EP2359455A2 - Systèmes et procédés d utilisation d un convertisseur de puissance pour la transmission de données sur l alimentation - Google Patents

Systèmes et procédés d utilisation d un convertisseur de puissance pour la transmission de données sur l alimentation

Info

Publication number
EP2359455A2
EP2359455A2 EP09829627A EP09829627A EP2359455A2 EP 2359455 A2 EP2359455 A2 EP 2359455A2 EP 09829627 A EP09829627 A EP 09829627A EP 09829627 A EP09829627 A EP 09829627A EP 2359455 A2 EP2359455 A2 EP 2359455A2
Authority
EP
European Patent Office
Prior art keywords
local management
management unit
string
voltage
module
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.)
Withdrawn
Application number
EP09829627A
Other languages
German (de)
English (en)
Inventor
Ron Hadar
Shmuel Arditi
Mordechay Avrustky
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.)
Tigo Energy Inc
Original Assignee
Tigo Energy 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
Priority claimed from US12/411,317 external-priority patent/US7602080B1/en
Application filed by Tigo Energy Inc filed Critical Tigo Energy Inc
Publication of EP2359455A2 publication Critical patent/EP2359455A2/fr
Withdrawn legal-status Critical Current

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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
    • H01L31/02—Details
    • H01L31/02016—Circuit arrangements of general character for the devices
    • H01L31/02019—Circuit arrangements of general character for the devices for devices characterised by at least one potential jump barrier or surface barrier
    • H01L31/02021—Circuit arrangements of general character for the devices for devices characterised by at least one potential jump barrier or surface barrier for solar cells
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B3/00—Line transmission systems
    • H04B3/54—Systems for transmission via power distribution lines
    • H04B3/548—Systems for transmission via power distribution lines the power on the line being DC
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B2203/00—Indexing scheme relating to line transmission systems
    • H04B2203/54—Aspects of powerline communications not already covered by H04B3/54 and its subgroups
    • H04B2203/5429—Applications for powerline communications
    • H04B2203/5458—Monitor sensor; Alarm systems
    • 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

Definitions

  • At least some embodiments of the disclosure relate to photovoltaic systems in general, and more particularly but not limited to, improving the energy production performance of photovoltaic systems.
  • the signal carrier frequency should not exceed 500 kHz, so as to avoid the antenna effects, and avoid excessive signal attenuation and unintentional electromagnetic radiation.
  • Power line carrier frequency is typically between 90 kHz and 490 kHz for small power line network line for, for example, a residence.
  • a larger commercial power line installation must further limit the maximum carrier frequency so that the effective length of the wires does not exceed 1 Zs of the carrier wave length.
  • Low carrier frequency in turn means that the rate of signal than can be modulated on such a carrier is also very low, so that a certain payload to carrier ratio is maintained.
  • the signal rate that can be carrier by a frequency is also limited by severe noise and attenuation typical to power lines. This is because the slower the signal rate, the more energy is carrier by a single symbol (bit), and with more energy in a bit, the less likely it is to be corrupted in transmission.
  • the narrowband power line communication products can be further divided into two types: the solutions involving a single or dual carrier tones and the newer solutions mostly involving a kind of spread spectrum technique involving a large number of carrier tones or a digitally synthesized equivalent.
  • Solar system installers take a large guard band (or safety margin) to make sure the voltages don't cross the 600V or 1000V limits in the United States and the European Union, respectively. That limitation inhibits them from installing more solar panel modules, often referred to as "modules" or "panels,” in series to reduce the cost of combiner boxes or string inverters.
  • modules When solar modules are connected in series or in mesh configurations, there can be a problem in which weaker modules not only produce less energy but also affect other modules' capabilities to deliver energy in the same string or wiring section.
  • apparatuses and methods include a photovoltaic energy production unit to generate electricity.
  • a local management unit is coupled between the photovoltaic energy production unit and a connection of energy production units forming a string bus.
  • the local management unit includes a controller and switching circuitry.
  • the controller provide a control for the switching circuitry to deliver electrical energy to the string bus.
  • a communication transmission modulator is associated with the local management unit. The communication transmission modulator modulates the control with data to be transmitted from the local management unit over the string bus.
  • Figures 1 - 3A illustrate local management units according to some embodiments.
  • Figure 4 illustrates a photovoltaic system according to one embodiment.
  • Figure 5 illustrates a solar panel according to one embodiment.
  • Figures 6 - 8 show methods to improve performance of a photovoltaic system according to some embodiments.
  • Figure 9 illustrates a local management unit according to one embodiment.
  • Figure 1OA is a plot of carrier frequency for a local management unit according to one embodiment.
  • Figure 1OB illustrates a subsystem including a local management unit according to one embodiment.
  • Figure HA illustrates a photovoltaic system according to one embodiment.
  • Figure HB illustrates a receiver of a photovoltaic system according to one embodiment.
  • Figure 12 illustrates a local management unit according to one embodiment.
  • Figures 13-18 illustrate operation of the local management unit illustrated in Figure 12.
  • Figure 19 illustrates a local management unit and transmission modulator according to one embodiment.
  • At least one embodiment of the present disclosure provides methods and systems to switch on and off weak modules in the string in a way that the current on the string bus from the good modules won't be affected by the weak modules.
  • the present invention allows transmission of data from solar modules to a central (or system controller management) unit and other local management units in an energy production or photovoltaic system without adding significant cost.
  • One embodiment of the present invention involves using the typically undesired electrical noise produced when operating local management units (sometimes referred to as "controllers" or “converters”) to act as a carrier system for data to be transferred. As there are a multitude of solar modules, each can be run on a slightly different frequency.
