SYSTEMS AND METHODS FOR MEASURING THE USE OF ELECTRIC POWER IN A STRUCTURE AND SYSTEMS AND METHODS O

专利摘要:
systems and methods to measure the use of electrical power in a structure and systems and methods to calibrate them. some modalities may refer to a method of using a device and measuring power consumption. the power consumption measuring device can be mechanically coupled to a surface of a circuit breaker box that overlaps at least part of one or more main electrical supply conductors for an electrical power infrastructure of a structure. the method may include: determining one or more first magnetic field readings from the one or more first magnetic field readings from one or more main electrical supply conductors using one or more sensors in the consumption meter of power; then, determine the one or more first magnetic field readings, electrically coupling a first calibration load to the electrical power infrastructure; while the first calibration load remains electrically coupled to the electrical power infrastructure, determining one or more second magnetic field readings from the one or more main electrical supply conductors as use of the one or more sensors in the power consumption measuring device ; calibrate the power consumption meter as using, in part, one or more first magnetic field readings and one or more second magnetic field readings, then calibrate the power consumption meter, determine one or more third magnetic field readings from one or more main electrical supply conductors with the use of one or more sensors in the power consumption measurement device; and determining an electrical power used by the electrical power infrastructure of the structure using at least one or more third magnetic field readings and one or more calibration coefficients. calibrating the power consumption measuring device may include determining one or more first calibration coefficients for the power consumption measuring device using at least part of the one or more first magnetic field readings and one or more second readings magnetic field and one or more second magnetic field readings. other modalities are described.
公开号:BR112013000048B1
申请号:R112013000048-1
申请日:2011-07-01
公开日:2020-09-24
发明作者:Shweatk N. Patel；Sidhant Gupta；Matthew S.Reynolds；Karthik Yogeeswaran
申请人:Belkin International, Inc.；
IPC主号:

专利说明:

