23 上海太阳能电池研究与发展中心 具有渐变带隙结构的碲锌镉薄膜太阳能电池
CN102432965A (zh) * 2011-12-27 2012-05-02 青岛泰孚光伏科技有限责任公司 太阳能电池背板及其制备方法
US20120145227A1 (en) * 2011-02-22 2012-06-14 Jun Jinhyung Frame system for solar cell module
KR101218931B1 (ko) 2011-04-11 2013-01-21 성균관대학교산학협력단 기둥형 태양전지를 포함하는 3차원 태양전지 모듈
FR2981504A1 (fr) * 2011-10-12 2013-04-19 Julien Martin Marcel Pellat Dispositif generateur photovoltaique
US8563847B2 (en) 2009-01-21 2013-10-22 Tenksolar, Inc Illumination agnostic solar panel
US20140150847A1 (en) * 2012-11-30 2014-06-05 National Chiao Tung University Solar cell module and method of fabricating the same
US8748727B2 (en) 2008-01-18 2014-06-10 Tenksolar, Inc. Flat-plate photovoltaic module
CN103872149A (zh) * 2014-03-06 2014-06-18 明汇科技有限公司 太阳能电池保护膜及太阳能电池
US8829330B2 (en) 2010-02-23 2014-09-09 Tenksolar, Inc. Highly efficient solar arrays
US8828778B2 (en) 2008-01-18 2014-09-09 Tenksolar, Inc. Thin-film photovoltaic module
US8933320B2 (en) 2008-01-18 2015-01-13 Tenksolar, Inc. Redundant electrical architecture for photovoltaic modules
PT107895A (pt) * 2014-09-18 2016-03-18 Filipe Pires Miguel Bruno Combinado de aparelhos em engenho autónomo fotovoltaico
US9300169B1 (en) 2013-06-26 2016-03-29 Cameron M. D. Bardy Automotive roof rack with integral solar cell array
US9299861B2 (en) 2010-06-15 2016-03-29 Tenksolar, Inc. Cell-to-grid redundandt photovoltaic system
US9773933B2 (en) 2010-02-23 2017-09-26 Tenksolar, Inc. Space and energy efficient photovoltaic array
EP3125308A4 (en) * 2014-03-25 2017-11-22 Kaneka Corporation Method for manufacturing compound semiconductor solar cell
WO2017218816A1 (en) * 2016-06-16 2017-12-21 Lumen Llc Photovoltaic systems for collection of diffuse and direct sun light and systems and methods of optimizing same
US9893216B1 (en) * 2014-03-27 2018-02-13 Steven Wade Shelton Polarized light based solar cell
US9997657B2 (en) 2010-07-02 2018-06-12 3M Innovative Properties Company Barrier assembly
CN109346534A (zh) * 2018-11-23 2019-02-15 中国电子科技集团公司第四十四研究所 一种陶瓷管壳结构及其封装结构
WO2021007442A1 (en) * 2019-07-09 2021-01-14 Arizona Board Of Regents On Behalf Of Arizona State University System including a self-powered, light-based, bycatch reduction device
US20210341028A1 (en) * 2018-12-25 2021-11-04 Mt-Tec Llc Damping Material
US11930565B1 (en) * 2021-02-05 2024-03-12 Mainstream Engineering Corporation Carbon nanotube heater composite tooling apparatus and method of use