  • FIGS 1 - 3 illustrate local management units according to some embodiments.
  • local management units (101) are used to switch on and off the solar module (102) periodically to improve the energy production performance of the photovoltaic systems connected, at least in part, in series.
  • a local management unit may be variously referred to as a solar module controller (or converter) or link module unit.
  • a local management unit is any of the various local management units (solar module controllers) offered by Tigo Energy,
  • a management unit (101) is local to the solar module (102) and can be used to periodically couple the solar module (102) to the serial power bus
  • the local management unit (LMU) (101) may include a solar module controller to control the operation of the solar module (102) and/or a link module unit to provide connectivity to the serial power bus (103) for energy delivery and/or for data communications.
  • Ql (106) is sent to the local management unit (101) over the photovoltaic (PV) string bus (power line) (103).
  • PV photovoltaic
  • power line power line
  • separate network connections can be used to transmit the data and/or commands to/from the local management unit (101).
  • the inputs are received in the local management unit via the serial power bus (103).
  • the solar module (102) is connected in parallel to the capacitor Cl (105) of the local management unit (101).
  • the diode Dl (107) of the local management unit (101) is connected in series in the serial power bus (103) which may or may not be part of an overall mesh configuration of solar modules.
  • the switch Ql (106) of the local management unit can selectively connect or disconnect the solar module (102) and the capacitor Cl (105) from a parallel connection with the diode Dl (107) and thus connect or disconnect the solar module (102) from the serial power bus (103).
  • a controller (109) of the local management unit (101) controls the operation of the switch (106) according to the parameters, such as duty cycle
  • the controller (109) receives the parameters (104a,
  • the controller (109) may communicate with other local management units connected on the serial power bus (103) to obtain operating parameters of the solar modules attached to the serial power bus (103) and thus compute the parameters (e.g., 104a and 104b) based on the received operating parameters.
  • the controller (109) may determine the parameter (e.g., 104a and 104b) based on the operating parameters of the solar module (102) and/or measurements obtained by the controller (109), without communicating with other local management units of other solar modules, or a remote system management unit.
  • a system (100) has a local management unit (101) coupled to the solar module (102).
  • the local management unit (101) is connected between the solar module (102) and the string bus (103) to improve the total power output for the whole string on the serial power bus (103).
  • Commands to the local management unit (101) can be sent over the photovoltaic (PV) string bus (power line) (103).
  • PV photovoltaic
  • the inputs (104a, 104b, 104c) to the controller (109) of the local management unit (101) were drawn separately, which does not necessarily indicate that the inputs (104a, 104b, 104c) are provided via separate connections and/or from outside the local management unit (101).
  • the controller (109) may compute the parameters (104a, 104b, 104c) based on measurements obtained at the local management unit (101), with or without data communications over the serial power bus (103) (or a separate data communication connection with other management units).
  • the local management unit (101) is connected in one side to the solar module (102) in parallel and on the other side in series to a string of other modules, which may or may not be part of an overall mesh configuration.
  • the local management unit (101) may receive, among others, three inputs or types of input data, including a) requested duty cycle (104a), which can be expressed as a percentage (e.g., from 0 to 100%) of time the solar module (102) is to be connected to the serial power bus (103) via the switch Ql (106), b) a phase shift (104b) in degrees (e.g., from 0 degree to 180 degree) and c) a timing or synchronization pulse (104c).
  • a requested duty cycle 104a
  • a phase shift 104b
  • degrees e.g., from 0 degree to 180 degree
  • a timing or synchronization pulse 104c
  • These inputs can be supplied as discrete signals, or can be supplied as data on a network, or composite signals sent through the power lines or wirelessly, and in yet other cases, as a combination of any of these input types.
  • the local management unit (101) periodically connects and disconnects the solar module (102) to and from the string that forms the serial power bus (103).
  • the duty cycle (104a) and the phase (104b) of the operation of the switch Ql (106) can be computed in a number of ways to improve the performance of the system, which will be discussed further below.
  • the local management unit (101) includes a capacitor Cl (105) and a switch Ql (106), as well as a diode Dl (107).
  • the diode Dl (107) is supplemented with an additional switch Q2 (108), which acts as a synchronous rectifier to increase efficiency.
  • the additional switch Q2 (108) is open (turned off) when the switch Ql (106) is closed (turned on) to attach the solar module (102) (and the capacitor Cl (105)) to the serial power bus (103).
  • a filter (not shown), including a serial coil and a parallel capacitor, is also used.
  • the controller (109) is used to process the input signals (e.g., 104a, 104b, 104c) and drive the switches Ql (106) and Q2 (108).
  • the controller (109) is a small single chip micro controller (SCMC).
  • SCMC small single chip micro controller
  • the controller (109) may be implemented using Application-Specific Integrated Circuit (ASIC) or Field-Programmable Gate Array (FPGA).
  • ASIC Application-Specific Integrated Circuit
  • FPGA Field-Programmable Gate Array
  • the controller (109) can even be implemented in discrete, functionally equivalent circuitry, or in other cases a combination of SCMC and discrete circuitry.
  • the controller (109) is coupled to the solar module (102) in parallel to obtain power for processing; and the controller (109) is coupled to the serial power bus (103) to obtain signals transmitted from other management units coupled to the serial power bus (103).
  • the local management unit (101) may lower the voltage reflected to the string bus (103) (e.g., a lower average voltage contributed to the string bus) and can cause the current reflected to the string bus (103) to be higher, nearer the level it would be if the module was not weak, generating a higher total power output.
  • the local management unit (101) provides two connectors (112 and 114) for serial connections with other local management unit (101) to form a serial power bus (103).
  • the controller (109) controls the states of the switches Ql (106) and Q2 (108).