[0001] This request claims the benefit of Provisional Order No. US 61 / 361,296, filed on July 2, 2010 and Provisional Order No. US 61 / 380,174 filed on September 3, 2010. This request is, in part, a continuation in part of Order No. US 12 / 567,561, filed on September 25, 2009. Provisional Orders No. 61 / 361,296 and 61 / 380,174 and Order No. US 12 / 567,561 are incorporated by reference in this document. FIELD OF THE INVENTION
[0002] This invention relates, in general, to electrical power monitoring devices, devices, systems and methods, and relates more particularly to such devices, devices, systems and methods that monitor electrical power in one or more power conductors electrical connections in a panel of a structure's electrical breaker box. BACKGROUND DESCRIPTION
[0003] A structure (for example, a house or a commercial building) can have one or more main electrical power conductors that supply electrical power to electrical devices (ie, the load) in the structure. Most structures use a split-phase electrical power distribution system with up to three main electrical power conductors. The main electrical power conductors enter the structure through an electrical breaker box panel. An electrical breaker box panel is the main electrical distribution point for electricity in a structure. Electrical breaker box panels also provide protection against overcurrents that could cause a fire or damage electrical devices in the structure. Electrical breaker box panels can be attached to and overlaid on at least part of the three main power conductors.
[0004] Different manufacturers of electrical breaker box panels, including, for example, Square-D, Eaton, Cutler-Hammer, - General- Electri, -Siemens -and Murray,-chose different configurations and conductor spacing for their electrical box panels. electrical breakers. In addition, each manufacturer produces different configurations of electrical breaker box panels for indoor installation, outdoor installation and for different ratings of total amperage, of which 100 ampere (A) and 200 A services are the most common.
[0005] The different conductor schemes in the many different types of electrical breaker box panels result in different magnetic field profiles on the metal surfaces of the electrical breaker box panels. In addition, the schematic of the internal conductors (for example, the main electrical power conductors) is not visible without the opening of the circuit breaker panel and the manner in which the schematic of the internal conductor is translated into a magnetic field profile on the panel surface. of electrical breaker box requires a detailed knowledge of electromagnetic theory to interpret and model correctly. It is therefore difficult to accurately measure the magnetic field of one or more main electrical power conductors on a surface of the electrical circuit breaker panel. If the magnetic field of one or more main electrical power conductors on a surface of the electrical breaker box panel could be precisely determined, the power and electrical current that are used by the load in the structure could be determined.
[0006] Consequently, there is a need or potential for the benefit of an appliance, system, and / or method that allows a non-electrician to accurately determine the magnetic field and other parameters related to the one or more main electrical power conductors on the surface of the control panel. electrical breaker box. BRIEF DESCRIPTION OF THE DRAWINGS
[0007] To facilitate further description of the modalities, the following drawings are provided, in which: Figure 1 illustrates a view of an exemplary electrical power monitoring system coupled to an electrical circuit breaker panel, in accordance with a first modality; Figure 2 illustrates a block diagram of the electrical power monitoring system of Figure 1, in accordance with the first modality; Figure 3 shows a sectional view of the panel of the circuit breaker box of Figure 1 along conductor 3-3, in accordance with the first embodiment; Figure 4 illustrates an example of magnetic field conductors generated by a conductor; Figure 5 illustrates an example of the magnetic field conductors generated by the main electrical power conductors in the circuit breaker box of Figure 1, in accordance with the first modality; Figure 6 illustrates an example of the capture device of Figure 2, in accordance with the first embodiment; Figure 7 illustrates an exemplary placement of the capture device of Figure 2 on a main electrical power conductor of the circuit breaker box of Figure 1, in accordance with the first embodiment; Figure 8 illustrates an exemplary graph of an electric current versus time sensor voltage, according to one modality; Figure 9 illustrates an example of a capture device, in accordance with the second embodiment; Figure 10 illustrates an example of the capture device of Figure 9 on the main electrical power conductors of the circuit breaker box of Figure 1, in accordance with the second embodiment; Figure 11 illustrates an example of the calibration device of Figure 1, in accordance with the first embodiment; Figure 12 illustrates an exemplary graph of a potential input low voltage signal to a controller of Figure 11 from a level translator of Figure 11, in accordance with an embodiment; Figure 13 illustrates exemplary graphs that illustrate the relationship between a square low voltage signal used to develop a phase reference and the low voltage signal of Figure 12, in accordance with one embodiment; Figure 14 illustrates an example of a switched load, in accordance with a third embodiment; Figure 15 illustrates an example of a switched load, in accordance with a fourth embodiment; Figure 16 illustrates an example of a switched load, in accordance with a fifth embodiment; Figure 17 illustrates an example of a switched load, in accordance with a sixth embodiment; Figure 18 illustrates a flowchart for a method of calibrating an electrical monitoring system, in accordance with one modality; Figure 19 illustrates a flow chart for an activity to determine the calibration coefficients, in accordance with a modality; Figure 20 illustrates a flow chart for a method of determining the predicted current in the main electrical power conductors, - in conformity with - a modality; Figure 21 illustrates an example of a first location of two electric current sensors in relation to the main electrical power conductors in an exemplary pickup device, in accordance with an embodiment; Figure 22 illustrates a graph that compares a predicted current compared to the measured currents for the electrical current sensors in Figure 21; Figure 23 illustrates an example of a second location of two electrical current sensors in relation to the main electrical power conductors in an exemplary pickup device, in accordance with an embodiment; and Figure 24 illustrates a graph that compares a predicted current compared to the measured currents for the electrical current sensors in Figure 23.
[0008] For the sake of simplicity and clarity of illustration, the figures drawn illustrate the general manner of construction, and descriptions and details of well-known techniques and aspects can be omitted to avoid making the invention unnecessarily difficult. In addition, elements in the drawn figures are not necessarily drawn to scale. For example, the dimensions of some of the elements in the Figures can be exaggerated in relation to other elements to help improve the understanding of modalities of the present invention. The same reference figures in different Figures represent the same elements.
[0009] The terms "first", "second", "third", "fourth" and the like in the description and in the claims, if present, are used to distinguish between similar elements and not necessarily - to describe a particular chronological or sequential order. It should be understood that the terms thus used are interchangeable under appropriate circumstances in such a way that the modalities described in this document have, for example, the ability to operate in sequences in addition to those illustrated or otherwise described in this document. In addition, the terms "includes", and "has" and any variations thereof, are intended to cover a non-exclusive inclusion, in such a way that a process, method, system, article, device or apparatus comprising a list of elements is not necessarily limited to those elements, but may include other elements not expressly listed or inherent in such a process, method, system, article, device or apparatus.
[0010] The terms "left", "right", "front", "rear", "top", "bottom", "over", "under" and the like in the description and in the claims, if present, are used for descriptive purposes and not necessarily to describe permanent relative positions. It is to be understood that the terms thus used are interchangeable under appropriate circumstances such that the modalities of the invention described in this document have, for example, the ability to operate in other orientations than those illustrated or otherwise described herein.
[0011] The terms "couple", "couple", "couple", "couple" and the like should be widely understood and refer to the connection of two or more elements or signals, electrically, mechanically and / or otherwise. Two or more electrical elements can be coupled electrically, but they may not be coupled mechanically or otherwise; two or more mechanical elements may be coupled mechanically but may not be coupled electrically or otherwise; two or more electrical elements may be coupled mechanically, but may not be coupled electrically or otherwise. The coupling can be for any length of time, for example, permanent or semi-permanent or just for an instant.
[0012] "Electrical coupling" and the like should be widely understood and include coupling that involves any electrical signal, be it a power signal, a data signal and / or other types or combinations of electrical signals. "Mechanical coupling" and the like should be widely understood and include mechanical coupling of all types.
[0013] The absence of the word "removably", "removable" and the like next to the word "coupled" and the like does not mean that the coupling, etc. in question is whether or not it is removable. DESCRIPTION OF EXAMPLES OF MODALITIES
[0014] Some modalities may deal with a method of using a power consumption measuring device. The power consumption measuring device can be mechanically coupled to a breaker box surface that overlaps at least part of one or more main electrical supply conductors for a structure's electrical power infrastructure. The method may include: determining one or more first magnetic field readings from one or more main electrical supply conductors using one or more sensors in the power consumption measuring device; after determining one or more first magnetic field readings, electrically couple a first calibration load to the electrical power infrastructure; while the first calibration load remains electrically coupled to the electrical power infrastructure, determine one or more second magnetic field readings from one or more main electrical supply conductors using one or more sensors in the consumption meter of power; calibrate the power consumption meter using at least part of the one or more first magnetic field readings and one or more second magnetic field readings, after calibrating the power consumption meter, determine one or more third magnetic field readings for the one or more main electrical supply conductors using one or more sensors in the power consumption measuring device; and determine an electrical power used by the electrical power infrastructure of the structure using at least one or more third magnetic field readings and one or more calibration coefficients. Calibrating the power consumption meter may include determining one or more first calibration coefficients for the power consumption meter using at least part of the one or more first magnetic field readings and one or more second readings magnetic field.
[0015] Other modalities may deal with a method of calibrating a magnetic field sensor device.
[0016] The magnetic field sensor device coupled to a first surface of a circuit breaker box. The circuit breaker box overlays a building's electrical power infrastructure. The electrical power infrastructure has a first phase branch and a second phase branch. The magnetic field sensor device may include two or more magnetic field sensors. The method may include: determining a first amplitude and a first "phase" angle of a first magnetic field in the two or more magnetic field sensors of the magnetic field sensor device; receive communications that a first load is coupled to the first phase branch of the electrical power infrastructure; while the first charge is coupled to the first phase branch, determining a second amplitude and a second phase angle of a second magnetic field in the two or more magnetic field sensors of the magnetic field sensor device; receive communications that a second load is coupled to the second phase branch of the electrical power infrastructure; while the second charge is coupled to the first phase branch, determining a third amplitude and a third phase angle of a third magnetic field in the two or more magnetic field sensors of the magnetic field sensor device; and determining one or more calibration coefficients for the magnetic field sensor device at least in part using the first amplitude and the first phase angle of the first magnetic field on the two or more magnetic field sensors, the second amplitude and the second phase angle of the second magnetic field in the two or more magnetic field sensors, and of the third amplitude and third phase angle of the third magnetic field in the two or more magnetic field sensors.
[0017] Additional modalities may deal with a system for monitoring the use of electrical power in a building's electrical power infrastructure. The building includes a circuit breaker box and electrical supply conductors for the building's electrical power infrastructure. The system may include: (a) a power consumption measuring device configured to be coupled to a first surface of the breaker box - the - breaker box - which overlaps at least part of the electrical supply conductors for the power infrastructure electrical power, the power consumption measuring device that has one or more magnetic field sensors; (b) a first calibration device configured to be electrically coupled to the electrical power infrastructure, the first calibration module comprising one or more first calibration loads; and (c) a calibration module configured to operate on a first processor and configured to at least partially calibrate the power consumption measuring device using data obtained from one or more magnetic field sensors on the measuring device power consumption.
[0018] The power consumption measuring device can be configured to obtain at least part of the data while at least one of the first or more calibration loads is electrically coupled to the electrical power infrastructure and while the power consumption measuring device is coupled to the first surface of the circuit breaker box.
[0019] In yet other additional embodiments, a magnetic field capture device may include: (a) at least two magnetic field sensors configured to detect a magnetic field in a conductor carrying current; (b) a phase detector electrically coupled to the freckles of at least two magnetic field sensors; and (c) a phase indicator electrically coupled to the phase detector. The phase indicator can include a display that indicates when the at least two magnetic field sensors are in a predetermined position in relation to the conductor carrying the current.