Families Citing this family (40)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20080302418A1 (en) * 2006-03-18 2008-12-11 Benyamin Buller Elongated Photovoltaic Devices in Casings
CN102017066B (zh) * 2008-03-14 2012-11-21 陶氏康宁公司 形成光伏电池模块的方法
KR20090122728A (ko) * 2008-05-26 2009-12-01 삼성전자주식회사 비선형 태양전지 모듈
WO2010044978A1 (en) * 2008-10-15 2010-04-22 Arizona Board of Regents, a body corporate acting for and on behalf of Arizona State University Hybrid group iv/iii-v semiconductor structures
US20100236614A1 (en) * 2009-02-06 2010-09-23 Los Alamos National Security, Llc Hybrid photovoltaics based on semiconductor nanocrystals and amorphous silicon
JP2010272466A (ja) * 2009-05-25 2010-12-02 Fujifilm Corp 透明導電体及びその製造方法
US20110017266A1 (en) * 2009-07-24 2011-01-27 Farrell James F Thin film photovoltaic module having a lamination layer for enhanced reflection and photovoltaic output
US20120138122A1 (en) * 2009-10-22 2012-06-07 Whitlock John P Parabolic light concentrating trough
KR101027493B1 (ko) 2009-12-28 2011-04-06 재단법인대구경북과학기술원 와이어 어레이를 이용한 태양광 전지 및 그 제조 방법
WO2011099539A1 (ja) * 2010-02-12 2011-08-18 三菱化学株式会社 太陽電池モジュール及び太陽電池モジュールの製造方法
CN102070796A (zh) * 2010-04-19 2011-05-25 孙美红 一种非金属导电材料及其制成的缓释离子型接地极
US8690066B2 (en) * 2010-04-30 2014-04-08 Axon Tubular Products, Inc. High temperature high pressure tag
DE102010036393A1 (de) 2010-07-14 2012-01-19 Sunsail Energy Gmbh & Co. Kg Hybrid-Kollektor
DE202010017250U1 (de) * 2010-11-09 2011-05-19 Dauer, Jürgen, B.A., 97070 Dreidimensionales Solarkraftwerk (DSKW)
CN102082207A (zh) * 2010-12-14 2011-06-01 英利能源（中国）有限公司 利用热收缩材料封装的光伏电池组件及其制备方法
KR101121510B1 (ko) 2011-01-12 2012-03-06 한국에너지기술연구원 원통형 태양전지 모듈, 그 제조방법 및 제조에 사용되는 라미네이터
US9647162B2 (en) 2011-01-20 2017-05-09 Colossus EPC Inc. Electronic power cell memory back-up battery
US20120187763A1 (en) 2011-01-25 2012-07-26 Isoline Component Company, Llc Electronic power supply
US20140182669A1 (en) * 2011-08-26 2014-07-03 National University Corporation Kyushu Institute Of Technology Dye-sensitized solar cell and method for manufacturing the same
CN102427069A (zh) * 2011-10-20 2012-04-25 新宝电机(东莞)有限公司 一种电路封装结构及封装方法
CN102557002B (zh) * 2011-11-29 2013-10-16 上海师范大学 一种碳纳米管/三元硫属半导体纳米复合材料及其制备方法
KR101289832B1 (ko) * 2012-03-06 2013-07-30 한주원 태양전지 및 그 제조방법
TWI501407B (zh) * 2012-04-13 2015-09-21 Univ Minghsin Sci & Tech 應用於太陽能電池之強化光吸收薄膜層及其太陽能電池結構與製作方法
KR101358857B1 (ko) * 2012-05-18 2014-02-06 최대규 태양전지
CN102738273B (zh) * 2012-07-11 2015-04-08 李富民 一种圆柱体太阳能光伏组件及其制造方法
JP2015065421A (ja) * 2013-08-28 2015-04-09 ウシオ電機株式会社 色素増感型太陽電池
US20150263205A1 (en) * 2014-03-13 2015-09-17 Tsmc Solar Ltd. Cylindrical solar module and method of making the module
CN103928545A (zh) * 2014-04-28 2014-07-16 杭州勇电照明有限公司 模块式太阳能电池板及成型方法
CN103923415A (zh) * 2014-04-28 2014-07-16 杭州勇电照明有限公司 太阳能电池模块外壳专用成形材料及制作方法
CN103928546A (zh) * 2014-04-28 2014-07-16 杭州勇电照明有限公司 浇注固化式太阳能模块及成型方法
CN103928548B (zh) * 2014-04-28 2017-07-21 杭州勇电照明有限公司 太阳能电池模块及成型方法
CN103923417A (zh) * 2014-04-28 2014-07-16 杭州勇电照明有限公司 太阳能电池模块外壳成形材料及制作方法
CN104362197B (zh) * 2014-10-23 2016-09-14 上海工程技术大学 一种立体采光式全固态太阳能电池及其制备方法
US20180151767A1 (en) * 2016-11-29 2018-05-31 Christopher Dwight Barnes Solar panel system
CN106684778A (zh) * 2016-12-16 2017-05-17 无锡市汤成机电配件厂 防滴水电线穿线管
CN106847989B (zh) * 2017-03-17 2019-04-16 南京理工大学 基于界面优化的氧化锌纳米棒阵列/聚乙烯咔唑/石墨烯杂化的纤维状紫外光探测器及方法
CN109096667B (zh) * 2018-08-17 2021-04-30 苏州星烁纳米科技有限公司 量子点膜及含有量子点膜的结构
US20220270925A1 (en) * 2019-07-22 2022-08-25 Massachusetts Institute Of Technology Flexing semiconductor structures and related techniques
US11239790B1 (en) 2020-08-01 2022-02-01 Mihai Cantemir Solar tower system
CN114420780B (zh) * 2022-03-31 2022-06-24 中国华能集团清洁能源技术研究院有限公司 一种柱式光伏组件及其制造方法