  • the controller (109) is further connected (not shown in Figure 3) to at least one of the connectors to transmit and/or receive information from the string.
  • the controller (109) includes sensors (not shown in Figure 3) to measure operating parameters of the solar panel, such as panel voltage, panel current, temperature, light intensity, etc.
  • FIG 3A shows an alternative three terminal implementation of the local management unit 101 shown in Figure 3.
  • a panel voltage (180) is connected to terminals (182, 184).
  • Terminals (182, 186) are connected to the string bus (103).
  • a module driver (110) and a single chip micro controller (SCMC) control the switches Ql and Q2.
  • SCMC single chip micro controller
  • Ql is on to allow normal operation of the system.
  • PWM pulse width modulation
  • PWM pulse width modulation
  • a single chip micro controller (SCMC) (109) can be connected in parallel to the diode Dl (107) to function in the manner of the SCMC 109 as described above.
  • the module driver (110) and the single chip micro controller (SCMC) (109) can be integrated in a single controller as shown in, for example, Figure 3.
  • single chip micro controller (SCMC) (109) can receive the inputs (104a, 104b, 104c).
  • the inputs (104a, 104b, 104c) are provided with a communications interface (not shown) coupled to a master controller (not shown).
  • FIG. 10 illustrates a photovoltaic system (200) according to one embodiment.
  • the photovoltaic system 200 is built from a few components, including photovoltaic modules (201a, 201b, ..., 20In), local management unit units (202a, 202b, ..., 202n), an inverter (203), and a system management unit (204).
  • photovoltaic modules 201a, 201b, ..., 20In
  • local management unit units 202a, 202b, ..., 202n
  • inverter 203
  • system management unit 204
  • the system management unit (204) is part of the inverter (203), the combiner box (206), a local management unit, or a stand-alone unit.
  • the solar modules (201a, 201b, ..., 20In) are connected in parallel to the local management units (202a, 202b, ..., 202n) respectively, which are connected in series to form a string bus (205), which eventually is connected to an inverter (203) and the management unit (204).
  • the solar module (201a) for example, is connected to the local management unit (202a) by the terminals (182, 184, 186) ( Figure 3A).
  • the terminal (182) which connects to the panel voltage and the string voltage, is connected to the depicted left connection between the solar module (201a) and the local management unit (202a) and connected to the depicted left connection between the local management unit (202a) and the string bus (205).
  • the terminal (184) which is connected to the panel voltage, is connected to the depicted right connection between the between the solar module (201a) and the local management unit (202a).
  • the terminal (186), which is connected to the string voltage is connected to the depicted right connection between the local management unit (202a) and the string bus (205).
  • the string bus (205) can be connected to the inverter (203) directly or as part of a mesh network or combiner boxes or fuse boxes (not shown).
  • An isolated local management unit can be used as a combiner box (206) to adjust all voltages before connecting to the inverter (206); or, a single or multi-string inverter can be used.
  • the management unit (204) may assign a different phase for each of the local management units (202a, 202b, ..., 202n). In one embodiment, at any given time, a maximum of a predetermined number of solar modules (e.g., one single solar module) are disconnected from the string bus (205).
  • the local management units can have the signal inputs, including but not limited to duty cycle (104a), phase (104b) and synchronization pulse (104c) (e.g., to keep the local management units synchronized).
  • the phase (104b) and the synchronization pulse (104c) are used to further improve performance, but the local management unit (101) can work without them.
  • the local management unit may provide output signals.
  • the local management unit (101) may measure current and voltage at the module side and optionally measure current and voltage in the string side.
  • the local management unit (101) may provide other suitable signals, including but not limited to measurements of light, temperature (both ambient and module), etc.
  • the output signals from the local management unit (101) are transmitted over the power line (e.g., via power line communication (PLC)), or transmitted wirelessly.
  • PLC power line communication
  • the system management unit (204) receives sensor inputs from light sensor(s), temperature sensor(s), one or more each for ambient, solar module or both, to control the photovoltaic system (200).
  • the signals may also include synchronization signals.
  • a management unit can send synchronization signals periodically to set the timing values, etc.
  • the local management unit can be a very non-expensive and reliable device that can easily increase the throughput of a photovoltaic solar system by a few (e.g., signal or low double digits) percentage points. These varied controls also allow installers using this kind of system to control the VOC (open circuit voltage) by, for example by shutting off some or all modules.
  • a few modules can be disconnected from a string if a string is getting to the regulatory voltage limit, thus more modules can be installed in a string.
  • local management units can also be used within the solar panel to control the connection of solar cells attached to strings of cells within the solar panel.
  • FIG. 5 illustrates a solar panel according to one embodiment.
  • the solar panel (300) has a few strings of solar cells (e.g., three solar cell strings per module).
  • a local management unit (101) can be applied to a group of cells (301) within a string of an individual solar panel (300), or in some cases to each cell (301) in a solar panel (300).
  • a group of solar cells (301) that are attached to a local management unit (101) may be connected to each other in series, in parallel, or in a mesh configure.
  • a number of local management units (101) connect the groups of the solar cells (301) in a string to provide output for the solar panel (300).
  • Some embodiments of the disclosure includes methods to determine the duty cycles and/or phases for local management units connected to a string or mesh of solar modules.
  • the duty cycle of all local management units in a string or mesh can be changed, to increase or decrease the string voltage.
  • the duty cycles may be adjusted to avoid exceeding the maximum voltage allowed.
  • the maximum voltage may be limited by the combiner box (206), the inverter (203), or any other load connected to the string bus (205), or limited by any regulations applicable to that system.
  • the duty cycles are adjusted to align the voltage of multiple strings.