[0020] Figure 1 illustrates a view of an electrical power-exemplary monitoring system 100 coupled to a breaker box panel 190, in accordance with a first embodiment. Figure 2 illustrates a block diagram of the electrical power monitoring system 100, in accordance with the first modality. Figure 3 shows a sectional view of the breaker box panel 190 along conductor 3-3, in accordance with the first embodiment.
[0021] The electrical power monitoring system 100 can also be considered a system for monitoring the electrical power usage of a structure (i.e., a building). The electrical power monitoring system 100 can also be considered a device and system for determining the predicted current used by one or more electrical devices (i.e., the load) in a structure. The electrical power monitoring system 100 is merely exemplary and is not limited to the modalities presented in this document. The electrical power monitoring system 100 can be employed in many different modalities or examples not shown or described specifically in this document.
[0022] In some instances, the electrical power monitoring system 100 may include: (a) at least one pickup device 110 (i.e., a power consumption measurement device); (b) at least one computational unit 120; and (c) at least one calibration device 180.
[0023] In some instances, system 100 can be used on circuit breaker panels from different manufacturers and on different types of circuit breaker panels from the same manufacturer. In addition, in some instances, system 100 can be easily installed by an untrained individual (eg, a non-electrician) without opening the circuit breaker panel box and without exposing the inside of uninsulated electrical power conductors.
[0024] Also as shown in Figure 1, a conventional breaker box or breaker box panel 190 may include: (a) two or more individual breaker boxes 191; (b) two or 192 main circuit breaker boxes; (c) a panel 196 with an outer surface; and (d) a door 197 providing access to circuit breaker boxes 191 and 192. At least a portion of main electrical power conductors 193, 194 and 195 can be located on circuit breaker panel 190. "Circuit breaker panel" can refer to and also include fuse boxes, which are still common in buildings with older electrical systems. The electrical power infrastructure of a structure can include at least breaker box panel 190 and main electrical power conductors 193, 194 and 195. In some examples, breaker box panels can also refer to any type electrical distribution panel used to supply electricity to a structure.
[0025] The main electrical power conductors 193, 194 and 195 are electrically coupled to the main circuit breaker boxes 192 and supply the electrical power to electrical devices (ie the load) in the structure. Panel 196 overlaps at least part of the main electrical power conductors 193, 194 and 195 and a set of associated circuits to protect people from accidental contact with these energized electrical power conductors. Typically, panel 196 is composed of steel or another metal.
[0026] Door 197 covers breaker boxes 191 and 192 and is typically closed for aesthetic reasons but can be opened to allow access to the breaker box levers 191 and 192 on breaker box panel 190. As shown in Figure 3, when door 197 is closed, panel region 398 can have panel region depth 399. panel region 399 depth is typically 13 millimeters (mm) to 20 mm to allow door 197 to be closed without reaching the levers breaker box 189. The depth of panel region depth 399 limits the permissible thickness of the pickup device 110 which is mounted in the panel region 398. That is, in several examples, the pickup device 110 can be fitted into the depth panel region 399 so that the breaker panel door can be kept closed while the pickup device 110 is in operation. In many instances, the pickup device 110 has a depth of less than 20 mm. In the same example, or in different examples, the pickup device 110 may have a depth of less than 13 mm.
[0027] Small, residential commercial electrical service is typically 240 volt split phase service. This refers to the supply, by the public service, of two 120 V alternating current (AC) conductors (for example, power conductors 193 and 194) that are 180 degrees out of phase, along a neutral conductor (for example, power conductor 195) that can be used to return current from power conductor 193 or 194. Power conductors 193, 194 and 195 are the "main" electrical power conductors or conductors that carry power public service entrance before being divided into branch circuits serving different loads. By capturing the magnetic fields generated by power conductors 193, 194 and 195, system 100 can capture the total current drawn through all loads in the public service, since all loads in the structure are coupled in parallel to the power conductors 193, 194 and / or 195.
[0028] In the United States, many different types of electrical charges are found in a building served by a 240 V split-phase utility service. Electrical charges can be divided into two categories of charges: (a) 120 V charges; and (b) 240 V loads.
[0029] 120 V loads can primarily include low watt power loads, that is, loads plugged into standard 15 A 120 V or 20 A 120 V 3-prong outlets, and small appliances with power consumption of less than ~ 2 kW (kilowatt). These loads are wired in individual circuits between the pair of power conductors 193 and 195 (the "first phase branch" or the "leg 193 to 195" of the wiring circuit) or the pair of power conductors 194 and 195 (the "second phase branch" or "leg 194 to 195" of the wiring circuit). When connecting the wired structure, electricians try to balance the anticipated wattage of loads and sockets in each leg, but this is not an exact process, so there is a likelihood that the currents in leg 193 to 195 and leg 194 to 195 will be balanced, as a different total wattage is typically drawn from each pair. When a 120 V load is connected, its current flows from the utility through the 193 or 194 power conductor through the circuit-breaker and main circuit breaker boxes to the load, and then back to the power conductor 195 and back to the public service.
[0030] 240 V loads are typically large appliances (eg, electric dryer, stove, air conditioning compressor, electric baseboard heaters) that - consume more than two kW (kilowatts). In this case, the load current flows between power conductors 193 and 194 and no load current flows through power conductor 195. Because of the 180 degree phase relationship between the voltages in power conductors 193 and 194, the voltage total is 240 V.
[0031] Referring again to Figures 1 and 2, computational unit 120 may include: (a) a communications module 221; (b) a processing module 222; (c) a power source 223 with an electrical connector 128; (d) a user communications device 134; (e) a controller 22 5; (f) a memory 226; (g) a calibration load module 227; (h) a calibration calculation module 229; (i) a control mechanism 132; and (j) an electrical voltage sensor 228.
[0032] The computational unit 120 can be configured to receive the output signal from the calibration device 180 and / or the capture device 110 through the communications module 221 and process the output signal to determine one or more parameters related to the use of electrical power of the structure (for example, the electrical power used by the structure and the electrical current in the main electrical power conductors 193, 194 and 195).
[0033] In some embodiments, computational unit 120 may be a personal computer (PC).
[0034] Controller 225 may be a microcontroller such as the MSP430 microcontroller manufactured by Texas Instruments, Inc. In another embodiment, controller 225 is a digital signal processor such as the TMS320VC5505 digital signal processor manufactured by Texas Instruments, Inc. or a processor digital signal amplifier manufactured by Analog Devices, Inc.
[0035] The 2-2-2 processing module can be configured to use current measurements from the pickup device 110 to determine one or more parameters related to the use of the electrical power of the structure (for example, the electrical current and electrical power of conductors of main electrical power 193, 194 and 195). As explained below, calibration calculation module 229 can be configured to use current measurements from the pickup device 110 to calibrate the electrical power monitoring system 100 (for example, calculate the calibration coefficients for the pickup device 110 ).
[0036] In some examples, processing module 222 and calibration calculation module 229 can be stored in memory 226 and configured to operate controller 225. When computer unit 120 is in operation, the program instructions (for example, the module process numbers 222 and / or calibration calculation module 229) stored in memory 226 are executed by controller 225. A portion of the program instructions, stored in memory 226, may be suitable for carrying out methods 1800 and 2000 (Figures 18 and 20, respectively) as described below.
[0037] The calibration load module 227 can include one or more calibration loads. As will be explained below, the one or more calibration loads can be temporarily electrically coupled, for example, to the first phase branch of the electrical power infrastructure of the structure to help calibrate the electrical power monitoring system 100.
[0038] In some examples, user communications device 134 and control mechanism 132 can be detachable from the rest of computer unit 120 and communicate - wirelessly with the rest of computer unit -120.
[0039] The electrical voltage sensor 228 can be used to determine the amplitude and phase angle of the voltage across the electrical power infrastructure. The phase angle of the through current is equal to the phase angle measured by the electric current sensors 211 minus the phase angle of the voltage measured using the electric voltage sensor 228. That is, the phase angle of the current can be calculated in reference to the zero point crossing of the voltage.
[0040] In some instances, the pickup device 110 can communicate the current measurement made by the electric current sensors 211 to the computing unit 120 so that the phase angle of the current can be calculated. In other examples, the computational device 120 can communicate the voltage measurement by the electrical voltage sensor 228 to the pickup device 110 so that the phase angle of the current can be calculated. In other examples, the voltage sensor 228 may be located on the calibration device 180.
[0041] Power source 223 can supply electrical power to communications module 221, processing module 222, user communications device 134, controller 225, memory 226, calibration load module 227 and / or the mechanism control unit 132. In some examples, power source 223 can be coupled to electrical connector 128 which can be coupled to an electrical wall outlet of the electrical power infrastructure.
[0042] User communications device 134 can be configured to display information to a user. In one example, user communications device 134 may be a monitor, a touchscreen and / or one or more LEDs (light-emitting diodes).
[0043] The control mechanism 132 may include one or more buttons configured to control at least partially the computer unit 120 or at least the user communications device 134. In one example, the control mechanism 132 may include a power switch (i.e. i.e., a power on / off switch) and / or a display switch configured to control what is displayed on user communications device 134.
[0044] Still with reference to Figures 1 and 2, the capture device 110 may include: (a) two or more magnetic field sensors or electric current sensors 211; (b) a controller 213; (c) a user communications module 214; (d) a communications module 215; (e) a power source 216; and (f) a coupling mechanism 219. Controller 213 can be used to control electric current sensors 211, user communications module 214, communications module 215 and power source 216.
[0045] Electric current sensors 211 can include an inductive pickup, a Hall effect sensor, a magnetoresistive sensor or any other type of sensor configured to respond to the time-varying magnetic field produced by conductors within circuit breaker panel 190.
[0046] In several examples, the pickup device 110 can be configured to be attached to a panel surface 196 using the coupling mechanism 219. In some examples, the coupling mechanism 219 may include an adhesive, a Velcro® material, a magnet or other fixing mechanism.
[0047] Communications module 215 can be electrically coupled to electric current sensors 211 and controller 213. In some instances, communications module 215 communicates voltages or other parameters measured using electric current sensors 211 to the communications module 221 of computational unit 120. In many instances, communications module 215 and communications module 221 can be wireless transceivers. In some examples, electrical signals can be transmitted using WI-FI (wireless fidelity), 802.11 wireless protocol from the IEEE (Institute of Electrical and Electronics Engineer -Institute of Electrical and Electronics Engineers) the Bluetooth 3.0+ wireless protocol HS (High Speed). In additional examples, these signals can be transmitted using a Zigbee wireless standard (IEEE 802.15.4 wireless protocol), Z-Wave, or a unique wireless standard. In other examples, communications module 215 and communications module 221 can communicate electrical signals using a wired or cellular connection.
[0048] The user communications module 214 can be configured to display information to a user. In one example, the user communications module 214 can be an LCD (liquid crystal display), and / or one or more LEDs (light emitting diodes).
[0049] Controller 213 can be configured to control electrical current sensors 211, communications module 215, user communications module 214, and / or power source 216.
[0050] Calibration device 180 may include: (a) a communications module 281; (b) an electrical connector 282; (c) a calibration load module 283; (d) a user communication device 184; (e) a controller 285; and (f) a 289 power source. In some examples, the 2 "81 communications module may be similar to or the same as the communications module 215 and / or 221. Electrical connector 282 may be an electrical power connector in some examples User communication device 184 can be configured to display information to a user In one example, user communication device 184 can be one or more LEDs.
[0051] In accordance with Ampere's Law, magnetic fields are generated by conductors that carry current, as shown in Figure 4. That is, the magnetic field generated by a given conductor is a three-dimensional vector field, which can be decomposed into each of the geometric axes X, Y and Z. In an alternating current system, these magnetic fields vary in magnitude over time, but maintain the same vector angle in relation to the coordinate base. Thus, in reference to the geometric axis X, for example, the field can in an instant be pointed in the + X direction or in the -X direction as the AC current reverses the direction at the line frequency of, for example, 60 Hz. It is known that a magnetic field component in the X direction can refer to + X or -X depending on the direction of the current flow at a particular time.
[0052] The magnetic field lines follow the "right hand rule" of Ampère's Law; if the thumb of an individual's right hand is aligned with the direction of current flow in the conductor, the field lines surround the conductor perpendicular to that conductor and towards the individual's fingers.
[0053] Some modalities deal primarily with the magnetic field component that is oriented perpendicular to the plane of the breaker box panel (along the geometric axis "Z"), as these are the field components that can be easily captured - by a field sensor (i.e., the catch device 110) outside the metal cover of the breaker box panel 190.