Citations (45)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2984775A (en) * 1958-07-09 1961-05-16 Hoffman Electronics Corp Ruggedized solar cell and process for making the same or the like
US3005862A (en) * 1958-09-15 1961-10-24 Int Rectifier Corp Solar battery mounting means
US3046324A (en) * 1961-01-16 1962-07-24 Hoffman Electronics Corp Alloyed photovoltaic cell and method of making the same
US3247392A (en) * 1961-05-17 1966-04-19 Optical Coating Laboratory Inc Optical coating and assembly used as a band pass interference filter reflecting in the ultraviolet and infrared
US3976508A (en) * 1974-11-01 1976-08-24 Mobil Tyco Solar Energy Corporation Tubular solar cell devices
US3991914A (en) * 1975-05-29 1976-11-16 The Risdon Manufacturing Company Easily assembled, leakproof liquid dispensing pump
US4078944A (en) * 1975-09-08 1978-03-14 Mobil Tyco Solar Energy Corporation Encapsulated solar cell assembly
US4113531A (en) * 1976-10-26 1978-09-12 Hughes Aircraft Company Process for fabricating polycrystalline inp-cds solar cells
US4217148A (en) * 1979-06-18 1980-08-12 Rca Corporation Compensated amorphous silicon solar cell
US4292092A (en) * 1980-06-02 1981-09-29 Rca Corporation Laser processing technique for fabricating series-connected and tandem junction series-connected solar cells into a solar battery
US4686323A (en) * 1986-06-30 1987-08-11 The Standard Oil Company Multiple cell, two terminal photovoltaic device employing conductively adhered cells
US4783373A (en) * 1986-04-18 1988-11-08 Optical Coating Laboratory, Inc. Article with thin film coating having an enhanced emissivity and reduced absorption of radiant energy
US4913744A (en) * 1987-01-13 1990-04-03 Helmut Hoegl Solar cell arrangement
US5437736A (en) * 1994-02-15 1995-08-01 Cole; Eric D. Semiconductor fiber solar cells and modules
US5449413A (en) * 1993-05-12 1995-09-12 Optical Coating Laboratory, Inc. UV/IR reflecting solar cell cover
US5474620A (en) * 1994-05-16 1995-12-12 United Solar Systems Corporation Cut resistant laminate for the light incident surface of a photovoltaic module
US5902416A (en) * 1993-08-27 1999-05-11 Twin Solar-Technik Entwicklungs-Gmbh Element of a photovoltaic solar cell and a process for the production thereof as well as the arrangement thereof in a solar cell
US6107564A (en) * 1997-11-18 2000-08-22 Deposition Sciences, Inc. Solar cell cover and coating
US6258620B1 (en) * 1997-10-15 2001-07-10 University Of South Florida Method of manufacturing CIGS photovoltaic devices
US6294723B2 (en) * 1998-02-26 2001-09-25 Hitachi, Ltd. Photovoltaic device, photovoltaic module and establishing method of photovoltaic system
US6355873B1 (en) * 2000-06-21 2002-03-12 Ball Semiconductor, Inc. Spherical shaped solar cell fabrication and panel assembly
US6359210B2 (en) * 1998-05-28 2002-03-19 Tecstar Power System, Inc. Solar cell having an integral monolithically grown bypass diode
US6410843B1 (en) * 1999-11-22 2002-06-25 Sanyo Electric Co., Ltd. Solar cell module
US20020130311A1 (en) * 2000-08-22 2002-09-19 Lieber Charles M. Doped elongated semiconductors, growing such semiconductors, devices including such semiconductors and fabricating such devices
US20020180909A1 (en) * 2001-03-26 2002-12-05 Lubart Neil D. Device having reflective and transmissive properties
US20030064292A1 (en) * 2001-09-12 2003-04-03 Neudecker Bernd J. Thin-film electrochemical devices on fibrous or ribbon-like substrates and method for their manufacture and design
US6548751B2 (en) * 2000-12-12 2003-04-15 Solarflex Technologies, Inc. Thin film flexible solar cell
US6555739B2 (en) * 2001-09-10 2003-04-29 Ekla-Tek, Llc Photovoltaic array and method of manufacturing same
US20030121544A1 (en) * 2000-03-02 2003-07-03 Nippon Sheet Glass Co., Ltd. Photoelectric conversion device
US6683244B2 (en) * 2000-12-07 2004-01-27 Seiko Epson Corporation Photoelectric conversion element
US6706959B2 (en) * 2000-11-24 2004-03-16 Clean Venture 21 Corporation Photovoltaic apparatus and mass-producing apparatus for mass-producing spherical semiconductor particles
US6706963B2 (en) * 2002-01-25 2004-03-16 Konarka Technologies, Inc. Photovoltaic cell interconnection
US20040063320A1 (en) * 2002-09-30 2004-04-01 Hollars Dennis R. Manufacturing apparatus and method for large-scale production of thin-film solar cells
US6762359B2 (en) * 2001-01-15 2004-07-13 Fuji Machine Mfg. Co., Ltd. Photovoltaic panel and method of producing same
US6806414B2 (en) * 2001-05-09 2004-10-19 Canon Kabushiki Kaisha Photovoltaic elements
US20050040374A1 (en) * 2002-01-25 2005-02-24 Konarka Technologies, Inc. Photovoltaic fibers
US20050098202A1 (en) * 2003-11-10 2005-05-12 Maltby Robert E.Jr. Non-planar photocell
US6940008B2 (en) * 1998-02-05 2005-09-06 Canon Kabushiki Kaisha Semiconductor device, solar cell module, and methods for their dismantlement
US20060086384A1 (en) * 2002-06-21 2006-04-27 Josuke Nakata Light receiving or light emitting device and itsd production method
US7094452B2 (en) * 2002-03-25 2006-08-22 Sanyo Electric Co., Ltd. Antireflective member and electronic equipment using same
US20060185714A1 (en) * 2005-02-05 2006-08-24 Samsung Electronics Co., Ltd. Flexible solar cell and method of producing the same
US20070079864A1 (en) * 2005-10-11 2007-04-12 Gronet Chris M Bifacial elongated solar cell devices with internal reflectors
US7235736B1 (en) * 2006-03-18 2007-06-26 Solyndra, Inc. Monolithic integration of cylindrical solar cells
US20070215197A1 (en) * 2006-03-18 2007-09-20 Benyamin Buller Elongated photovoltaic cells in casings
US20090007963A1 (en) * 2006-03-18 2009-01-08 Solyndra, Inc. Elongated photovoltaic cells in casings with a filling layer