  • the duty cycle of one local management unit (101) in a string can be changed to cause higher current in that local management unit (101) and overall higher power harvesting.
  • the duty cycles are computed for the solar modules that are connected to a string via the corresponding local management units.
  • the duty cycles can be calculated based on the measured current and voltages of the solar modules and/or the temperatures.
  • the duty cycles can be further fine tuned and/or re-adjusted to changes, such as shifting shading etc., one step a time, to improve power performance (e.g., to increase power output, to increase voltage, to increase current, etc.).
  • target voltages are computed for the solar modules, and the duty cycles are adjusted to drive the module voltage towards the target voltages.
  • the methods to compute the duty cycles of the solar modules can also be used to compute the duty cycles of the groups of solar cells within a solar module.
  • Figures 6 - 8 show methods to improve performance of a photovoltaic system according to some embodiments.
  • At least one operating parameter of a solar energy production unit coupled to a string via a management unit is received (401) and used to identify (403) a duty cycle for the management unit to connect the solar energy production unit to string.
  • the solar energy production unit may be a solar module, a group of solar cells within a solar module, or a single solar cell in a string in a solar module.
  • the duty cycle is adjusted (405) to optimize the performance of the solar energy production unit and/or the string.
  • the duty cycle can be adjusted to increase the current in the string and/or the solar energy production unit, to increase the output power of the string and/or the solar energy production unit, to increase the voltage of the solar energy production unit, etc.
  • the operating voltages of a plurality of solar panels connected in series are received (421) and used to identify (423) a second solar panel having the highest operating voltage (highest output power) in the string.
  • a duty cycle of a first solar panel is computed (425) based on a ratio in operating voltage between the first and second solar panels.
  • the duty cycle can be computed based on a ratio in output power between the first and second solar panels.
  • the duty cycle can be computed based on a ratio between the first and second solar panels in estimated/computed maximum power point voltage.
  • the duty cycle can be computed based on a ratio between the first and second solar panels in estimated/computed maximum power point power.
  • the duty cycle of the first solar panel is adjusted (427) to improve the performance of the first solar energy production unit and/or the string, until a decrease in the operating voltage of the second solar panel is detected.
  • the duty cycle of the first solar panel can be adjusted to increase the total output power of the string, to increase the current of the string, to increase the current of the first solar panel, to drive the voltage of the first solar panel towards a target voltage, such as its maximum power point voltage estimated based on its current operating parameters, such as temperature or a voltage calculated using its estimated maximum power point voltage.
  • the duty cycle of the second solar panel is optionally decreased (431) to increase the operating voltage of the second solar panel.
  • the strongest solar panel or strong panels within a threshold from the strongest panel
  • is not switched off line e.g., to have a predetermined duty cycle of
  • the duty cycle of the second solar panel is repeatedly decreased (429) until it is determined (431) that the decrease (429) in the duty cycle of the second solar panel cannot increase the voltage of the second solar panel.
  • operating parameters of a plurality of solar panels connected in a string are received (441) and used to identify (443) a first maximum power point voltage of a first solar panel.
  • a second solar panel having the highest operating voltage (or output power) in the string is identified.
  • a second maximum power point voltage of the second solar panel is identified (447) based on the received operating parameters and used to compute (449) a target voltage for the first solar energy production unit.
  • the target voltage is a function of the first and second maximum power point voltages and the highest operating voltage identified
  • the duty cycle of the first solar energy production unit is adjusted to drive the operating voltage of the first solar panel towards the target voltage.
  • the target voltage may be the set as the first maximum power point voltage of the first solar panel.
  • a same factor is applied to all modules in that string. For example, in a case of a first module Al that is producing only 80%, and the voltage of the whole string needs to be 5% lower, the duty cycle of Al is 80% multiplied the duty cycle applied to the whole string (which is Y in this example) so module Al then has Yx 0.8 as duty cycle.
  • system management unit (204) and/or the local management units are used solely or in combination to determine the parameters to control the operations of the switches.
  • a system management unit (204) is the
  • each local management unit broadcasts information to the other local management units on the string to allow the individual local management units to decide their own duty cycle and phase parameters.
  • a local management unit may instruct one or more other local management units to adjust duty cycle and phase parameters.
  • the local management units on a string bus (205) may elect one local management unit to compute the duty cycle and phase parameters for other local management units on the string.
  • the system management unit (204) may determine one or more global parameters (e.g., a global duty cycle, the maximum power on the string, the maximum voltage on the string, etc.), based on which individual local management units adjust their own duty cycles.
  • one or more global parameters e.g., a global duty cycle, the maximum power on the string, the maximum voltage on the string, etc.
  • a local management unit may effectively self manage and determine its own duty cycles without relying upon communicating with other management units. For example, the local management unit may adjust its duty cycle for connecting its solar module to the string to operate the solar module at the maximum power point. No local management unit is in control over the system, and each adjusts its own duty cycle (and thus, its power and voltage.)
  • module voltage are measured by the local management units in the same string at substantially/approximately the same time and used to identify the strongest solar module.
  • a strongest solar module provides the most power in the string. Since the modules are connected in series, the solar module having the highest module voltage in the string can be identified as the strongest solar module.
  • the operating voltage and current of the solar module are measured to determine the power of the solar module.
  • Additional approaches can be implemented to control the voltage, power output, or the efficiency of one or more strings of solar module controllers as described above.
  • a system controller management unit controls the operation of a plurality of local management units in one or more strings.
  • one or more local management units controls the operation of a plurality of local management units in one or more strings.
  • the local management unit may only control its own operation, or may control the operation of itself and other local management units in the same string.
  • One or more local management units in a string may have the capability to control the operation of other local management units in the same string.
  • a single local management unit can be selected to be a controlling local management unit to control a plurality panels in a string.