[0054] As shown in Figure 5, as power conductors 193 and 194 have a 180 degree phase difference, at any point in time, the direction of the magnetic field lines has loops in opposite directions.
[0055] Thus, in accordance with the Kirchhoff Currents Law, the total current through a given supply conductor (ie, power conductors 193, 194 and / or 195) is the sum of all charge currents extracted from that conductor. The magnitude of the magnetic field generated by each of the conductors (that is, the 193, 194 or 195 power conductor) is, therefore, directly proportional to the sum of the currents extracted in all branch circuits connected to that conductor. The direction of the magnetic field lines of a given conductor does not change like the currents in the branches.
[0056] System 100 can be configured to capture the magnetic fields generated at least through power conductors 193 and 194 in order to deal with the three possible load cases: (a) 120 V load between leg 193 to 195, (b ) 120 V load between leg 194 to 195, and (c) 240 V load between leg 193-194. In some cases it is not necessary to capture the magnetic field generated by the power conductor 195 (ie, the neutral conductor) as any current drawn through the power conductor 195 is originated by the power conductor 193 or 194.
[0057] Figure 6 illustrates an example of an electric current sensor 211, in accordance with the first modality. In these examples, the electric current sensor may include: (a) one or more sensors 641 and 642; (b) one or more "amplifiers- 647 and 648; (c) one or more- filters 649e-650; (d) one or more phase detectors 651; (e) at least one differential amplifier 652; and (f) at least one 653 scanner.
[0058] In some examples, the system 100 can be configured to assist the user in the proper placement of the pickup device 110 by indicating the appropriate placement with the user communications module 214. In some examples, the system 100 can determine the appropriate placement through detecting a phase difference of approximately 180 degrees between sensors 641 and 642 which are arranged on opposite sides of a conductor (i.e., the electrically powered conductor 193 or 194). In the same example, or in different examples, the user communications module 214 can be colocalized with the pickup device 110 or the user communications module 214 can be used and can be remote and connected to the pickup device 100 via a wireless network.
[0059] The 641 sensor can include: (a) 643 ferromagnetic core; and (b) a pickup coil 644 surrounding the ferromagnetic core 643. Sensor 642 may include: (a) a 645 ferromagnetic core; and (b) a pickup coil 646 that surrounds the ferromagnetic core 645. In several examples, sensors 641 and 642 can be 2.5 millimeters (mm) to 12.7 mm in diameter. In other examples, the electric current sensor 211 includes only sensor 641 and does not include sensor 642, amplifier 647, filter 649, phase detector 651 and / or differential amplifier 652. In this alternative embodiment, filter 649 or 650 is coupled to the 653 digitizer. In additional modalities, the electric current sensor 211 includes four, six, eight or ten sensors.
[0060] The purpose of the ferromagnetic cores 643 and 645 is to concentrate the magnetic field of the pickup coils 644 and 646 to produce a higher sensor output voltage at the output terminals of the pickup coils 644 and 646. The voltage at the output of the pickup coils 644 and 646 is given by Faraday's Law. That is, the voltage depends on the applied AC magnetic field, the physical dimensions of the coil and the wire, the number of turns of the wire in the coil, and the magnetic permeability of the core. In other examples, sensors 641 and 642 do not include ferromagnetic cores 643 and 645, respectively.
[0061] As shown in Figure 7, when the electric current sensor 211 is coupled to the breaker box panel 190, one of the sensors 641 and 642 can be located on each side of a conductor (that is, in the electrical power conductor 193 or 194 ). In this mode, the voltage induced in sensor 641 is 180 degrees out of phase with sensor 642 because the magnetic field enters sensor 642 from the bottom while the magnetic field enters sensor 641 from the top.
[0062] A schematic of the phase relationship between the voltage in sensors 641 and 642 is shown in Figure 8. Referring to Figure 8, when the AC current flowing in the conductor (that is, in the 193 or 194 electric power conductor) induces a voltage V (sensor) in the pickup coils 644 and 646. This voltage, V (sensor) is proportional to the current, I (sensor) carried by the conductor (that is, by the electrical power conductor 193 or 194) that is, V ( sensor) = k * I (sensor). The proportionality constant, k, can be found by extracting a known current through the conductor by temporarily connecting a calibration load (that is, the calibration load module 283 or 227 (Figure 2)) to a served circuit by the conductor (that is, by the electrical power conductor 193 or 194) and measuring the "voltage induced in sensors 641 and 642 (Figure 6). In some cases, more than a known current can be extracted to establish a calibration of multipoint of the proportionality constant.
[0063] Referring again to Figure 6, this configuration of two sensors (that is, sensors 641 and 642) can be exploited to produce a pickup device 110 that automatically communicates to a user that it has been correctly placed in relation to a given conductor carrying current while interference from other sources is rejected, including other nearby conductors. This ability is useful in the electrically noisy environment in a breaker box panel where there are many conductors close to a conductor of particular interest.
[0064] Specifically, in some modality, the output of each of the sensors 641 and 642 can be amplified using the amplifiers 64 8 and 647, respectively and then filtered using the filters 650 and 649, respectively. The output of filters 650 and 649 can be presented to the phase detector 651 coupled to a phase indicator 619 in the user communications module 214 (for example, one or more LEDs). User communications module 214 is configured to indicate to the user that sensors 641 and 642 have been placed correctly in relation to a given conductor carrying current. The user can be instructed to move the sensor over the region where the main electrical power conductors are to be found, and to stop the movement since the phase indicator indicates the phase difference between the signals from sensors 641 and 642 is approximately 180 degrees. For example, when the signals from sensors 641 and 642 are approximately 180 degrees out of phase, a green LED could light up on top of the pickup device 110.
[0065] Amplifiers 648 and 647 and filters 650 and 649 are optional in some examples. The purpose of amplifiers 648 and 647 and filters 650 and 649 is to increase the signal level while rejecting noise at unwanted frequencies and thus increasing the signal to noise ratio of the 641 and 642 sensor signals in noisy environments. Amplifiers 648 and 647 can be operational amplifiers such as type TL082 manufactured by Texas Instruments, Inc. Filters 650 and 649 can be passive heaped element filters or active filters deployed with operational amplifiers. In general, the 650 and 649 filters are bandpass filters configured to pass the AC line frequency (for example, 60 Hz in the USA and Canada, or 50 Hz in Europe and Japan) while out-of-band noise is rejected.
[0066] The phase detector 6 51 can be an analog phase detector circuit or a digital phase detector. A digital phase detector can be deployed with combinational logic, with programmable logic, or in software on a controller. In one embodiment, an integrated phase detector circuit may be employed such as the phase detector contained in the type 4046 or 74HC4046 phase capture loop integrated controllers manufactured by Texas Instruments, Inc. In another embodiment, the phase detector 651 is implemented by digitizing the sensor signals with an analog / digital converter, and then fitting an arcotangent function to the vector of samples received from sensors 641 and 642. In an additional modality, the phase detection and filtering functions are combined using a periodogram-based maximum probability estimator such as a Fast Fourier Complex Transform (FFT) algorithm to find the phase angle and b-signal magnitude only at the AC line frequency while noise is rejected in other frequencies.
[0067] The phase indicator 619 can be any device that indicates to a user that the desired phase relationship between the output signals from sensors 641 and 642 has been achieved. In some embodiments, the phase indicator can be one or more LEDs. In other embodiments, the phase indicator 619 can be a graphical or numeric display such as a liquid crystal display (LCD), or an audio tone that indicates to the user that the voltages of sensors 641 and 642 are approximately 180 degrees out of phase.
[0068] The differential amplifier 652 can be used to combine the signals from sensors 641 and 642 to produce a current or voltage signal proportional to the current in the main electrical power conductor once the correct phase relationship is established. This signal can be used as an input for calculations performed by controller 213. In the same example or in a different example, communications module 215 can be used to transmit data to the computational unit that includes: (a) the proper placement of sensors 641 and 642 as indicated by the phase relationship sensor as well as (b) the signal differentially captured from sensors 641 and 642.
[0069] Turning to another embodiment, Figure 9 illustrates an example of a catching device 910, in accordance with a second embodiment. Figure 10 illustrates an example of a capture device 910 on electrical power conductors 193 and 194, in accordance with the second modality. In this example, a linear array of sensors 941:., 9412, ..., 941N can be used where N is a number between 2 and 10. In other examples, N can be other numbers "such as 4, 6, 8 , 20, 50 Om 100: One purpose of this linear sensor array is to allow controller 213 to automatically select one or more pairs of sensors 9411, 9412, ..., 941N so that the user does not have to manually place the pickup device 910 in the correct placement In some embodiments, the pickup device 910 can be used instead of the pickup device 110 in system 100 of Figure 1.
[0070] Referring to Figures 9 and 10, in this example, the pickup device 910 may include: (a) sensors 941i, 9412, ..., 941N; (b) amplifiers 647 and 648; (c) filters 649 and 650; (d) the 651 phase detectors; (e) the 652 differential amplifier; (f) the 653 digitizer; and (g) at least one multiplexer 955 and 956.
[0071] As shown in Figure 10, the linear array of sensors 9411, 9412, ..., 941N is coupled to multiplexers 955 and 956, which select at least one sensor from the sensors 9411, 9412, ..., 941N for use with a sensor magnetic field to produce a signal proportional to the current in the main electrical power conductors 193 and / or 194.
[0072] In another modality, more than one conductor among the electric power conductors 193 and 194 are simultaneously captured by the capture device 910. In this modality, the controller 213 controls the multiplexers 955 and 956 in such a way that two different sensors from the sensors 9411, 9412 , 941N are selected that are adjacent to two different power conductors that carry different currents 193 and 194. In this mode, controller 213 controls the multiplexers to select sensors based on the amplitude or phase angle of the sensor signal. In some embodiments, the multiple sensors of sensors 9411, 9412, ..., 941N are multiplexed under the control of controller 213 to select different sensors, each of which has preferential magnetic field coupling to a conductor carrying a different current.
[0073] Referring again to Figure 1, system 100 can use calibration in some examples to achieve accurate current measurement in electrical power conductors 193 and 194. The potential need for calibration may be due to poorly controlled geometry, for example, when the catchment device 110 or 910 (Figure 9) is installed by an untrained user.
[0074] Figure 11 illustrates an example of a calibration device 180, in accordance with the first embodiment. Calibration device 180 is shown in Figure 11 as a single circuit calibration device that is configured to switch a single calibration load to a single input conductor (i.e., electrical power conductor 193 or 194) to complete a circuit between the input conductor, the single calibration load, and the neutral or return conductor (that is, the electrical power conductor 195). The switching signal is used to temporarily complete the circuit with the calibration load, which is used by the 1800 calibration method in Figure 18.
[0075] In some examples, the calibration load module 283 may include: (a) a switched load 1105; (b) a 1171 transformer; (c) a 1172 filter; (d) a level 1173 translator; and (e) a framing device 1174. Switched load 1105 can include: (a) a switch 1187 and (b) a calibration load 1188. Controller 285 can include: (a) an analog / digital converter 1177; (b) a digital input 1176; and (c) an 1186 temperature sensor.
[0076] In the embodiment of Figure 11, the calibration load module 283 can be designed to calibrate the measurement of a single conductor carrying current (a feeder for the branch circuit) that is measured by the pickup device 110. In this embodiment, a the single calibration load 118 8 is changed by switch 118 7 between the line conductor (for example, the main electrical power conductors 193 and 194) and the neutral conductor (for example, the main electrical power conductor 195) under control of a switching signal from a 285 controller. In the United States, switched load 1105 can be used with a 120 V outlet. In other countries, switched load 1105 can be used with 240 V and other voltage outlets.
[0077] It should be noted that although the calibration charge 1188 and the calibration charges in Figures 14 to 17 are extracted with a resistor, the calibration charge 1188 and other calibration charges in Figures 14 to 17 can be any charge that includes a charge reactive, such as an inductor or capacitor, with or without a resistive component. In addition, the calibration load can be a load with a variable resistance. Furthermore, it should be noted that although switch 1187 and other switches in Figures 14 to 17 are designed as mechanical relay switches, the switches can be other forms of switching devices. For example, switches can be semiconductor switches such as solid state relays, triacs, transistors such as FETs (field effect transistors), SCRs (silicon controlled rectifiers), BJTs (bipolar joint transistors), or IGBTs ( isolated port bipolar transistors), or other controllable switching devices.
[0078] As shown in Figure 11, the ~ 281 communications module is ~ coupled to controller 285 to allow the transfer of calibrated current measurements from calibration device 180 to computational unit 120. In some examples, communications module 281 may include a receiver and a transmitter. The communications module 281 can include any form of wireless or wired communication device that operates at any frequency and with any data link protocol. In one embodiment, the communications module 281 includes a 2.4 GHz transceiver, part number CC2500, available from Texas Instruments, Inc. In another embodiment, the communications module 281 includes a 900 MHz transceiver, part number CC2010 , available from Texas Instruments, Inc. In some embodiments, the 281 communications module can communicate using any of the following communication protocols: WiFi (IEEE 802.11), Zigbee (IEEE 802.15.4), ZWave or the protocol SimpliciTI. In another modality, an exclusive data communication protocol is employed. In additional modalities, the communication link between the communication module 215 and the communication modules 281 and / or 221 is reached through the monitored conductor. In this mode, the communication link consists of power line (PLC) communication formed by injecting a signal transmitted in at least one branch circuit conductor to which the calibration device is attached.