Family Cites Families (79)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US237168A (en) 1881-02-01 carpenter
US2807587A (en) 1952-08-27 1957-09-24 Sylvania Electric Prod Blue electroluminescent zinc sulfide phosphors
US2985775A (en) 1959-10-29 1961-05-23 Gen Electric Electronic switch with comparator
US3031416A (en) 1959-11-16 1962-04-24 Sylvania Electric Prod White emitting electroluminescent phosphor mixture
US3031415A (en) 1959-11-16 1962-04-24 Sylvania Electric Prod Electroluminescent phosphor and process for making same
US3152995A (en) 1960-07-12 1964-10-13 Sylvania Electric Prod Process for increasing the brightness of electroluminescent phosphors
US3222214A (en) 1961-09-05 1965-12-07 Sylvania Electric Prod Method of preparing electroluminescent devices
FR1367478A (fr) * 1963-04-11 1964-07-24 Rhone Poulenc Sa Nouveau procédé de fabrication de granulés d'alcool polyvinylique
US3657142A (en) 1971-04-19 1972-04-18 Stanley M Poss Zinc sulfide phosphors
US3990914A (en) * 1974-09-03 1976-11-09 Sensor Technology, Inc. Tubular solar cell
FR2327643A1 (fr) 1975-10-09 1977-05-06 Commissariat Energie Atomique Convertisseur d'energie lumineuse en energie electrique
US4170507A (en) * 1977-12-27 1979-10-09 Motorola, Inc. Method for encapsulating a solar cell array
JPS58151071A (ja) 1982-03-02 1983-09-08 Toppan Printing Co Ltd 太陽電池
JPS58158976A (ja) 1982-03-16 1983-09-21 Toppan Printing Co Ltd 太陽エネルギ−変換装置
DE3209548A1 (de) 1982-03-16 1983-10-20 Siemens AG, 1000 Berlin und 8000 München Solarzellenanordnung in duennschichtbauweise aus halbleitermaterial sowie verfahren zu ihrer herstellung
JPS5947773A (ja) * 1982-09-10 1984-03-17 Sanyo Electric Co Ltd 太陽エネルギ−変換装置
JPS59125670A (ja) 1983-01-06 1984-07-20 Toppan Printing Co Ltd 太陽電池
JPS59143377A (ja) 1983-02-05 1984-08-16 Toyobo Co Ltd 糸状太陽電池
JPS59144177A (ja) 1983-02-07 1984-08-18 Seiko Epson Corp 太陽電池
US4461922A (en) * 1983-02-14 1984-07-24 Atlantic Richfield Company Solar cell module
EP0140917A1 (fr) 1983-04-25 1985-05-15 Institut De Microtechnique Cellule photovoltaique de grande surface et son procede de fabrication
JPS6038490A (ja) 1983-08-11 1985-02-28 Toshiba Corp 白色発光混合螢光体及びこれを用いた陰極線管
JPS60187066A (ja) * 1984-03-07 1985-09-24 Fuji Electric Co Ltd 太陽電池
US4641315A (en) 1984-12-20 1987-02-03 The Boeing Company Modified involute flashlamp reflector
JPS6312686A (ja) 1986-07-04 1988-01-20 Toshiba Corp 陰極線管
US4988342A (en) 1987-03-02 1991-01-29 Atrium Medical Corporation Improved fluid recovery system
US4859361A (en) 1988-05-13 1989-08-22 Gte Products Corporation Process for producing electroluminescent phosphors of improved brightness
JP3256587B2 (ja) 1992-02-21 2002-02-12 株式会社東芝 高熱伝導性放熱体およびその製造方法
US5269966A (en) 1992-12-31 1993-12-14 Osram Sylvania Inc. Method of making zinc sulfide precursor material for a copper-activated zinc sulfide electroluminescent phosphor
JPH07120072A (ja) 1993-09-03 1995-05-12 Maruyoshi:Kk 太陽光変換装置
DE4339547A1 (de) 1993-11-19 1995-05-24 Twin Solar Technik Entwicklung Verfahren zur photovoltaischen Herstellung von Elektrizität mittels Solarzellen sowie Vorrichtung zu dessen Durchführung
DE4343514A1 (de) 1993-12-20 1995-06-22 Peter Pelz Solarmodul - bestücktes Dach- oder Wandelement, z. B. Dachziegel
DE4406760A1 (de) 1994-03-02 1995-09-07 Twin Solar Technik Entwicklung Lichtdurchlässiges photovoltaisches Solarzellenmodul
US5468988A (en) * 1994-03-04 1995-11-21 United Solar Systems Corporation Large area, through-hole, parallel-connected photovoltaic device
KR100209698B1 (ko) 1996-10-11 1999-07-15 구본준 유기 반사방지막 식각방법
JPH10298547A (ja) 1997-04-23 1998-11-10 Sony Corp 陰極線管及び青色蛍光体
JP3740251B2 (ja) * 1997-06-09 2006-02-01 キヤノン株式会社 太陽電池モジュールの製造方法
DE19732876A1 (de) 1997-07-30 1999-02-04 Reitstall Icking Gmbh Photovoltaische Solarzellenanordnung
JPH11103085A (ja) 1997-09-29 1999-04-13 Shin Etsu Polymer Co Ltd 太陽電池とその製造方法及び太陽電池ユニット
US6004722A (en) 1998-04-06 1999-12-21 Chartered Semiconductor Manufacturing Ltd. Hydrolytically stable organic polymer material for organic polymer anti-reflective (ARC) layer