  • the controlling local management unit in a string can be selected using any suitable protocol.
  • the first local management unit that announces its intent to take control of other modules in the string could become the controlling local management unit.
  • one or more local management units can each receive module voltage from all local management units in the same string and identify the strongest local management unit (i.e., the one with the maximum power and voltage). Each local management unit can then set its own duty cycle as a function of the received voltage.
  • the duty cycle for each module can be computed as a function of a ratio between the module voltage V of the module and the highest module voltage V m .
  • a particular local management unit receives the voltages of all other local management units at the same time or substantially same time (e.g., all voltages are received within an interval of less than one second.)
  • the system management (204) may identify the highest module voltage from the module voltages received from the local management units (202a, 202b, ..., 202n), and compute the duty cycles for the corresponding local management units (202a, 202b, ..., 202n).
  • the local management units (202a, 202b, ..., 202n) may report their module voltages on the string bus (205) to allow individual local management units (202a, 202b, ..., 202n) to identify the highest module voltage and compute the duty cycles, without relying upon the system management unit (204). [0097] In one embodiment, one of the local management units (202a, 202b, ..., 202n) may identify the highest module voltage and/or compute the duty cycles for the other local management units (202a, 202b, ..., 202n).
  • the duty cycles are determined and/or adjusted periodically (e.g., every 30 seconds).
  • the intervals can take into account various environmental factors (e.g., where shadows on a solar panel are cast on different parts of the panel over the course of a day).
  • the duty cycles for the solar modules on the string are set based on the module voltage ratio relative to the highest module voltage in the string, the duty cycles can be fine tuned to increase the power performance.
  • the duty cycles can be fine tuned one step a time, until a decrease of voltage of the module with the highest power is detected. In response to the detected decrease, the last change that caused the decrease can be reversed (undone).
  • the fine tuning of the duty cycles can be used to reach the peak performance point (e.g., for maximum power point tracking).
  • the duty cycles of the solar modules on the string are adjusted until the module with the highest power in the string decrease its voltage. Since decreasing the duty cycle of a solar module decreases the time period the module is connected to the string and thus increases its voltage, the duty cycle of the module with the highest power in the string can be decreased to increase its voltage, in response to the decrease in its voltage caused by the adjustment to the duty cycles of other solar modules on the string. For example, the duty cycle of the module with the highest power in the string can be decreased until its voltage is maximized.
  • the performance of solar modules may vary significantly with temperature.
  • a system capable of measuring temperature can implement methods for controlling the voltage, power output, or the efficiency of one or more strings of solar module controllers using module temperature as a factor.
  • the local management unit measures module and ambient temperatures for some methods to determine the duty cycles.
  • the operating parameters measured at the local management units e.g., 202a, 202b, ..., 202n
  • module temperature can be used compute the estimated voltages of the solar modules at their maximum power points. For example, a formula presented by Nalin K. Gautam and N.D.
  • a local management unit may adjust the duty cycle of the solar module connected to the local management unit to change the module voltage to the computed/estimated maximum power point voltage V mp , without having to communicating with other management units.
  • a local management unit may adjust the duty cycle of the solar module connected to the local management unit to perform maximum power point tracking.
  • the duty cycle for each module on a string can be computed as a function of a ratio between the maximum power point voltage V mp of the module and the maximum power point voltage V mpm of the strongest module.
  • the duty cycle can be periodically updated, based on the current operating parameters measured, and/or fine tuned until a decrease in the voltage of the strongest module is detected.
  • a target voltage for each module on the string can be computed as a function of a ratio between the maximum power point voltage V mp of the module and the maximum power point voltage V mpm of the strongest module.
  • the target voltage for a module can be computed as V m x V mp /V mpm , where V m is the measured voltage of the strongest module.
  • the duty cycle of the module can be changed to drive the module voltage of the module towards the target voltage.
  • the duty cycle for each module on a string can be computed as a function of a ratio between the maximum power point power P mp of the module and the maximum power point power P mpm of the strongest module.
  • the duty cycle can be periodically updated, based on the current operating parameters measured, and/or fine tuned until a decrease in the voltage of the strongest module is detected, since decreasing the duty cycle normally increases the module voltage.
  • a target voltage for each module on the string can be computed as a function of a ratio between the maximum power point power P mp of the module and the maximum power point power P mpm of the strongest module.
  • the target voltage for a module can be computed as V m x P mp /P mpm , where V m is the measured voltage of the strongest module.
  • the duty cycle of the module can be changed to drive the module voltage of the module towards the target voltage, since decreasing the duty cycle normally increases the module voltage.
  • the duty cycle for each local management unit is changed to increase the current of the solar module attached to the local management unit (e.g., based on the measurement of the voltage and current of the solar module), until the maximum current is achieved.
  • This method assumes that string maximum power can be achieved with some accuracy by driving each local management unit to maximum current.
  • the voltages and currents of the solar modules are measured for tuning the duty cycles for maximum power point tracking for the string. The measurements of the voltages and currents of the solar modules also enable the local management units to additionally serve as a module level monitoring system.
  • the duty cycles can be adjusted by the system management unit (e.g., 204) based on the measurements reported by the local management units (e.g., 202a, 202b, ..., 202n), or adjusted directly by the corresponding local management units (e.g., 202a, 202b, ..., 202n).
  • the system management unit e.g., 204 based on the measurements reported by the local management units (e.g., 202a, 202b, ..., 202n), or adjusted directly by the corresponding local management units (e.g., 202a, 202b, ..., 202n).
  • the maximum power point tracking operation by the inverter (203) is frozen (temporarily stopped).
  • Light intensity at the solar modules is monitored for changes.