[0079] In the example shown in Figure 11, power source 289 can include a Power source 289. Power source 289 can include an isolation transformer and a DC power supply. The 289 power supply converts the input line voltage from an AC power line voltage, such as 120 V in the USA and Canada, or 220 V in Europe, to a low DC voltage such as 3.3 V or 5 V DC for power controller 213 and other elements of calibration device 180.
[0080] Controller 285 can receive a sample of the input AC power line voltage, converted by the level translator 1173 to a low voltage AC signal that is proportional to the input AC power line voltage. In some embodiments, the input AC power line voltage is 12 0 V AC while the low voltage AC signal is in the range 0 to 3.3 V. In some embodiments, the 1173 level translator is used to change the low voltage signal of a bipolar signal that alternates between + V and -V to a unipolar signal between 0 V and VDD, or another unipolar signal range that is within the valid voltage range of the 1177 analog / digital converter. The converter analog / digital 1177 can sample the low input voltage signal as shown in Figure 12. In the same or different modes, the 1172 filter can restrict the frequency range of the low voltage signal to the AC line frequency.
[0081] In many instances, the 1177 analog / digital converter can be integrated with controller 285, or can be separated from controller 213, but coupled to controller 285. The sampled AC line voltage allows controller 213 to order the incoming AC line voltage to more accurately calibrate system 100 by calculating the current drawn by the calibration load 1188 given to the sampled low voltage signal, which is proportional to the AC line voltage. In addition, the sampled low voltage signal can be used to develop a phase reference that is synchronous to the AC line voltage.
[0082] In some embodiments, controller 285 uses a square low voltage signal to develop a phase reference. "In these modalities, the framing device 1174 creates the low voltage square signal. The low voltage square signal can be a square wave that has the same period and zero crossing delay as the low voltage AC signal. This relationship between the square signal and the low voltage signal are shown in Figure 13. In some embodiments, the 1174 framing device may include a Schmitt trigger, comparator or digital logic gate such as an inverter or a transistor level changer. square wave amplitude is chosen to be a logic level that is compatible with the 285 controller. The square signal does not contain information about the amplitude of the incoming AC line voltage, but does contain phase information because the positive and negative edges of the square signals are synchronous at zero intersections of the incoming AC line voltage.
[0083] In some embodiments, the phase reference derived from the low voltage signal or its square counterpart is used to measure the relative phase angle between the calibrated current measurement reported by the pickup device 110 and the input power line voltage. This measurement of the relative phase angle between voltage and current is used to accurately account for the power factor of reactive loads connected to the power conductor which is measured by the pickup device 110.
[0084] The power factor is the cosine of the phase angle between the current and voltage waveforms. This power factor can be computed directly from a sampled low voltage signal, or it can be computed indirectly in the case of the square low voltage signal by fitting a sinusoid of the appropriate frequency to the edge transitions in the square signal.
[0085] The power factor is the ratio of the actual power flowing in the conductor compared to the apparent power flowing in the conductor. In some modalities, it is preferred to report to the user of system 100 the real power flowing in the electrical power conductors 193, 194 and 195 to better approximate the reading of an electric power meter supplied by the public service. In these modalities, the phase information provided by the low voltage signal is critical to properly compute the expected power.
[0086] Since the calibration load 1188 dissipates current when switched using switch 1187, the calibration load 1188 is subject to heating. Such heating can endanger the safe operation of the calibration load 1188 causing thermal damage to the calibration load itself 1188, or to other components in the housing of the calibration device 180, or to individuals or things that are close to the calibration device 180.
[0087] In some embodiments, controller 285 includes a temperature sensor 118 6 such as a bimetallic thermostat, a thermistor or a semiconductor temperature sensor. In some embodiments, the temperature sensor 1186 interrupts the switching signal to switch off the calibration load 1188 when the calibration load 1188 or the housing of the calibration device 180 is too hot.
[0088] In additional modes, controller 285 checks the temperature reading from the temperature sensor 1186 before connecting the calibration load 1188 to ensure that the calibration load 1188 or the housing of the calibration device 180 is not too hot at the beginning of the calibration process. calibration. In even further modes, controller 285 can perform an extrapolation to determine whether calibration load 1188 is likely to become too hot after a typical period of operation of calibration load 1188. In this mode, controller 285 acts to delay the calibration process until the process can be completed without the calibration load 1188 or the housing of the calibration device 180 becoming too hot.
[0089] In some embodiments, there are two different control mechanisms by which a controller controls the switching signal for switch 1187. The two methods correspond to two different processor locations that perform the calibration process to obtain a calibrated current measurement.
[0090] In a first method, controller 285 is placed with and controls the calibration load module 283. Controller 285 can also obtain sensor readings from the pickup device 110 (via the communications module 281) and controller 213. The 285 controller performs the calibration process (described below with reference to Figure 18) and obtains the calibrated current measurement. In these examples, calibration calculation module 229 can be located on calibration device 180, not computational unit 120.
[0091] In the first method in which controller 285 performs the calibration process, communications module 281 receives input signal measurements from the pickup device 110 and / or computational unit 120. Controller 285 can calculate the calibrated current measurements with the use of method 2000 in Figure 20. After calculating the calibrated current measurements, the calibration device 180 can communicate the calibrated current measurements to the computational unit 120 for display and other uses.
[0092] In a second method, a remote processor, such as controller 225 (Figure 2) or controller 213 (Figure 2), controls the calibration load 1188 for the on and off switch and that controller (controller 225 or controller 213) performs the 1800 calibration method in Figure 18 and obtains the calibrated current measurement as described in Method 2000 in Figure 20.
[0093] When the second method is being used with controller 225 to control calibration, controller 225 receives a message through a communication link from controller 285. In some embodiments, controller 225 sends a message to connect the calibration load for one specified period of time. In some embodiments, this time period is selected from one or more predetermined time periods. In other embodiments, the calibration load 118 8 is switched on until a shutdown message is received by the controller 285 or until the end of an interval timer or the activation of the temperature sensor 1186 indicating that the calibration load 1188 or its housing it's too hot.
[0094] In additional modalities, controller 285 makes an independent decision to switch on the calibration load for a particular period of time. In some examples, controller 285 turns calibration load 1188 on and off for a particular period of time, while simultaneously, previously, or later sends a notification to controller 225 indicating that calibration load 1188 has been turned on. In this embodiment, controller 213 uses a known time offset between messages received from controller 285 to synchronize the flow of the calibration procedure to the on / off terms of calibration load 1l88 indicated by a message received from controller 285 via a communication link. In additional examples, controller 285 turns calibration load 1188 on and off in a sequence that is known to controller 213 and / or 225 (Figure 2).
[0095] Figure 11 illustrates an example of switched load 1105 on calibration device 180. Other possible configurations of switched load are shown in Figures 14 to 17.
[0096] Specifically, Figure 14 illustrates an example of switched load 1405, in accordance with a third embodiment. Switched load 1405 can include: (a) switches 1187 and 1442; and (b) the calibration loads 1188 and 1441. In this embodiment, the switched load 1405 replaces the switched load 1105 in the calibration device 180 of Figures 2 and 11.
[0097] In this mode, the switched load 14 05 can be configured to calibrate the measurement of a single conductor carrying current (a feeder for the branch circuit labeled "Line") which is measured by a pickup device 110. In this mode, the Controller 285 can switch between calibration loads 1188 and 1441 to provide two different measurement sets for use in the calibration process. In other examples, switched load 1405 can include three or more tries switches or more calibration loads.
[0098] Figure 15 illustrates an example of load switching 1505, in accordance with a fourth embodiment. Switched load 1505 can include: (a) switches 1587 and 1542; and (b) the calibration loads 1588 and 1541. In this embodiment, the switched load 1505 replaces the switched load 1105 in the calibration device 180 of Figures 2 and 11.
[0099] In this modality, the switched load 1505 can be designed to calibrate the mediation of two conductors that carry the current (a feeder for the branch circuit labeled "Line 1" and "Line 2") that is measured by the pickup device 110. In this mode, two different calibration loads 1588 and 1541 can be switched between the individual line conductors and the neutral conductor under the control of a switching signal from controller 285. Controller 285 can control switching signals to electrically couple calibration loads as Follow:
[0100] Figure 16 illustrates an example of switched load 1605, in accordance with a fifth embodiment. Switched load 1605 can include: (a) switches 1687, 1642 and 1643; and (b) the calibration loads 1588 and 1541. In this embodiment, the switched load 1605 replaces the switched load 1105 in the calibration device 180 of Figures 2 and 11.
[0101] In this mode, the switched load 1605 can also be configured to calibrate the measurement of more than one conductor carrying the current (a feeder for the branch circuit labeled "Line 1" and "Line 2") that is measured by the device pickup 110. In this mode, two different calibration loads 1588 and 1541 are switched to allow the calibration loads 1588 and 1541 to be connected individually to a neutral return, or in a pair with the Line 1 / Line 2 pair as required. common in a split-phase power system. The 285 controller can control the switching signals to electrically couple the calibration loads as follows:
[0102] Figure 17 illustrates an example of switched load 1705, in accordance with a sixth embodiment. The switched chamber 1705 can include: (a) the switches 1787, 1742 and 1743; and (b) the 1788 calibration load. In this embodiment, the switched load 1705 replaces the switched load 1105 in the calibration device 180 of Figures 2 and 11.
[0103] In this mode, the switched load 1705 is also configured to calibrate the measurement of more than one current-carrying conductor (a feeder for the branch circuit labeled "Line 1" and "Line 2") which is measured by the capture 110. In this mode, a single 1788 calibration load is switched to allow calibration of two conductors plus a neutral as is common in a split phase power system. Switches 1787 and 1743 can be unipolar two-way switches (SPDT). Switches 1787 and 1743 can be used with the 1788 calibration load to couple different combinations of the branch circuit conductors. The switched load 1705 may be cheaper to deploy compared to the switched load 1605 (Figure 16) due to the single calibration load employed. The 285 controller can control the switching signals to electrically couple the calibration loads as follows:
[0104] In many instances, both electrical infrastructure phase lines need to be calibrated. Consequently, one of the calibration devices of Figures 11 and 14 to 17 would need to be connected on a first phase branch and on the second phase branch. In the example shown in Figure 2, calibration device 180 is the first calibration device and computational unit 120 includes the second calibration device. In other examples, a single calibration device (for example, a calibration device with one of a switched load 1505, 1605 or 1705) can be attached to a 240 V outlet, which is attached to both the first and the second branch of phase.
[0105] In the mode in which one of the calibration devices in Figures 11 and 14 to 17 is connected to each of the first phase branch and the second phase branch, the calibration devices must be able to communicate with each other, with the capture device and the computing unit. Several different methods of communication could be implemented. For example, all calibration devices could receive and transmit data. In other examples, a calibration device (for example, calibration device 180 in Figure 1) could transmit data and the second calibration device (for example, computational unit 120 in Figure 2) could receive data.
[0106] In some embodiments, the two calibration devices may be in radio communication. For example, communications module 281 and communications module 221 of Figure 2 can include a radio. The calibration devices are configured to determine if they are on different electrical phase branches by reporting the phase angle of the 60 Hz cycle observed for other calibrators. In some instances, a “calibration device” may report wirelessly to the other calibration device when a zero intersection occurs in the electrical current or voltage. An overlap in the received wireless messages will occur in the messages when both calibration devices are installed on the same electrical phase branch. If there is a deviation between the observed zero intersection and the message received, the calibration devices are installed on different electrical phase branches.
[0107] In the same or a different example, user communication device 184 on calibration device 180 (Figure 1) can include a single red / green LED. A green LED can indicate that the two calibration devices are installed correctly in the two different phases. For example, the user first installs the calibration device 180 in Figure 1 (that is, the transmission calibration device) in an arbitrary electrical outlet. Then, the user installs the computational unit 120 of Figure 1 (that is, the reception calibration device) in another electrical outlet. The LED on user communication device 184 may light red to indicate that both are on the same phase or green if they are on different phase branches. The user can move the second calibrator to different outlets until the green indicator on user communication device 184 is shown.
