Systems and methods for measuring electrical power usage in a structure and systems and methods of calibrating the same.

(54) Title: SYSTEMS AND METHODS TO MEASURE THE USE OF ELECTRICAL ENERGY IN A STRUCTURE AND SYSTEMS AND METHODS TO CALIBRATE IT.

(54) Title: SYSTEMS AND METHODS FOR MEASURING ELECTRICAL POWER USAGE IN A STRUCTURE AND SYSTEMS AND METHODS OF CALIBRATING THE SAME.

(57) Summary

Some embodiments may refer to a method of using an energy consumption measuring device. The energy consumption measurement device may be mechanically coupled to a surface of a circuit breaker box that is superimposed on at least part of one or more main conductors of the electrical power supply for an electrical power infrastructure of a structure. The method may comprise: determining one or more first magnetic field readings from one or more main power supply conductors using one or more detectors in the power consumption measurement device; after determination of the one or more first magnetic field readings, the electrical coupling of a first calibration charge to the electrical power infrastructure; while the first calibration charge remains electrically coupled to the electrical power infrastructure, determining one or more second magnetic field readings from the one or more main power supply conductors, using the one or more detectors in the device energy consumption measurement; calibration of the energy consumption measurement device using, at least in parle, the first or first magnetic field readings and the one or more second magnetic field readings; after calibrating the power consumption measuring device, determining one or more third magnetic field readings from one or more main power supply conductors using the one or more detectors in the power consumption measurement device and determining an electrical power used by the power infrastructure electrical structure using at least one or more third magnetic field readings and one or more calibration coefficients. Calibration of the energy consumption measurement device may include determining one or more first calibration coefficients for the energy consumption measurement device using, at least in part, the one or more first magnetic field readings and the one or more second readings of the magnetic field. Other embodiments of the invention are disclosed.

(57) Abstract

Some implementations can concern a method of using a power consumption measurement device. The power consumption measurement device can be mechanically coupled to a surface of a Circuit breaker box overlying at least part of one or more main electrical supply conductors for an electrical power infrastructure of a structure. The method can inelude: determining one or more first magnetic field readings from the one or more main electrical supply conductors using one or more sensors in the power consumption measurement device; after determining 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 using the one or more sensors in the power consumption measurement device; calibrating the power consumption measurement device using at least in part the one or more first magnetic field readings and the one or more second magnetic field readings, after calibrating the power consumption measurement device, determining one or more third magnetic field readings from the one or more main electrical supply conductors using the 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 the one or more third magnetic field readings and the one or more calibration coefficients. Calibrating the power consumption measurement device can inelude determining one or more first calibration coefficients for the power consumption measurement device using at least in part the one or more first magnetic field readings and the one or more second magnetic field readings. Other realizations are disclosed.

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PATENT TITLE NO. 338368

Owner (s): BELKIN INTERNATIONAL, INC.

Address: 12045 East Waterfront Drlve, Playa Vista, California, 90094, USA

Name: SYSTEMS AND METHODS TO MEASURE THE USE OF ELECTRICAL ENERGY IN A STRUCTURE AND SYSTEMS AND METHODS TO CALIBRATE IT

Classification: lnt.CI.8: G01R22 / 06

Inventor (s): SHWETAK N. PATEL; SIDHANT GUPTA; MATTHEW S. REYNOLDS; KARTHIK

YOGEESWARAN

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No. «nK #» «« 2015/004302 á of filing i July 1, 2011 Divisional Patent Number: 331484

PRIORITY

Country:

US

US

Date:

kP July 2010 'September 2010

Number:

61/361,296

61/380,174

Validity: Twenty high

Date of expiration'l of j

The reference patent is conferred with a skirt Deformity with article 23 of the jjfcy of the Propl counted with the article from the date of the presenfeción of the solid fen subscribes the present Indus trial piety (Diario j §1 / 2004, 16 / 06/2005, 25

a), 4th and 12th fraction wr lulo ha (Acial of 1/2006, Ofi I and III d &lt;j (/ 2004 and 'ipledad Ir

12031 ^ this patent has a validity of twenty years; mprc 'will be subject to the payment of the fee to maintain i'

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fraction V, 6th fraction III, and 58 of the Industrial Property Law.

with foundation

Federation (DOF)) 5 / 2009,06 / 01/2010, 18/01 Regulation of the Mexical Institute

6 · fraction »ttt and 7 ° bis 2 of laj

1/1996, 12/26/1997, IJ 1) 4/2012); Articles 1, 3 | ndustrial (DOF 12/14/1999,

fire, before the hey of the 105/1999, icclón V side el irgánico

I7); 1, 3 and 5 Clause a) of the Agreement that delegates powers to the Deputy Directors General, Coordinator, Divisional Directors, Holders of the Regional Offices, Divisional Deputy Directors, Departmental Coordinators and other subordinates of the Mexican Institute of Industrial Property. (DOF 12/15/1999, amended on 02/04/2000, 07/29/2004, 08/04/2004 and 09/13/2007).