  • the voltage and current of the solar modules are measured for the determination of the duty cycles.
  • normal operation resumes (e.g., unfreezing of maximum power point tracking operation).
  • the local management units measure the voltages and currents of the solar modules to determine the power of the solar modules. After identifying the highest power P m of the solar module on the string, the duty cycles of the solar modules on the string are determined by the power radio relative to the highest power P m .
  • a predetermined threshold is used to select the weak modules to apply duty cycles. For example, in one embodiment, when a module produces power less than a predetermine percent of highest power P m , a duty cycle is calculated and applied to the solar module. If the module is above the threshold, the module is not disconnected (and thus having a duty cycle of 100%).
  • the threshold may be based on the power, or based on the module voltage.
  • the system management unit (204) finds the duty cycles for the local management units (202a, 202b, ..., 202n) and transmits data and/or signals representing the duty cycles to the local management units (202a, 202b, ..., 202n) via wires or wireless connections.
  • the local management units (202a, 202b, ..., 202n) may communicate with each other to obtain the parameters to calculate the duty cycles.
  • the system management unit (204) knows all the different duty cycles indicated for the local management units (202a, 202b, ..., 202n). [00115] In one embodiment, during power fine tuning, the system management unit (204) sends the appropriate data/signal to the appropriate local management units (202a, 202b, ..., 202n), and then the system management unit (204) calculates the total power of the string and corrects the duty cycle to produce maximum power. Once maximum power is achieved, the duty cycles for the local management units (202a, 202b, ..., 202n) may be saved in a database and serve as a starting point for the corresponding local management units (202a, 202b, ..., 202n) at the same time of day on the next day. Alternatively, a local management may store the duty cycle in its memory for the next day.
  • the stored duty cycles can be used when there is a fixed shade on the modules, such as a chimney, a tree, etc., which will be the same shade on any day at the same time. Alternatively, historical data may not be saved, but may be recalculated from scratch on each run, for example every 30 minutes. [00117] In one embodiment, the light intensity at the solar modules is monitored for changes. The duty cycles are calculated when the light intensity does not change significantly. If there are changes in sun light radiation at the solar modules, the system will wait until the environment stabilizes before applying or adjusting the duty cycles.
  • the system management unit (204) can communicate with the inverter as well.
  • the inverter may stop maximum power point tracking. In such a situation, the inverter can be set up for its load, instead of tracking for maximum power point.
  • the system management unit (204) and the local management units are used to set the operating parameters and balance the string.
  • the environment is not stable but measurements and calculation are done faster than the MPPT is working, there may be no need to stop the MPPT on the inverter.
  • measurements can be taken few times for the same radiation until a stable result is achieved.
  • FIG 9 shows an overview of a local management unit (202x) that is modified from the local management unit (101) discussed above in relation to Figure 3A.
  • local management unit (202x) contains a single chip micro controller (SCMC) (109).
  • SCMC single chip micro controller
  • all of the features and details of the local management units discussed above apply to the local management unit (202x) and are not repeated for purposes of clarity.
  • some of the features and details of the local management units discussed above selectively apply to the local management unit (202x) and are not repeated for purposes of clarity.
  • the module driver (110) is connected in parallel with the capacitor Cl, and is also connected between the switches Ql and Q2.
  • the micro controller (109) contains various operating parameters regarding the local management unit (202x), such as the voltage, current, etc.
  • the micro controller (109) can run suitably programmed software (120a-n) to modulate the chopping frequency of the switches Ql and Q2.
  • the switches Ql and Q2 perform a duty cycle according to the formula calculated as previously described.
  • a duty cycle would result in minor variations from cycle to cycle (i.e., in the inter cycle) that can be used to encode using MFM (modified frequency modulation), Manchester-type encoding, or other suitable time-delay type encoding technique with or without additional error correction.
  • MFM modified frequency modulation
  • Manchester-type encoding or other suitable time-delay type encoding technique with or without additional error correction.
  • the approach of modulating, for example, the PWM inter cycle would allow a receiver (301) at the end of the string bus (205) to measure the different variations of each of the local management units.
  • the local management units each can have a slightly different base frequency so that their respective harmonics would not cover each other, although they would move in a similar range. This approach has the added benefit of reducing overall EMI of
  • Figure 1OA is a plot of the upper half of a frequency spectrum (500) of a carrier frequency (501) for a particular local management unit.
  • the frequency spectrum (500) shows the harmonics fnl-fnn as elements (505a-n). Arrows above the harmonics fnl-fnn (505a-n) indicate they wobble around with the variations in pulse width modulation from cycle to cycle. Also shown is a notch filter curve (504), which can be used to remove significant noise to avoid EMI problems in the system and to comply with FCC and other regulatory agency regulations as needed.
  • Figure 1OB shows an overview of a subsystem (510) that includes the local management unit (202x), the panel voltage (180), terminals (182, 184, 186), and a notch filter (506).
  • the notch filter (506) includes an inductor Ln and a capacitor Cn.
  • the notch filter (506) acts as a low pass filter and relies on the internal capacity of the single chip micro controller (SCMC) of the local management unit (202x).
  • SCMC single chip micro controller
  • a notch frequency of the notch filter (506) sits on the switching frequency to suppress noise.
  • additional or different filters may be used.
  • Figure HA shows an overview of a system (200) with a string bus (205) similar to that of system (200) previously discussed in relation to Figure 4.
  • a receiver subsystem (300) is a receiving portion of a modem associated with a head end to receive modulated signals from local management units, as described in more detail below.
  • the receiver subsystem (300) includes a receiving path separate from the string bus (205) and the combiner box (206) so that the modulated signals from the local management units can be recovered before provision to the combiner box (206) and significant noise therein.