[0108] In other modalities, wireless communication can also exist between each of the pickup device 110, the calibration device 180 and the computational unit 120. In this mode, the pickup device 110 can detect the two electrical phases on the circuit breaker panel. As the calibration device 180 is switched through its electrical charges, the calibration device 180 can notify the pickup device 110 and the pickup device 110 can determine which phase the calibration device 180 is coupled to. The computational unit 120 can also report to the capture device 110 when its charge cycle begins. The capture device 110 observes at which phase angles these changes are taking place to infer that the calibrators are installed in two different phases.
[0109] In yet another example, a communication method that is not wireless can be used can communicate between calibration device 180 and computational unit 120. In these examples, communication modules 221 and / or 281 can include a signal injector and / or signal receiver. In this example, calibration device 180 and computational unit 120 can send a signal across the electrical power infrastructure. For example, a simple 1 kHz (kilohertz) tone can be used. In the same example, or in different examples, the signal consists of an amplitude modulated voltage injected into one or more conductors of the electrical power infrastructure. In another mode, the signal consists of a modulated current in amplitude extracted from the electrical power infrastructure.
[0110] In an additional modality, the signal consists of a frequency modulated voltage or current. In one embodiment, computational unit 120 may be designated as a signal transmitter, while calibration device 180 may be designed as the receiver. When the calibration device 180 is plugged into an electrical outlet, user communication device 184 may light a green LED if it is not possible to detect the presence of the signal being transmitted by the first device. If the calibration device 180 and the computational unit 120 are coupled to separate phase branches, the calibration device 180 and the computational unit 120 could not detect placement signals in the electrical power infrastructure on the other.
[0111] If the calibration device 180 detects the signal, when a red light comes on it can indicate that the two calibration devices are in the same phase. At this point, the user can be instructed to move one of the calibration device 180 or computer unit 120 to a different electrical outlet. In yet another embodiment, instead of communications modules 221 and 281 that include an injector and / or signal receiver, communications modules 221 and 281 can include power line communication modules (PLC) to allow the calibration device 180 and computational unit 120 communicate across the electrical power infrastructure.
[0112] Turning to another modality, Figure 18 illustrates a flowchart for a modality of an 1800 method of calibrating an electrical monitoring system, in accordance with one modality. The 1800 method is merely exemplary and is not limited to the modalities presented in this document. The 1800 method can be used in many different modalities or examples not specifically represented or described in this document. In some modalities, the 1800 method activities, procedures and / or processes can be performed in the order presented. In other modalities, the 1800 method activities, procedures and / or processes can be carried out in any other appropriate order. In still other embodiments, one or more of the activities, procedures and / or processes in the 18 0 0 method can be combined or ignored.
[0113] The 1800 method can be considered to describe a general method of calibrating a pickup device. This method may involve determining one or more calibration coefficients that can be used to calculate the current predicted in the electrical power infrastructure of the structure in the 2000 method of Figure 20. The method described below can be used to accurately calculate the coefficients of calibration regardless of the position of the pickup device 110 (Figure 1) on panel 196 (Figure 1) with the exception of the following points: (a) whether the current sensors 211 (Figure 2) are placed so far from the power conductors main 193 and 194 (Figure 1) that almost no noticeable signal from the main power conductors 193 and 194 is measured; and (b) if all the electric current sensors 211 (Figure 2) are placed very close to the neutral electrical power conductor 195 (Figure 1) and away from the electrical power conductors 193 and 194.
[0114] Method 1800 in Figure 18 includes an 1860 activity for obtaining and storing one or more first baseline measurements. In some examples, the pickup device 110 (Figure 2) can be used to obtain first baseline measurements with the use of electric current sensors 211 (Figure 2). These first baseline measurements can include the rated current that flows in at least one of the 193 or 194 power conductors (Figure 1) due to the electrical devices that are drawing electrical power. In addition, for each sensor (for example, sensors 641 and 642 (Figure 6) or sensors 9411, 9412, ... 941N (Figure 9)), a phase and amplitude measurement can be made. Each amplitude reading, L, is stored with the name Lveiha-N and each phase reading, ø, is stored with the name øvelha-N where N is the sensor number. In some examples, the first baseline measurements are made on both the first phase branch and the second phase branch.
[0115] In some examples, activity 1860 also includes determining the phase angle and amplitude of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some examples, the voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.
[0116] Thereafter, method 1800 of Figure 18 includes a temporary 1861 coupling activity of a first known calibration charge to the first phase branch. In some examples, the calibration device 180 (Figures 1 and 11) can be coupled to one of the calibration loads in the switched loads 1105, 1405, 1505, 1605 or 1705 of Figures 11, 14, 15, 16, and 17, respectively .
[0117] Then, the 1800 method of Figure 18 includes an 1862 activity of obtaining and storing one or more first calibration measurements in the first phase branch. In some instances, the pickup device 110 (Figure 2) can be used to obtain the first calibration measurements for the electric current sensors 211 (Figure 2). In some examples, the first calibration measurements are performed while a known calibration load of the switched load 1105, 1405, 1505, 1605 or 1705 of Figure 11, 14, 15, 16 and 17, respectively, is coupled to the first phase branch (for example, Line 1 in Figures 15 to 17). This first known calibration load will draw a known Lcal-1 current. These first calibration measurements may include the rated current flowing in at least one of the 193 or 194 power conductors (Figure 1) due to the tools that are drawing electrical power and the first known calibration load.
[0118] For example, on each sensor (for example, on sensors 641 and 642 (Figure 6) or on sensors 9411, 9412, ... 941N (Figure 9)), a measurement of phase angle and amplitude is made. Each amplitude reading, L, is stored with a name such as Lnova-N-1 and each phase angle reading, ø, is stored with a name such as ønova-N-1, where N is the sensor number .
[0119] In some examples, activity 1862 also includes determining the phase angle and amplitude of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some examples, the voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.
[0120] Method 1800 in Figure 18 continues with an activity 1863 of disconnecting the first known calibration charge and temporarily coupling a second known calibration charge to a second phase branch. In some examples, the calibration device 180 (Figures 1 and 11) can be coupled to one of the calibration loads in the switched load 1405, 1505 or 1605 of Figures 14, 15 and 16, respectively. In some examples, the second known calibration charge is coupled to a second phase branch (for example, Line 2 in Figures 15 to 17).
[0121] Thereafter, method 1800 in Figure 18 includes an 1864 activity for obtaining and storing second calibration measurements in the second phase branch. In some examples, the pickup device 110 (Figure 2) can be used to obtain the second calibration measurements - of the electric current sensors 211 (Figure 2). These second calibration measurements may include the nominal current that flows in at least one of the 193 or 194 power conductors (Figure 1) due to the utensils that are drawing electrical power and the second known calibration load. In some examples, second calibration measurements are performed while a known calibration load is coupled to the second phase branch (for example, Line 2 in Figures 15 to 17). The second known calibration load will pull a known current Lcal-2 ·
[0122] For example, on each sensor (for example, sensors 641 and 642 (Figure 6) or sensors 9411, 9412, ... 941n (Figure 9)), a measurement of phase angle and amplitude is made. Each amplitude reading, L, is stored with the name LnoVa-N-2 and each phase angle reading, ø, is stored with the name such as ønova-N-2 where N is the sensor number.
[0123] In some examples, activity 1864 also includes determining the phase angle and voltage amplitude. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some examples, the voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.
[0124] Thereafter, method 1800 of Figure 18 includes an activity 1865 for disconnecting any known calibration charges (i.e., the second calibration charge) from power conductors 193, 194 and / or 195 (Figure 1).
[0125] Method 1800 in Figure 18 continues with an activity 18 66 for obtaining and storing one or more second baseline measurements. In some instances, the pickup device 110 (Figure 2) can be used to obtain baseline second measurements from the electric current sensors 211 (Figure 2). These second baseline measurements can include the rated current that flows in at least one of the 193 or 194 power conductors (Figure 1) due to the appliances that are drawing electrical power. The purpose of this second baseline reading is to ensure that the baseline load seen in activity 1861 has not changed during the calibration process. If the measurements in activity 1866 are the same as the measurement in 18 61 within a predetermined amount, measurements in activity 1866 can be discarded. If the measurements in activity 1866 are outside the predetermined quantity, the 1861 measurement can be discarded. In other examples, activity 1866 can be ignored.
[0126] In some examples, activity 1866 also includes determining the phase angle and amplitude of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some examples, the voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.
[0127] Subsequently, method 1800 in Figure 18 includes an activity 1867 for determining the calibration coefficients. In some examples, activity 1867 includes the application of a sensor calibration equation (s) to the baseline measurement and each of the calibration measurements to solve the calibration factors of the pickup device 110 (Figure 1 ) to produce a calibrated current measurement on at least one conductor that is picked up by the pickup device 110. In some examples, the calibration calculation module 229 (Figure 2) can determine the calibration coefficients as described below.
[0128] Figure 19 illustrates a flow chart for an exemplary modality of activity 1867 for determining the calibration coefficients, in accordance with the first modality. In some examples, activity 1867 may broadly include the calculation of the calibration coefficients, øM, K1, K2, Y1 and Y2. In other examples, other calibration coefficients can be determined.
[0129] Referring to Figure 19, activity 1867 includes a 1971 procedure for determining potential calibration coefficients for the first phase branch. In some examples, for each sensor 1 through N (where N is the number of sensors in the current sensor), the 1971 procedure may include the calculation of XN-1 and øm-n-1 with
[0130] Referring to Figure 19, activity 1867 includes a 1971 procedure for determining potential calibration coefficients for the first phase branch. In some examples, for each sensor 1 through N (where N is the number of sensors in the current sensor), the 1971 procedure may include the calculation of XN-1 and øm-n-1 with THE USE OF LVelha-N, øvelha-N, Lcal -1, Lnova-N-1 and ønova-N-1 / que: Xn-1 = [✓ {Lvelha-N2 + Lnova-N-1 - 2 * Lvelha-N * Lnova-Nl * COS (øvelha-N - ønova-N-1)}] / Lcal-1 and øM-N-1 = ønova-Nl - Sin-1 [(Lvelha-N * Sin (øvelha-N - ønova-Nl)) / (XN-1 * LCal-1)] In addition, in some examples, if øm-ni> 180 °, So øM-N-1 = øM-N-1 - 180 ° and XN-1 = Xn-i * (-1)
[0131] Activity 1867 in Figure 19 continues with a 1972 procedure for determining potential calibration coefficients for the second phase branch. In some examples, for each sensor 1 through N, the 1972 procedure may include the calculation of XN-2 and øm-n-2 with THE USE of Lvelha-N, øvelha-N, Lcal-2, Lnova-N-2 and ønova-N-2 where: XN-2 = [✓ {Lvelha-N2 + Lnova_N-2-2 * Lvelha_N * Lnovva-N-2 * COS øvelha-N - ønova-N-2)}] / Lcal-2 and øM-N-2 = ønova-N-2 - Sin-1 [(Old-N * Sin (øvelha-N - ønova-N-2)) / (Xn-2 * Lcal-2)] In addition, in some examples, if øm-n-2> 180 °, then øM-N-2 = øM-N-2- 180 ° and Xn-2 = XN-2 * (-1)
[0132] Subsequently, activity 1867 in Figure 19 includes a 1973 procedure for verifying the validity of measurements. In the 1973 procedure, if øM-Ni = øm-n-2 within a predetermined tolerance (for example 0.1%, 1%, 5%, 10% or 20%) for each sensor 1 through N, the measurements for the sensor are maintained. If øm-n-i * øm-n-2, within the predetermined tolerance, the phase angles for that sensor are discarded.
[0133] Then, activity 1867 in Figure 19 includes a 1974 procedure for determining a statistical mode, ømodo / for øm-ni for sensors not discarded in the 1973 procedure. In some examples, the statistical mode is the phase angle that occurs with more frequency within the predetermined tolerance for sensors not discarded in the 1973 procedure.
[0134] Activity 1867 in Figure 19 continues with a 1975 procedure for determining a first part of the calibration coefficients. In some examples, of the remaining sensors, the 1975 procedure includes choosing the sensor with the highest XN-1 value and assigning XN-1 = K1 and XN-2 = K2 and øM-N-1 = øM-K · That sensor chosen will be referred to as the K sensor from now on. The K sensor can be dropped from the list of available sensor candidates for the rest of activity 1867.
[0135] Subsequently, activity 1867 in Figure 19 includes a 1976 procedure for determining a second part of the calibration coefficients. In some examples, of the remaining sensors, the 1976 procedure includes choosing the sensor with the highest XN-2 value and assigning XN-2 = Y1 and XN-2 = Y2 and øm-n-2 = øM-Y · That sensor chosen will be referred to as the Y sensor from now on.
[0136] Then, activity 1867 in Figure 19 includes a 1977 procedure for determining a third part of the calibration coefficients. In some examples, øM is calculated where: øM = [øM-Y + øM-K] / 2
[0137] The example of the formulas used to determine the calibration coefficients above is just an example. In other examples, other formulas (for example, linear, nonlinear, quadratic and / or iterative equations) can be used to calculate the same calibration coefficients or different calibration coefficients.