US6221776B1 (en) 1998-05-05 2001-04-24 Cypress Semiconductor Corp. Anti-reflective coating used as a disposable etch stop
US6294459B1 (en) 1998-09-03 2001-09-25 Micron Technology, Inc. Anti-reflective coatings and methods for forming and using same
US6661521B1 (en) 1998-09-11 2003-12-09 Robotic Vision Systems, Inc. Diffuse surface illumination apparatus and methods
US6635583B2 (en) 1998-10-01 2003-10-21 Applied Materials, Inc. Silicon carbide deposition for use as a low-dielectric constant anti-reflective coating
JP2000174299A (ja) 1998-12-07 2000-06-23 Bridgestone Corp 太陽電池用カバー材、封止膜及び太陽電池
WO2000035025A1 (fr) 1998-12-07 2000-06-15 Bridgestone Corporation Revetement pour cellule solaire film d'etancheite et cellule solaire
US6713234B2 (en) 1999-02-18 2004-03-30 Micron Technology, Inc. Fabrication of semiconductor devices using anti-reflective coatings
JP2000294821A (ja) * 1999-04-01 2000-10-20 Sentaro Sugita 光発電素子、並びに、ソーラーセル
KR100315225B1 (ko) 1999-05-11 2001-11-26 김순택 저전압용 분홍색 형광체
US6257737B1 (en) 1999-05-20 2001-07-10 Philips Electronics Na Low-profile luminaire having a reflector for mixing light from a multi-color linear array of LEDs
JP3932008B2 (ja) 1999-06-18 2007-06-20 富士電機ホールディングス株式会社 太陽電池モジュール
EP1264298B1 (en) 2000-03-06 2007-01-03 Teledyne Lighting and Display Products, Inc. Led light source with field-of-view-controlling optics
JP4117871B2 (ja) 2000-11-09 2008-07-16 東京応化工業株式会社 反射防止膜形成用組成物
US6661167B2 (en) * 2001-03-14 2003-12-09 Gelcore Llc LED devices
US6498290B1 (en) * 2001-05-29 2002-12-24 The Sun Trust, L.L.C. Conversion of solar energy
US20040023253A1 (en) 2001-06-11 2004-02-05 Sandeep Kunwar Device structure for closely spaced electrodes
US6538191B1 (en) * 2001-09-26 2003-03-25 Biomed Solutions, Llc Photocell with fluorescent conversion layer
KR100465866B1 (ko) 2001-10-26 2005-01-13 주식회사 하이닉스반도체 유기반사방지막 조성물 및 그의 제조방법
JP4055053B2 (ja) * 2002-03-26 2008-03-05 本田技研工業株式会社 化合物薄膜太陽電池およびその製造方法
US6988925B2 (en) 2002-05-21 2006-01-24 Eikos, Inc. Method for patterning carbon nanotube coating and carbon nanotube wiring
US6660930B1 (en) * 2002-06-12 2003-12-09 Rwe Schott Solar, Inc. Solar cell modules with improved backskin
JP4271433B2 (ja) 2002-12-05 2009-06-03 昭和シェル石油株式会社 Ｃｉｓ系薄膜太陽電池モジュールの構成部材回収方法
JP2004293118A (ja) 2003-03-26 2004-10-21 Matsushita Electric Works Ltd 瓦一体型太陽電池パネルの構造
US6936761B2 (en) 2003-03-29 2005-08-30 Nanosolar, Inc. Transparent electrode, optoelectronic apparatus and devices
AU2003901559A0 (en) * 2003-04-07 2003-05-01 Unisearch Limited Glass texturing method
EP1614165A2 (fr) * 2003-04-16 2006-01-11 Apollon Solar MODULE PHOTOVOLTAIQUE ET PROCEDE DE FABRICATION D’UN TEL MODULE
WO2005015678A1 (ja) * 2003-08-06 2005-02-17 Fujikura Ltd. 光電変換素子およびその製造方法
JP2005099693A (ja) 2003-09-05 2005-04-14 Hitachi Chem Co Ltd 反射防止膜形成用組成物及びそれを用いた反射防止膜の製造方法、光学部品、太陽電池ユニット
JP4609856B2 (ja) 2003-09-19 2011-01-12 古河電気工業株式会社 一次元太陽電池、太陽電池モジュール、および、太陽電池発電システム
EP1521308A1 (de) 2003-10-02 2005-04-06 Scheuten Glasgroep Kugel- oder kornförmiges Halbleiterbauelement zur Verwendung in Solarzellen und Verfahren zur Herstellung; Verfahren zur Herstellung einer Solarzelle mit Halbleiterbauelement und Solarzelle
US7122398B1 (en) * 2004-03-25 2006-10-17 Nanosolar, Inc. Manufacturing of optoelectronic devices
KR20070004787A (ko) * 2004-03-31 2007-01-09 로무 가부시키가이샤 적층형 박막 태양전지 및 그 방법
JP2006080396A (ja) 2004-09-10 2006-03-23 Sharp Corp 光電変換素子
WO2006034540A1 (en) * 2004-09-27 2006-04-06 Gallium Enterprises Pty Ltd Method and apparatus for growing a group (iii) metal nitride film and a group (iii) metal nitride film
KR100661116B1 (ko) * 2004-11-22 2006-12-22 가부시키가이샤후지쿠라 전극, 광전 변환 소자 및 색소 증감 태양 전지
WO2007002110A2 (en) 2005-06-20 2007-01-04 Solyndra, Inc. Bifacial elonagated solar cell devices
US8183458B2 (en) 2007-03-13 2012-05-22 Solyndra Llc Photovoltaic apparatus having a filler layer and method for making the same
US20080047599A1 (en) * 2006-03-18 2008-02-28 Benyamin Buller Monolithic integration of nonplanar solar cells
EP2203942A2 (en) 2007-09-26 2010-07-07 Solyndra, Inc. Photovoltaic modules having a filling material