  • the receiver subsystem (300) includes a receiver (301), a sensing line (302), and a data output line (303).
  • the sensing line (302) is connected to the string bus (205) and the data output line (303) connects to the combiner box (206).
  • the subsystem (300) can be inside the inverter (203).
  • the subsystem (300) is contained in the combiner box (206).
  • the subsystem (300) is shown external to the combiner box (206) in Figure HA for purposes of clarity.
  • FIG HB shows the receiver (301).
  • the receiver (301) includes a band pass filter (310), a mixer (311), a beat oscillator (VCO) (312), a multiband pass filter (313), a microcontroller (314), and a power supply (315).
  • Data from the local management unit arrives over the power bus 205 via sensing line (302), and then passes through the band pass filter (310) to improve signal-to-noise ratio.
  • the mixer (311) mixes the output of the band pass filter (310) and the output of the VCO (312).
  • the output of the mixer (311) is then applied to the multiband pass filter (313), where the signal is analyzed in multiple band, frequency, and time domains.
  • the output of the multiband pass filter (313) is analyzed by the microcontroller (314).
  • the power supply (315) can receive power from the string bus (205) or from the inverter (203) and provide it to the various elements of the receiver (301).
  • the receiver (301) can manage communications from all the local management units.
  • each local management unit can have its own receiver.
  • a receiver can be implemented in hardware (HW) only.
  • a digital radio can be used as the receiver, in which case an analog to digital converter (ADC) samples the signals and all the processing is done in a microcontroller or a digital signal processor using software (SW), or any combination of SW and HW.
  • ADC analog to digital converter
  • Figure 12 shows a novel topology of a local management unit (1200) as a distributed converter and remaining aspects of the local management unit (1200), as discussed above, are not shown for purposes of clarity.
  • the local management unit (1200) in Figure 12 can be used alternatively to the local management units discussed above.
  • the local management unit (1200) is a series-resonant converter with phase shift operation for light load operation.
  • the local management unit (1200) includes capacitor Cin, switches Ql, Q2, Q3, Q4, inductor LR, capacitor CR, transformer having a primary winding Tp coupled to a secondary winding Ts, diodes Dl, D2, and two capacitors Cout.
  • a typical range of input voltage Vin for the local management unit (1200) is the standard panel voltage of V mp plus or minus 20%.
  • Output voltage Vout of the distributed converter is a fixed value of 375V plus or minus a few percentage points.
  • switch Ql and switch Q2 are controlled oppositely, and switch Q3 and switch Q4 are controlled oppositely.
  • switch Ql is on, switch Q3 is on.
  • switch Q2 is on, switch Q4 is on.
  • the current can be increased or decreased by adjusting switches Ql, Q2, Q3, Q4.
  • a controller (not shown), suitably connected to a power supply, controls the operation of the switches Ql, Q2, Q3, Q4. In one embodiment, the controller can be off the shelf and possibly modified.
  • the controller can have analog circuitry. In one embodiment, the controller can be a microcontroller. In one embodiment, the controller could be a combination of these features.
  • a phase shift can be created between the currents controlled by the switches Ql, Q2, Q3, Q4.
  • the inductor LR and the capacitor CR constitute an LC (or tank) circuit.
  • the primary winding Tp of the transformer T is coupled to the secondary winding Ts.
  • Diode Dl, diode D2, and capacitor Cout constitute a Delon rectifier circuit. In a positive cycle, diode Dl charges the upper capacitor of capacitor Cout. In a negative cycle, diode D2 charges the lower capacitor of the capacitor Cout. Vout is effectively two times the voltage across the secondary winding Ts of the transformer T.
  • the local management unit (1200) requires a reliable current limit because it is required to charge a large input capacitance reflected from the inverter (203).
  • the local management unit (1200) needs to allow operation with low input and output capacitance, because reliability does not allow the use of aluminum capacitors due to their limited life expectancy. In many instances aluminum may not be suitable for the local management unit (1200) for reasons of reliability.
  • Efficiency of the novel topology of the local management unit (1200) should be higher than 96 percent at the range of 20 percent to 100 percent load.
  • the topology of the local management unit (1200) should allow direct control of input impedance for smooth MPPT control, and should minimize the need for damping networks (i.e., snubbers) in order to limit EMI emissions to improve reliability and maximize efficiency.
  • the transformer should be protected from saturation. Isolation voltage must be higher than 2000V, and switching losses reduced (i.e., zero current switching/ zero voltage switching). No load condition is to be defined during inverter turn on.
  • FIGs 13 through 18 illustrate waveforms to show performance of the local management unit (1200) and the reduction of snub voltage transients without resort to a snubber network in the local management unit (1200).
  • waveform 1302 shows the current through the primary winding Tp of the transformer T and waveform 1304 shows the drain voltage at the switch Ql at the MPPT point.
  • the waveform 1304 shows ringing on the square wave for only approximately two and a half waves at approximately one volt peak-to-peak.
  • waveform 1402 shows the current through the primary winding Tp of the transformer T and waveform 1404 shows the drain voltage at the switch Ql at 30 percent load.
  • Figure 15 shows low input voltage at full load condition.
  • waveform 1502 shows the current through the primary winding Tp of the transformer T and waveform 1504 shows the drain voltage at the switch Ql at full load condition. Steps (1503) in the waveform 1502 result from a phase shift between switches. The steps (1503) results is reduced undershoot and overshoot in the waveform 1504.
  • Figure 16 shows output diode voltage at resonant frequency at maximum load.
  • waveform 1602 shows the output current from the local management unit (1200) to the inverter (203) and waveform 1604 shows diode Dl (or diode D2) voltage at minimum frequency.
  • Figure 17 shows typical output diode voltages at medium loads.