[0138] For example, the pickup device can be calibrated (and the predicted current determined) using only the sensor. In this example, the sensor is placed in such a way that the magnetic field of the main electrical power conductors 193 and 194 (Figure 1) is symmetrical in the sensor. That is, the magnetic field of the main electrical power conductors 193 and 194 (Figure 1) is symmetrical in the sensor. In addition, in this example, the Z sensor is in a location where the magnetic field of the main electrical power conductor 195 (Figure 1), which represents the neutral return conductor, is small and can be ignored.
[0139] At this point the sensor will be called in which the magnetic fields are symmetric Z sensors. In this example, the current measured at the Z sensor is equal to Lz = Kz * Lprevista where Lz is the current measured by the sensor Z, Kz and a constant, and Lprevista is the combined current predicted in the first phase branch and in the second phase branch.
[0140] In this example, the baseline current measurement made on the Z sensor in activity 1860 or 1866 can be stored as Lz-baseline · The first calibration measurements made on the Z sensor can be stored in Lz_ cal and the current from the first known calibration load can be ΔΡ. In this example, Kz can be calculated where: Kz = (Lz-cal - Lz-baseline) / AP
[0141] In other examples, other calibration equations can be used that require more than two calibration measurements. In these examples, activities 1861 to 1866 (Figure 18) can be repeated as much as necessary with different calibration loads to obtain the required number of calibration points.
[0142] After the 1977 procedure is completed, activity 1867 for calculating the calibration coefficients is completed.
[0143] Referring again to Figure 18, method 1800 in Figure 18 continues with an activity 1868 for storing the calibration coefficients. In some examples, the calibration coefficients can be stored in the memory 226 of the computational unit 120 of Figures 1 and 2. In the same example, or in different examples, the calibration coefficients can be stored in the memory of the capture device 110 and / or of the calibration device 180 of Figure 1. In still other modalities, the calibration coefficients can be transmitted to a remote server for storage and use. After activity 1868, method 1800 is completed.
[0144] Figure 20 illustrates a flowchart for a method of a 2000 method of determining the predicted current in the electrical power conductors. The 2000 method is merely an example and is not limited to the modalities presented in this document. The 2000 method can be used in many different modalities or examples not specifically represented or described in this document. In some modalities, the activities, procedures and / or processes of the method 2000 can be performed in the order presented. In other modalities, the activities, procedures and / or processes of the method 2000 can be carried out in any other appropriate order. In still other modalities, one or more of the activities, procedures and / or processes in method 2000 can be combined or ignored.
[0145] Method 2000 describes a general method of determining the predicted electrical power (and / or electrical current) used in electrical power conductors. This method involves the use of several predetermined calibration coefficients (see method 18 in Figure 18) to determine the current predicted in the electrical power infrastructure of the structure. The method described below can be used to accurately calculate the predicted currents regardless of the position of the catch device 110 (Figure 1) on panel 196 (Figure 1) with the exception of the following points: (a) if the electric current sensors 211 (Figure 2) are placed so far from the main power conductors 193 and 194 (Figure 1) that almost no perceptible signal is measured; and (b) if all electrical current sensors 211 (Figure 2) are placed very close to the neutral electrical power conductor 195 (Figure 1) and away from electrical power conductors 193 and 194. In some examples, the 2000 method can include, in a broad way, the calculation of the predicted, L1-predicted and L2-predicted current (as would be reported by the electric utility that supplies the electric power) in each branch of the electric power infrastructure (for example, the first and the second phase ramifications).
[0146] In some examples, method 1800 in Figure 18 and method 2000 can be combined to create a method of using a power consumption meter. Alternatively, method 1800 in Figure 18 combined with method 2 0 00 can be considered a method of determining the predicted current (and / or electrical power) in the electrical power conductors. In these modalities, method 1800 can be performed once to determine the calibration coefficients and method 2000 can be performed repeatedly before to determine the predicted current (and / or electrical power) that is used by the load of the structure at various times.
[0147] Referring to Figure 20, method 2000 includes an activity 2061 of making a first set of measurements using a first electric current sensor. In several modalities, one of the electric current sensors 211 (Figure 2) can be used to perform the first set of measurements. In some examples, activity 2061 may include measuring a phase angle and amplitude at the K sensor. The amplitude reading can be stored under the name LK and the phase angle reading can be stored under the name øK.
[0148] In some examples, activity 2061 also includes determining the phase angle and voltage amplitude. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some examples, the voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.
[0149] Subsequently, the method 2000 of Figure 20 includes an activity 2062 of making a second set of measurements using a second electric current sensor. In several modalities, one of the electric current sensors 211 (Figure 2) can be used to perform the first set of measurements. In some examples, activity 2063 may include measuring a phase angle and current amplitude at the Y sensor. The amplitude reading can be stored under the name LY and the phase angle reading can be stored under the name øY.
[0150] In some examples, activity 2062 also includes determining the phase angle and voltage amplitude. As discussed above, the phase angle of the current is equal to the phase angle measured by the sensor minus the phase angle of the voltage. In some instances, the voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.
[0151] Then, method 2000 in Figure 20 includes an activity 2063 for determining an expected electrical power used in a first phase branch. In some examples, activity 2063 may include determining the amplitude, Lu., Of the first phase branch and the phase angle, ø1, of the first phase branch using the calibration coefficients øM, K1, K2, Y1 and Y2 where: L1 = [✓ {(LK / K2) 2 + (Ly / Y2) 2 - 2 * * (LK / K2) * (LY / Y2) * Cos (øK - øγ)}] / [(Κ1 / Κ2) - ( Y1 / Y2)] and ø1 = Tan-1 [{(Lk / K2) * Sin (øK - øM) - (Ly / Y2) * Sin (øY - øm)} / {(Lk / K2) * Cos (øK - øM) - (Ly / Y2) * Cos (øy - øm)}]
[0152] In some examples, the predicted power, P1. predicted / in the first phase branch can be the electrical power in the first phase branch as reported by the electrical utility In some modalities, the predicted current, L1_previcted / in the first phase branch is: Pl-predicted = V * L1 * COS (ø1) where V is the voltage measured in activity 2062.
[0153] The 2000 method in Figure 20 continues with a 2064 activity of determining an expected electrical power used in a second phase branch. In some examples, activity 2064 may include determining the amplitude, L2, of the second phase branch and the phase angle, ø2, of the second phase branch using the øM, K1, K2, Y1 and Y2 calibration coefficients on what: L2 = [✓ {(LK / K1) 2 + (Ly / Y1) 2 - 2 * (LK / K1) * (LY / Y1) * Cos (øK - øγ)}] / [(K2 / K1) - ( Y2 / Y1)] and ✓2 = Tan-1 [{(Lk / K1) * Sin (øK - øM) - (LY / Y1) * Sin (øY - øM)} / {(Lk / K1) * Cos (øk - øm) ( LY / Y1) * Cos (øy - øm)}]
[0154] In some instances, the predicted electrical power, P2 - expected / in the second phase branch may be the electrical power in the second phase branch as reported by the public utility. In some embodiments, the predicted current, P2-predicted / in the second phase branch is: Expected P2 = V * L2 * COS (ø2) where V is the voltage measured in activity 2062.
[0155] In a second example where the pickup device is using only one Z sensor, determining the expected power, Pprevista is relatively simple. In this example, the Z sensor was placed in such a way that the magnetic field of the main electrical power conductors 193 and 194 (Figure 1) is symmetrical in the Z sensor and the Z sensor is in a location where the magnetic field of the main electrical power conductor 195 (Figure 1) is small and can be ignored. In this example, the electrical power measured at the Z sensor can be calculated where: Pprevista = V * Lz / Kz and where V is the voltage measured in activity 2062, Lz is the current measured by sensor Z in activity 2061, Kz is a constant (already determined in activity 1867 in Figure 18).
[0156] Method 20 00 in Figure 20 continues with an activity 2065 of using and / or reporting the current predicted in the first and second phase branches. The total predicted electric power, Pprevista, is the sum of the predicted electric power in the first phase branch and the predicted electric power in the second phase branch: Pprevista = P2-predicted + P1-predicted
[0157] In some examples, the electrical power used by the load on the structure (ie, Pprevista) can be displayed to the user on the user communications device 134 of computational unit 120 (Figures 1 and 2). In other examples, the electrical power used (and / or the predicted current) can be communicated to the electrical utility that supplies the electrical power or can be reported to other entities.
[0158] In still other modalities, the predicted current can be used in the breakdown of loads based on the change in step and phase angle between the observed voltage and current. Computational unit 120 can determine and assign a step change (the increase or decrease in current) to one or more electrical devices in the structure to indicate its use. Additional disaggregation can be achieved by observing the presence of 120 V and 240 V utensils of the current data in each phase branch In addition to adding current phase changes, step changes in each individual phase branch additionally identify the presence of a different tool or load (that is, similar loads installed at different locations in the building). The change in the phase angle observed due to the internal reactance of a device allows the identification of inductive loads (that is, fans, motors, microwaves, compressors).
[0159] The expected reactance is not required, but instead the observed gross phase angles are sufficient contact that are associated with an a priori device. In some instances, the momentary change in current consumption in the electrical power infrastructure can be a starting feature of a device, which can characterize household appliances. This technique involves using models compatible with a known boot signature library to classify unknown loads. This characteristic space is much less susceptible to overlapping categories of devices and has the ability to separate many devices with similar load characteristics. For example, two engines with similar reactive and actual power consumption can exhibit highly different starting aspects and thus be disaggregated. This approach may be appropriate for electrical devices that consume large current loads or at least consume large currents during startup. With the use of these activities, the loads in the electrical power infrastructure can be disaggregated.
[0160] After activity 2065, method 2000 is completed. Figure 21 illustrates an example of a first location of two electric current sensors in relation to the main electrical power conductors 193, 194 and 195 (Figure 1), in accordance with one modality. The location of the two electrical current sensors shown in Figure 21 was used to test the 1800 calibration method in Figure 18 and the current determination method 2000 in Figure 20. Loads coupled to the main electrical power conductors 193, 194 and 195 ( Figure 1) were randomly turned on and off. While randomly switching the loads on and off, the actual current was monitored using a current monitor. The predicted currents were also calculated using the methods 1800 and 2000 of Figures 18 and 20 after measurements were taken with the two electric current sensors. Figure 22 illustrates a graph that compares the currents predicted by the methods of Figures 18 and 20 against the measured currents. As shown in Figure 22, the predicted currents closely mirror the measured currents.
[0161] Figure 23 illustrates an example of a second location of two electrical current sensors in relation to the main electrical power conductors 193, 194 and 195 (Figure 1), in accordance with an embodiment. The location of the two electrical current sensors shown in Figure 23 was also used to test the 1800 calibration method in Figure 18 and the current determination method 2000 in Figure 20. The loads coupled to the main electrical power conductors 193, 194 and 195 (Figure 1) were turned on and off randomly. While the loads were randomly switched on and off, the actual current was monitored using a current monitor. The predicted currents were also calculated using the 1800 and 2000 methods after measurements were taken with the two electric current sensors. Figure 24 illustrates a graph that compares the currents predicted by the methods of Figures 18 and 20 against the measured currents. As shown in Figure 24, the predicted currents closely mirror the measured currents.
[0162] Although the invention has been described with reference to specific modalities, those skilled in the art will understand that various changes can be made without departing from the spirit or scope of the invention. Accordingly, disclosure of the modalities of the invention is intended to be illustrative of the scope of the invention and is not intended to be limiting. The scope of the invention is expected to be limited only to the degree required by the appended claims. For example, for an individual of ordinary skill in the art, it will be readily apparent that activities 1860, 1861, 1862, 1863, 1864, 1865, 1866, 1867 and 1868 in Figure 18, procedures 1971, 1972, 1973, 1974, 1975 , 1976 and 1977 in Figure 17, and activities 2061, 2062, 2063, 2064 and 2065 in Figure 20 can consist of many different activities and procedures and can be performed by many different modules, in many different orders than any element in Figure 1 can be modified and that the previous discussion of some of these modalities does not necessarily represent a complete description of all possible modalities.
[0163] All elements claimed in any particular claim are essential to the modality claimed in that particular claim. Consequently, the replacement of one or more elements claimed or constitutes reconstruction and not repair. In addition, benefits, other advantages and solutions to problems have been described in relation to specific modalities. The benefits, advantages and solutions to problems, and any element or elements that may cause any benefit, advantage or solution to occur or become stronger, however, should not be interpreted as elements, critical, required, or essential aspects of any or all claims, unless such benefits, advantages, solutions or elements are cited in such claim.
[0164] Furthermore, the modalities and limitations disclosed in this document are not dedicated to the public under the doctrine of dedication to the modalities and / or limitations: (1) it is not expressly claimed in the claims; and (2) are or are potentially equivalent to elements and / or limitations expressed in the claims under the doctrine of equivalents.