Patent Citations (45)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2984775A (en) * 1958-07-09 1961-05-16 Hoffman Electronics Corp Ruggedized solar cell and process for making the same or the like
US3005862A (en) * 1958-09-15 1961-10-24 Int Rectifier Corp Solar battery mounting means
US3046324A (en) * 1961-01-16 1962-07-24 Hoffman Electronics Corp Alloyed photovoltaic cell and method of making the same
US3247392A (en) * 1961-05-17 1966-04-19 Optical Coating Laboratory Inc Optical coating and assembly used as a band pass interference filter reflecting in the ultraviolet and infrared
US3976508A (en) * 1974-11-01 1976-08-24 Mobil Tyco Solar Energy Corporation Tubular solar cell devices
US3991914A (en) * 1975-05-29 1976-11-16 The Risdon Manufacturing Company Easily assembled, leakproof liquid dispensing pump
US4078944A (en) * 1975-09-08 1978-03-14 Mobil Tyco Solar Energy Corporation Encapsulated solar cell assembly
US4113531A (en) * 1976-10-26 1978-09-12 Hughes Aircraft Company Process for fabricating polycrystalline inp-cds solar cells
US4217148A (en) * 1979-06-18 1980-08-12 Rca Corporation Compensated amorphous silicon solar cell
US4292092A (en) * 1980-06-02 1981-09-29 Rca Corporation Laser processing technique for fabricating series-connected and tandem junction series-connected solar cells into a solar battery
US4783373A (en) * 1986-04-18 1988-11-08 Optical Coating Laboratory, Inc. Article with thin film coating having an enhanced emissivity and reduced absorption of radiant energy
US4686323A (en) * 1986-06-30 1987-08-11 The Standard Oil Company Multiple cell, two terminal photovoltaic device employing conductively adhered cells
US4913744A (en) * 1987-01-13 1990-04-03 Helmut Hoegl Solar cell arrangement
US5449413A (en) * 1993-05-12 1995-09-12 Optical Coating Laboratory, Inc. UV/IR reflecting solar cell cover
US5902416A (en) * 1993-08-27 1999-05-11 Twin Solar-Technik Entwicklungs-Gmbh Element of a photovoltaic solar cell and a process for the production thereof as well as the arrangement thereof in a solar cell
US5437736A (en) * 1994-02-15 1995-08-01 Cole; Eric D. Semiconductor fiber solar cells and modules
US5474620A (en) * 1994-05-16 1995-12-12 United Solar Systems Corporation Cut resistant laminate for the light incident surface of a photovoltaic module
US6258620B1 (en) * 1997-10-15 2001-07-10 University Of South Florida Method of manufacturing CIGS photovoltaic devices
US6107564A (en) * 1997-11-18 2000-08-22 Deposition Sciences, Inc. Solar cell cover and coating
US6940008B2 (en) * 1998-02-05 2005-09-06 Canon Kabushiki Kaisha Semiconductor device, solar cell module, and methods for their dismantlement
US6294723B2 (en) * 1998-02-26 2001-09-25 Hitachi, Ltd. Photovoltaic device, photovoltaic module and establishing method of photovoltaic system
US6359210B2 (en) * 1998-05-28 2002-03-19 Tecstar Power System, Inc. Solar cell having an integral monolithically grown bypass diode
US6410843B1 (en) * 1999-11-22 2002-06-25 Sanyo Electric Co., Ltd. Solar cell module
US20030121544A1 (en) * 2000-03-02 2003-07-03 Nippon Sheet Glass Co., Ltd. Photoelectric conversion device
US6355873B1 (en) * 2000-06-21 2002-03-12 Ball Semiconductor, Inc. Spherical shaped solar cell fabrication and panel assembly
US20020130311A1 (en) * 2000-08-22 2002-09-19 Lieber Charles M. Doped elongated semiconductors, growing such semiconductors, devices including such semiconductors and fabricating such devices
US6706959B2 (en) * 2000-11-24 2004-03-16 Clean Venture 21 Corporation Photovoltaic apparatus and mass-producing apparatus for mass-producing spherical semiconductor particles
US6683244B2 (en) * 2000-12-07 2004-01-27 Seiko Epson Corporation Photoelectric conversion element
US6548751B2 (en) * 2000-12-12 2003-04-15 Solarflex Technologies, Inc. Thin film flexible solar cell
US6762359B2 (en) * 2001-01-15 2004-07-13 Fuji Machine Mfg. Co., Ltd. Photovoltaic panel and method of producing same
US20020180909A1 (en) * 2001-03-26 2002-12-05 Lubart Neil D. Device having reflective and transmissive properties
US6806414B2 (en) * 2001-05-09 2004-10-19 Canon Kabushiki Kaisha Photovoltaic elements
US6555739B2 (en) * 2001-09-10 2003-04-29 Ekla-Tek, Llc Photovoltaic array and method of manufacturing same
US20030064292A1 (en) * 2001-09-12 2003-04-03 Neudecker Bernd J. Thin-film electrochemical devices on fibrous or ribbon-like substrates and method for their manufacture and design
US6706963B2 (en) * 2002-01-25 2004-03-16 Konarka Technologies, Inc. Photovoltaic cell interconnection
US20050040374A1 (en) * 2002-01-25 2005-02-24 Konarka Technologies, Inc. Photovoltaic fibers
US7094452B2 (en) * 2002-03-25 2006-08-22 Sanyo Electric Co., Ltd. Antireflective member and electronic equipment using same
US20060086384A1 (en) * 2002-06-21 2006-04-27 Josuke Nakata Light receiving or light emitting device and itsd production method
US20040063320A1 (en) * 2002-09-30 2004-04-01 Hollars Dennis R. Manufacturing apparatus and method for large-scale production of thin-film solar cells
US20050098202A1 (en) * 2003-11-10 2005-05-12 Maltby Robert E.Jr. Non-planar photocell
US20060185714A1 (en) * 2005-02-05 2006-08-24 Samsung Electronics Co., Ltd. Flexible solar cell and method of producing the same
US20070079864A1 (en) * 2005-10-11 2007-04-12 Gronet Chris M Bifacial elongated solar cell devices with internal reflectors
US7235736B1 (en) * 2006-03-18 2007-06-26 Solyndra, Inc. Monolithic integration of cylindrical solar cells
US20070215197A1 (en) * 2006-03-18 2007-09-20 Benyamin Buller Elongated photovoltaic cells in casings
US20090007963A1 (en) * 2006-03-18 2009-01-08 Solyndra, Inc. Elongated photovoltaic cells in casings with a filling layer