  • waveform 1702 shows the output current from the local management unit (1200) to the inverter (203) and waveform 1704 shows diode Dl (or diode D2) voltage at minimum frequency.
  • switches Ql, Q3 are operated together at 50 percent duty cycle, while switches Q4, Q2 are operated together at 50 percent duty cycle with no phase shift.
  • Input power is controlled by changing operating frequency of the local management unit (1200) above and below the resonant frequency.
  • Turn ratio of the primary winding Tp and secondary winding Ts is set according to MPPT voltage because at this voltage efficiency is at the highest point (i.e., zero voltage, zero current is achieved).
  • switching is performed at zero voltage because there is current in the primary winding Tp and resonant tank that is maintained, and this current causes voltage shift that allows turn-on to be performed at zero voltage.
  • phase shift mode switches Ql, Q2 are reversed, and switches Q3, Q4 are reversed.
  • a phase shift causes switches Q3 and Q4 to conduct together part of the time, and likewise for switches Ql, Q4.
  • steps 1503 in the waveform 1502 are caused by the phase shift.
  • the phase shift range and frequency range are optimized for maximum efficiency by the local management unit (1200).
  • the switches (primary transistors) do not have off spike because they are clamped to the input bus.
  • phase shift minimizes ringing (and overshoot and undershoot), which in turn increases efficiency, reduces EMI, and reduces heat losses.
  • Secondary diodes D 1 , D2 are connected in center tap configuration to prevent voltage spikes from developing across them during turn-off and eliminating need for clamping components.
  • a phase shift between the switches causes a reduction in undershoot and overshoot in the diode D 1 voltage without implementation of snubber networks.
  • efficiency of the local management unit (1200) is improved both on the switch side and the diode side. In one embodiment, efficiency is improved on each side by approximately 1-2%.
  • a resonant tank provides a limit to the current through the primary winding Tp.
  • a serial capacitor CR prevents transformer saturation. Output rectifier voltage is clamped to output voltage Vout allowing the use of 600V ultra fast diodes. There are no spikes across the switching transistors. Transformer parameters act as part of resonant tank.
  • FIG. 18 shows a spectral waveform (1802) of typical emission characteristics of the local management unit (1200). Current ripple of the local management unit (1200) is measured with a current probe. Most of the current ripple comes from the inverter (203). In one embodiment, the inverter (203) is an off the shelf item. From the spectral waveform (1802), it can be seen that data transmission is possible but needs to be in the same level or higher level than the noise level. It can be seen that the maximum noise level value is approximately 35 dB.
  • FIG 19 shows a local management unit (1900) that can be used in accordance with the present invention.
  • the local management unit (1900) can be used in place of the local management units discussed above.
  • the local management unit (1900) includes a capacitor Cl, switches Ql, Q2, diode Dl, inductor L, capacitor C2, controller 1902, terminals 1904, 1906, 1908, and communication transmission modulator 1910. Operation of the local management unit (1900) is similar to the operation of the local management units, as discussed above.
  • Data transmission by the local management unit (1900) involves modulating the switching frequency of the local management unit (1900) and transferring data by using the solar module itself as power amplifier (PA).
  • PA power amplifier
  • PWM pulse width modulation
  • the PWM technique creates noise, as shown in, for example, Figure 18.
  • the created noise can be modulated to transmit data over the string bus (205) from a solar module (or slave node) to a head unit (master) in the energy production or photovoltaic system.
  • the use of noise in this way avoids the need to provide a costly separate, dedicated communications channel from the solar module to the head unit.
  • the communication transmission modulator (1910) modulates switching of the pulse width modulation (PWM) operation to transmit data from the local management unit (1900).
  • Various modulation encoding schemes can be used, such as, for example, modified FM (MFM) and Manchester coding.
  • the communication transmission modulator (1910) represents the transmission portion of a modem (not shown) that is associated with the local management unit (1900). In one embodiment, the communication transmission modulator (1910) is part of the local management unit (1900). In one embodiment, the communication transmission modulator (1910) is external to the local management unit (1900). [00144]
  • This system allows the use of full duplex (two-way) communications.
  • the receiver at the module side can be implemented within the module circuitry. The limitation of transmit and receive within same circuit does not exist. Transmission from management unit can be used to synchronize modules. Reliability is not affected by transmission. The effect on overall performance is very small because transmission duty cycle from module is low.

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Abstract

Les appareils et procédés selon l’invention comprennent une unité de production d’énergie photovoltaïque pour générer de l’électricité. Une unité de gestion locale est couplée entre une unité de production d’énergie photovoltaïque et une connexion d’unités de production d’énergie formant un bus en ligne. L’unité de gestion locale comprend une commande et un circuit de commutation. La commande sert à commander le circuit de commutation pour fournir une énergie électrique au bus de ligne. Un modulateur de transmission des communications est associé à l’unité de gestion locale. Le modulateur de transmission des communications module la commande avec les données à transmettre depuis l’unité de gestion locale via le bus de ligne.
EP09829627A 2008-11-26 2009-10-29 Systèmes et procédés d utilisation d un convertisseur de puissance pour la transmission de données sur l alimentation Withdrawn EP2359455A2 (fr)

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US20027908P 2008-11-26 2008-11-26
US20060108P 2008-12-02 2008-12-02
US20729609P 2009-02-10 2009-02-10
US12/411,317 US7602080B1 (en) 2008-11-26 2009-03-25 Systems and methods to balance solar panels in a multi-panel system
PCT/US2009/062536 WO2010062662A2 (fr) 2008-11-26 2009-10-29 Systèmes et procédés d'utilisation d'un convertisseur de puissance pour la transmission de données sur l'alimentation

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