权利要求:
Claims (20)
[0001]
Method for using a power consumption measuring device, in which the power consumption measuring device is mechanically coupled to a surface of a circuit breaker box, with the circuit breaker box overlapping at least part of a or more main electrical supply conductors for a structure's electrical power infrastructure, the method being characterized by the fact that it comprises: determine (1860) one or more first magnetic field readings from one or more main electrical supply conductors with the use of one or more sensors in the power consumption measuring device; after determining one or more first magnetic field readings, electrically couple (1861) a first calibration load to the electrical power infrastructure; while the first calibration load remains electrically coupled to the electrical power infrastructure, determine (1862) one or more second magnetic field readings from one or more main electrical supply conductors using one or more sensors in the measuring device power consumption; calibrate (1867) the power consumption meter using at least part of one or more first magnetic field readings and one or more second magnetic field readings, and calibrate the power consumption meter comprises: determining one or more first calibration coefficients for the power consumption measuring device using at least part of one or more first magnetic field readings and one or more second magnetic field readings; after calibrating the power consumption meter, determine (2061) one or more third magnetic field readings from one or more main power supply conductors using one or more sensors on the power consumption meter ; and determine (2063) an electrical power used by the electrical power infrastructure of the structure using at least one or more third magnetic field readings and one or more first calibration coefficients, where: one or more sensors in the power consumption meter are not electrically coupled in series with or physically coupled directly to one or more main electrical supply conductors in the circuit breaker box when one or more sensors in the power consumption meter are attached to the surface of the circuit breaker box.
[0002]
Method, according to claim 1, characterized by the fact that it comprises: electrically couple a second calibration load to the electrical power infrastructure; and while the second calibration load remains electrically coupled to the electrical power infrastructure, determine one or more fourth magnetic field readings using one or more sensors in the power consumption measurement device, where: calibrating the power consumption measuring device comprises: determine one or more first calibration coefficients for the power consumption measuring device using at least part of one or more first magnetic field readings, one or more second magnetic field readings and one or more fourth readings magnetic field.
[0003]
Method according to either of claims 1 or 2, characterized by the fact that: one or more sensors comprise a first sensor; and the first sensor among one or more sensors is in a location, in relation to one or more main electrical supply conductors, so that a magnetic field of a first phase branch and a second phase branch of the electrical power infrastructure is symmetrical in the first sensor of one or more sensors.
[0004]
Method according to any one of claims 1, 2 or 3, characterized by the fact that: determining electrical power comprises: determine the electrical power used by the electrical power infrastructure of the structure using at least one or more third magnetic field readings, one or more first calibration coefficients, and a voltage drop by the electrical power infrastructure of the structure.
[0005]
Method according to any one of claims 1, 2, 3 or 4, characterized by the fact that: determining one or more first calibration coefficients comprises: use one or more first magnetic field readings and one or more second magnetic field readings in one or more sensor calibration equations to determine one or more first calibration coefficients.
[0006]
Method according to any one of claims 1, 2, 3, 4 or 5, characterized by the fact that: one or more first magnetic field readings comprise a measured current and a phase angle measurement of the measured current; and the phase angle measurement of the measured current is relative to a phase of a measured voltage.
[0007]
Method according to any one of claims 1, 2, 3, 4, 5 or 6, characterized by the fact that it further comprises: decouple the first calibration load from the electrical power infrastructure before determining one or more third magnetic field readings.
[0008]
Method according to any one of claims 1, 2, 3, 4, 5, 6 or 7, characterized by the fact that: electrically coupling the first calibration load to the electrical power infrastructure comprises: receive a communication from a calibration device that the first calibration charge has been electrically coupled to the electrical power infrastructure, where the calibration device comprises the first calibration charge.
[0009]
Method for calibrating a magnetic field sensor device, in which the magnetic field sensor device is attached to a first surface of a circuit breaker box, the circuit breaker box overlapping at least part of an electrical power infrastructure of a building, the electrical power infrastructure having a first phase branch and a second phase branch, with the magnetic field sensor device comprising two or more magnetic field sensors, the method characterized by the fact that it comprises: determine (1862), by means of the magnetic field sensor device, a first amplitude and a first phase angle of a first magnetic field in the two or more magnetic field sensors of the magnetic field sensor device while the magnetic field is coupled to the first surface of the circuit breaker box; after a first charge has been coupled to the first phase branch of the electrical power infrastructure, determine (1864), by means of the magnetic field sensor device, a second amplitude and a second phase angle of a second magnetic field in the two or more magnetic field sensors from the magnetic field sensor device while the magnetic field sensor device is coupled to the first surface of the breaker box and while the first load is coupled to the first phase branch; after the first charge has been decoupled from the first phase branch of the electrical power infrastructure and a second charge has been coupled to the second phase branch of the electrical power infrastructure, determine (1866) by means of the magnetic field sensor device, a third amplitude and a third phase angle of a third magnetic field in the two or more magnetic field sensors of the magnetic field sensor device while the magnetic field sensor device is coupled to the first surface of the circuit breaker box and while the second load is coupled to the second phase branch; and determine (1867), by means of a computer processor, one or more calibration coefficients for the magnetic field sensor device at least partially using the first amplitude and the first phase angle of the first magnetic field in two or more magnetic field, second amplitude and second phase angle sensors of the second magnetic field in two or more magnetic field sensors, and third amplitude and third phase angle of the third magnetic field in two or more magnetic field sensors, on what: the magnetic field sensor device is not electrically coupled in series or physically directly coupled to one or more main electrical supply conductors in the circuit breaker box when the magnetic field sensor device is coupled to the first surface of the circuit breaker box.
[0010]
Method, according to claim 9, characterized by the fact that: after the first charge has been decoupled from the first phase branch of the electrical power infrastructure and the second charge has been decoupled from the second phase branch of the electrical power infrastructure, determine, by means of the magnetic field sensor device, a fourth amplitude and a fourth phase angle of a fourth magnetic field in two or more magnetic field sensors of the magnetic field sensor device while the magnetic field sensor device is coupled to the first surface of the circuit breaker box; determines whether the fourth amplitude and fourth phase angle of the fourth magnetic field in two or more magnetic field sensors is within a predetermined amount of the first amplitude and the first phase angle of the first magnetic field in two or more magnetic field sensors .
[0011]
System to monitor the use of electrical power in a building's electrical power infrastructure, in which the building comprises a circuit breaker box and one or more main electrical supply conductors of the building's electrical power infrastructure, the system being characterized by the fact that which comprises: a power consumption measuring device (110) configured to be coupled to a first surface of the circuit breaker box, the circuit breaker box overlapping at least part of one or more main electrical supply conductors of the electrical power infrastructure, being that the power consumption measuring device comprises one or more magnetic field sensors; a first calibration device (180) configured to be electrically coupled to the electrical power infrastructure, the first calibration device comprising one or more first calibration loads; and a calibration module (229) configured to run on a first processor and configured to at least partially calibrate the power consumption measuring device using data obtained from one or more magnetic field sensors of the measuring device power consumption, where: the power consumption meter is configured to obtain at least part of the data while at least one or more of the first calibration loads is electrically coupled to the electrical power infrastructure and while the power consumption meter is coupled to the first breaker box surface; and one or more magnetic field sensors of the power consumption meter are not electrically coupled in series with or physically coupled directly to one or more main electrical supply conductors in the circuit breaker box when one or more sensors in the power meter power are coupled to the surface of the circuit breaker box.
[0012]
System, according to claim 11, characterized by the fact that: the first calibration device also comprises: an electrical connector configured to connect electrically to the electrical power infrastructure; a display unit configured to display information to a user; a switching module configured to electrically couple or decouple one or more first calibration loads to the electrical power infrastructure; and a second processor configured to control the switch module.
[0013]
System, according to claim 12, characterized by the fact that: the power consumption measuring device is configured to control the switching module of the first calibration device.
[0014]
System according to any one of claims 11, 12 or 13, characterized by the fact that it further comprises: a second calibration device configured to be electrically coupled to the electrical power infrastructure, the second calibration module comprising one or more second calibration loads.
[0015]
System, according to claim 14, characterized by the fact that: the first calibration device comprises a signal injector for injecting a signal into the electrical power infrastructure; and the second calibration device comprises a receiver configured to detect the signal in the electrical power infrastructure.
[0016]
System according to claim 14 or 15, characterized by the fact that: the electrical power infrastructure also comprises a first phase branch and a second phase branch; the first phase branch and the second phase branch are electrically coupled to and receive electrical power from one or more main electrical supply conductors; and the second calibration device is configured to determine whether the first calibration device and the second calibration device are both coupled to the first phase branch or the second phase branch or whether the first calibration device and the second calibration device are coupled the first phase branch and the second phase branch different.
[0017]
System, according to any of the claims 11, 12, 13, 14, 15 or 16, characterized by the fact that it further comprises: a processing module configured to run on the first processor and configured to determine at least partially a current used by the electrical power infrastructure using data obtained from one or more magnetic field sensors of the power consumption measuring device.
[0018]
System, according to any of the claims 11, 12, 13, 14, 15, 16 or 17, characterized by the fact that: the circuit breaker box comprises a door configured to move between an open position and a closed position; the first surface is an internal surface of the circuit breaker box when the door is in the closed position; the first surface is an outer surface of the circuit breaker box when the door is in the open position; and the power consumption meter is configured to be coupled to the first surface of the circuit breaker box so that the door can be placed in the open and closed position at different times while the power consumption meter remains attached to the first surface.
[0019]
Magnetic field capture device comprising: at least two magnetic field sensors (641, 642) configured to detect a magnetic field produced by an alternating current power signal in a current-carrying conductor, each of at least two magnetic field sensors being configured to emit a signal different detected from the magnetic field produced by the alternating current power signal in the current-carrying conductor due to the different position of each of the at least two magnetic field sensors relative to the current-carrying conductor; and the magnetic field capture device characterized by the fact that it also comprises: a phase detector (651) electrically coupled to the outputs of at least two magnetic field sensors; and a phase indicator (619) electrically coupled to the phase detector, where: the phase indicator comprises a display that indicates, based on the phase angles of the different signals emitted by at least two magnetic field sensors and detected from the magnetic field produced by the alternating current power signal in the current-carrying conductor, when the at least two magnetic field sensors are in a predefined position in relation to the current-carrying conductor.
[0020]
Magnetic field capture device, according to claim 19, characterized by the fact that: the at least two magnetic field sensors comprise a linear array of magnetic field sensors.

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法律状态:
2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

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2019-07-09| B06T| Formal requirements before examination [chapter 6.20 patent gazette]|

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2020-03-03| B06A| Patent application procedure suspended [chapter 6.1 patent gazette]|

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2020-07-07| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|

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2020-09-24| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 01/07/2011, OBSERVADAS AS CONDICOES LEGAIS. |

优先权:

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申请号 | 申请日 | 专利标题

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US36129610P| true| 2010-07-02|2010-07-02|

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US61/361,296|2010-07-02|

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US38017410P| true| 2010-09-03|2010-09-03|

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US61/380,174|2010-09-03|

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