Cited By (59)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070215197A1 (en) * 2006-03-18 2007-09-20 Benyamin Buller Elongated photovoltaic cells in casings
US20090014055A1 (en) * 2006-03-18 2009-01-15 Solyndra, Inc. Photovoltaic Modules Having a Filling Material
US8742252B2 (en) 2006-03-18 2014-06-03 Solyndra, Llc Elongated photovoltaic cells in casings with a filling layer
US20110000534A1 (en) * 2006-03-18 2011-01-06 Solyndra, Inc. Elongated photovoltaic cells in casings with a filling layer
US20080223442A1 (en) * 2007-03-13 2008-09-18 Beck Markus E Photovoltaic apparatus having a filler layer and method for making the same
US8183458B2 (en) * 2007-03-13 2012-05-22 Solyndra Llc Photovoltaic apparatus having a filler layer and method for making the same
US8674213B2 (en) 2007-03-13 2014-03-18 Solyndra, Llc Photovoltaic apparatus having a filler layer and method for making the same
WO2009042184A2 (en) * 2007-09-26 2009-04-02 Solyndra, Inc. Photovoltaic modules having a filling material
WO2009042184A3 (en) * 2007-09-26 2009-08-06 Solyndra Inc Photovoltaic modules having a filling material
US20100269907A1 (en) * 2007-12-18 2010-10-28 Plansee Metall Gmbh Thin-film solar cell having a molybdenum-containing back electrode layer
US20090183764A1 (en) * 2008-01-18 2009-07-23 Tenksolar, Inc Detachable Louver System
US8933320B2 (en) 2008-01-18 2015-01-13 Tenksolar, Inc. Redundant electrical architecture for photovoltaic modules
US8828778B2 (en) 2008-01-18 2014-09-09 Tenksolar, Inc. Thin-film photovoltaic module
US8748727B2 (en) 2008-01-18 2014-06-10 Tenksolar, Inc. Flat-plate photovoltaic module
US9768725B2 (en) 2008-01-18 2017-09-19 Tenksolar, Inc. Redundant electrical architecture for photovoltaic modules
US20100258160A1 (en) * 2008-05-08 2010-10-14 Georgia Tech Research Corporation Fiber Optic Solar Nanogenerator Cells
US8664523B2 (en) * 2008-05-08 2014-03-04 Georgia Tech Research Corporation Fiber optic solar nanogenerator cells
US20110203645A1 (en) * 2008-10-31 2011-08-25 Asahi Glass Company, Limited Solar cell
US9543890B2 (en) 2009-01-21 2017-01-10 Tenksolar, Inc. Illumination agnostic solar panel
US8563847B2 (en) 2009-01-21 2013-10-22 Tenksolar, Inc Illumination agnostic solar panel
US20110005275A1 (en) * 2009-07-09 2011-01-13 Reiner Bartsch Process for production of glass tubes having at least one tube end section of reduced stress
DE102010017731B4 (de) * 2009-07-09 2012-05-03 Schott Ag Verfahren zur Herstellung von Glasrohren mit zumindest einem Rohrendabschnitt reduzierter Spannung
DE102010017731A1 (de) 2009-07-09 2011-01-20 Schott Ag Verfahren zur Herstellung von Glasrohren mit zumindest einem Rohrendabschnitt reduzierter Spannung
US8474285B2 (en) 2009-07-09 2013-07-02 Schott Ag Process for production of glass tubes having at least one tube end section of reduced stress
US20110028008A1 (en) * 2009-08-03 2011-02-03 Array Converter, Inc. Programmable structure for passing parameters to a controller
WO2011016949A1 (en) * 2009-08-03 2011-02-10 Array Converter, Inc. Programmable structure for passing parameters to a controller
US20110209746A1 (en) * 2009-09-06 2011-09-01 Hanzhong Zhang Tubular Photovoltaic Device and Method of Making
US7923628B2 (en) * 2009-09-09 2011-04-12 International Business Machines Corporation Method of controlling the composition of a photovoltaic thin film
US20100218814A1 (en) * 2009-09-09 2010-09-02 International Business Machines Corporation Method of controlling the composition of a photovoltaic thin film
US9773933B2 (en) 2010-02-23 2017-09-26 Tenksolar, Inc. Space and energy efficient photovoltaic array
US8829330B2 (en) 2010-02-23 2014-09-09 Tenksolar, Inc. Highly efficient solar arrays
US8580603B2 (en) 2010-04-21 2013-11-12 EncoreSolar, Inc. Method of fabricating solar cells with electrodeposited compound interface layers
WO2011133361A1 (en) * 2010-04-21 2011-10-27 EncoreSolar, Inc. Method of fabricating solar cells with electrodeposited compound interface layers
US9299861B2 (en) 2010-06-15 2016-03-29 Tenksolar, Inc. Cell-to-grid redundandt photovoltaic system
US10038111B2 (en) 2010-07-02 2018-07-31 3M Innovative Properties Company Barrier assembly with encapsulant and photovoltaic cell
US9997657B2 (en) 2010-07-02 2018-06-12 3M Innovative Properties Company Barrier assembly
US10693024B2 (en) 2010-07-02 2020-06-23 3M Innovative Properties Company Barrier assembly
CN102157617A (zh) * 2011-01-31 2011-08-17 常州大学 一种硅基纳米线太阳电池的制备方法
US20120145227A1 (en) * 2011-02-22 2012-06-14 Jun Jinhyung Frame system for solar cell module
US10316879B2 (en) * 2011-02-22 2019-06-11 Lg Electronics Inc. Frame system for solar cell module
KR101218931B1 (ko) 2011-04-11 2013-01-21 성균관대학교산학협력단 기둥형 태양전지를 포함하는 3차원 태양전지 모듈
CN102254966A (zh) * 2011-06-23 2011-11-23 上海太阳能电池研究与发展中心 具有渐变带隙结构的碲锌镉薄膜太阳能电池
FR2981504A1 (fr) * 2011-10-12 2013-04-19 Julien Martin Marcel Pellat Dispositif generateur photovoltaique
CN102432965A (zh) * 2011-12-27 2012-05-02 青岛泰孚光伏科技有限责任公司 太阳能电池背板及其制备方法
US20140150847A1 (en) * 2012-11-30 2014-06-05 National Chiao Tung University Solar cell module and method of fabricating the same
US9300169B1 (en) 2013-06-26 2016-03-29 Cameron M. D. Bardy Automotive roof rack with integral solar cell array
CN103872149A (zh) * 2014-03-06 2014-06-18 明汇科技有限公司 太阳能电池保护膜及太阳能电池
US9893228B2 (en) 2014-03-25 2018-02-13 Kaneka Corporation Method for manufacturing compound semiconductor solar cell
EP3125308A4 (en) * 2014-03-25 2017-11-22 Kaneka Corporation Method for manufacturing compound semiconductor solar cell
US9893216B1 (en) * 2014-03-27 2018-02-13 Steven Wade Shelton Polarized light based solar cell
US20180212075A1 (en) * 2014-03-27 2018-07-26 Steven Wade Shelton Polarized light based solar cell
PT107895A (pt) * 2014-09-18 2016-03-18 Filipe Pires Miguel Bruno Combinado de aparelhos em engenho autónomo fotovoltaico
WO2017218816A1 (en) * 2016-06-16 2017-12-21 Lumen Llc Photovoltaic systems for collection of diffuse and direct sun light and systems and methods of optimizing same
CN109346534A (zh) * 2018-11-23 2019-02-15 中国电子科技集团公司第四十四研究所 一种陶瓷管壳结构及其封装结构
US20210341028A1 (en) * 2018-12-25 2021-11-04 Mt-Tec Llc Damping Material
US11959525B2 (en) * 2018-12-25 2024-04-16 Kotobukiya Fronte Co., Ltd. Damping material
WO2021007442A1 (en) * 2019-07-09 2021-01-14 Arizona Board Of Regents On Behalf Of Arizona State University System including a self-powered, light-based, bycatch reduction device
US20220248648A1 (en) * 2019-07-09 2022-08-11 Mark Bailly System including a self-powered, light based, bycatch reduction device
US11930565B1 (en) * 2021-02-05 2024-03-12 Mainstream Engineering Corporation Carbon nanotube heater composite tooling apparatus and method of use

Also Published As

Publication number Publication date
WO2008060315A2 (en) 2008-05-22
US20080302415A1 (en) 2008-12-11
CN101449386A (zh) 2009-06-03
JP2013175746A (ja) 2013-09-05
US20110000534A1 (en) 2011-01-06
JP2009530852A (ja) 2009-08-27
EP1999798A2 (en) 2008-12-10
WO2008060315A3 (en) 2008-11-06
KR20080112313A (ko) 2008-12-24
KR20130101159A (ko) 2013-09-12
US8742252B2 (en) 2014-06-03
US20090007963A1 (en) 2009-01-08
DE202007018756U1 (de) 2009-03-26
CN101449386B (zh) 2013-06-19

Similar Documents

Publication Publication Date Title
US8742252B2 (en) Elongated photovoltaic cells in casings with a filling layer
US20070215197A1 (en) Elongated photovoltaic cells in casings
US20080302418A1 (en) Elongated Photovoltaic Devices in Casings
US20090014055A1 (en) Photovoltaic Modules Having a Filling Material
US7259322B2 (en) Interconnects for solar cell devices
US7394016B2 (en) Bifacial elongated solar cell devices with internal reflectors
US20100326429A1 (en) Hermetically sealed cylindrical solar cells
US20100132765A1 (en) Hermetically sealed solar cells
US8710361B2 (en) Volume compensation within a photovoltaic device
WO2007002110A2 (en) Bifacial elonagated solar cell devices
US20100300532A1 (en) Hermetically sealed nonplanar solar cells
US8093493B2 (en) Volume compensation within a photovoltaic device
US20070227579A1 (en) Assemblies of cylindrical solar units with internal spacing
US20070240760A1 (en) Methods for manufacturing solar cells
US20100255628A1 (en) Scribing methods for photovoltaic modules including a mechanical scribe
WO2009042184A2 (en) Photovoltaic modules having a filling material
US20100147367A1 (en) Volume Compensation Within a Photovoltaic Device

Legal Events

Date Code Title Description
AS Assignment

Owner name: SOLYNDRA, INC., CALIFORNIA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:BULLER, BENYAMIN;GRONET CHRIS M.;MORAD, RATSON;AND OTHERS;REEL/FRAME:017822/0097

Effective date: 20060425

AS Assignment

Owner name: HSH NORDBANK AG, NEW YORK BRANCH, AS COLLATERAL AG

Free format text: SECURITY AGREEMENT;ASSIGNOR:SOLYNDRA, INC.;REEL/FRAME:019229/0936

Effective date: 20070406

AS Assignment

Owner name: SOLYNDRA, INC., CALIFORNIA

Free format text: TERMINATION OF SECURITY INTEREST IN PATENTS;ASSIGNOR:HSH NORDBANK AG, NEW YORK BRANCH;REEL/FRAME:022678/0278

Effective date: 20090430

AS Assignment

Owner name: ARGONAUT VENTURES I, L.L.C.,OKLAHOMA

Free format text: SECURITY AGREEMENT;ASSIGNOR:SOLYNDRA, INC.;REEL/FRAME:024547/0671

Effective date: 20100617

Owner name: ARGONAUT VENTURES I, L.L.C., OKLAHOMA

Free format text: SECURITY AGREEMENT;ASSIGNOR:SOLYNDRA, INC.;REEL/FRAME:024547/0671

Effective date: 20100617

AS Assignment

Owner name: SOLYNDRA LLC, CALIFORNIA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:SOLYNDRA, INC.;REEL/FRAME:025847/0962

Effective date: 20110223

AS Assignment

Owner name: U.S. BANK NATIONAL ASSOCIATION, NEW YORK

Free format text: SECURITY AGREEMENT;ASSIGNOR:SOLYNDRA LLC (FORMERLY KNOWN AS SOLYNDRA FAB 2 LLC);REEL/FRAME:025881/0712

Effective date: 20110223

AS Assignment

Owner name: U.S. BANK NATIONAL ASSOCIATION, NEW YORK

Free format text: SECURITY AGREEMENT;ASSIGNOR:SOLYNDRA LLC;REEL/FRAME:025919/0070

Effective date: 20110223

AS Assignment

Owner name: SOLYNDRA RESIDUAL TRUST, CALIFORNIA

Free format text: ORDER CONFIRMING DEBTOR'S AMENDED JOINT CHAPTER 11 PLAN;ASSIGNOR:SOLYNDRA LLC;REEL/FRAME:031424/0748

Effective date: 20121022

Owner name: SOLYNDRA RESIDUAL TRUST, CALIFORNIA

Free format text: BANKRUPTCY COURT/ORDER CONFIRMING DEBTORS' AMENDED JOINT CHAPTER 11 PLAN;ASSIGNOR:SOLYNDRA LLC;REEL/FRAME:031693/0147

Effective date: 20121022

AS Assignment

Owner name: SOLYNDRA RESIDUAL TRUST, CALIFORNIA

Free format text: ORDER CONFIRMING DEBTOR'S AMENDED JOINT CHAPTER 11 PLAN;ASSIGNOR:SOLYNDRA LLC;REEL/FRAME:031448/0645

Effective date: 20121022

STCB Information on status: application discontinuation

Free format text: ABANDONED -- AFTER EXAMINER'S ANSWER OR BOARD OF APPEALS DECISION