Issue Date: April 13, 2016

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- 1 SYSTEMS AND METHODS TO MEASURE THE USE OF ELECTRICAL ENERGY IN A STRUCTURE AND SYSTEMS AND METHODS TO CALIBRATE IT CROSS TO RELATED PATENT APPLICATIONS Patent application claims the

MEXICAN INSTITUTE of provisional patent of States

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Reference

This application

61 / 361,295, filed July 2, 2010, and United States Provisional Patent Application No. 61 / 380,174, filed September 3, 2010. This patent application is also a continuation in part of the United States patent application. States number 12 / 567,561, filed on September 25, 2009. United States Provisional Patent Applications Nos. 61 / 361,296 and 61 / 380,174 and United States Patent Application No. 12 / 567,561, are incorporated herein by reference.

Field of the Invention

This invention relates, in general, to apparatus, devices, systems, and methods for supervising the supply of electrical energy, and relates more particularly to apparatus, devices, systems, and methods that monitor the supply of electrical energy in one or more main conductors of electrical energy supply in a panel of electrical circuit breakers of a structure.

Background description

A structure (eg, a dwelling or a commercial building) may have one or more main power supply conductors that provide 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 supply conductors. The main electrical power supply conductors penetrate the structure through a panel of electrical circuit breakers. An electrical circuit breaker panel is the electrical distribution point

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main for electricity in a structure. The electrical circuit breaker panels also provide protection against overcurrent currents, which could cause fires or damage to electrical devices in the structure. Electric circuit breaker panels can be coupled to, and overlapped on, at least part of the three main electrical power supply conductors.

Different manufacturers of electrical circuit breaker panels including, by way of example, Square-D, Eaton, Cutler-Hammer, General Electric, Siemens and Murray, have chosen different conductor spacings and configurations for their electrical circuit breaker panels. In addition, each manufacturer provides numerous different configurations of electrical circuit breaker panels for indoor installations, outdoor installations and for different total amperes, of which 100 amp (A) and 200 A service are the most prevalent.

The different conductor arrangements in the many different types of electrical circuit breaker panels give rise to different magnetic field profiles on the metal surfaces of the electrical circuit breaker panels. In addition, the arrangement of the internal conductors (eg, the main conductors for electrical power supply) is not visible unopened on the circuit breaker panel and the manner in which the arrangement of internal conductors is converted into a magnetic field profile , on the surface of the electrical circuit breaker panel, requires a detailed understanding of electromagnetic theory to interpret and create models correctly. Therefore, it is difficult to accurately measure the magnetic field of the one or more main power supply conductors on a surface of the electrical circuit breaker panel. If the magnetic field of the one or more main power supply conductors could be accurately determined on a surface of the electrical circuit breaker panel, it could

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Determine the current and electrical power used by the load on the structure.

Accordingly, a need or potential for benefit exists for an apparatus, system, and / or method that enables a non-electrician to accurately determine the magnetic field and other parameters related to the one or more main electrical power supply conductors. on a surface of the electrical circuit breaker panel.

Brief description of the drawings

To further facilitate the description of the embodiments, the following drawings are provided wherein:

Figure 1 illustrates a view of an electrical energy monitoring system, by way of example, coupled to a panel of electrical circuit breakers, according to a first embodiment;

Figure 2 illustrates a block diagram of the electrical energy monitoring system of Figure 1, according to the first embodiment;

Figure 3 illustrates a sectional view of the circuit breaker panel shown in Figure 1 along the conductor 33, according to the first embodiment;

Figure 4 illustrates an example of conductors of the magnetic field generated by a conductor;

Figure 5 illustrates, by way of example, the magnetic field conductors generated by the main electric power supply conductors in the circuit breaker represented in Figure 1, according to the first embodiment;

Figure 6 illustrates, by way of example, the detector device represented in Figure 2, according to the first embodiment;

Figure 7 illustrates, by way of example, the placement of the detector device represented in Figure 2, on a main electrical power supply conductor of the circuit breaker of Figure 1, according to the first embodiment;

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a device the device

Figure 8 illustrates, by way of example, LUld ”^ ¿graphical presentation of a voltage of electric current detectors with respect to time, according to an embodiment;

Figure 9 illustrates, by way of example, a detector, according to a second embodiment;

Figure 10 illustrates, by way of example, the detector of Figure 9 on the main conductors of the electrical power supply of the circuit breaker of Figure 1, according to the second embodiment;

Figure 11 illustrates, by way of example, the calibration device of Figure 1, according to the first embodiment;

Figure 12 illustrates, by way of example, the graphical representation of the incoming low voltage signal potential to a controller of Figure 11 from a level converter of the

Figure 11, according to an embodiment;

Figure 13 illustrates, by way of example, graphical representations illustrating the relationship of a square wave low voltage signal used to develop a phase reference and the low voltage signal of Figure 12, according to one embodiment;

Figure 14 illustrates, by way of example, a switched load, according to a third embodiment;

Figure 15 illustrates, by way of example, a switched load, according to a fourth embodiment;

Figure 16 illustrates, by way of example, a switched load, according to a fifth embodiment;

Figure 17 illustrates, by way of example, a switched load, according to a sixth embodiment;

Figure 18 illustrates a flow diagram for a method of calibrating an electrical power monitoring system, in accordance with one embodiment;

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Figure 19 illustrates a flow chart for a calibration coefficient determination activity, according to one embodiment;

Figure 20 illustrates a flow diagram for a method of determining the expected current in the main conductors of the electrical power supply, according to one embodiment;

Figure 21 illustrates, by way of example, a first location of two electric current detectors relative to the main conductors for supplying electrical energy in an detector device, by way of example, according to an embodiment;

Figure 22 illustrates a graphical representation comparing a predicted current versus measured currents for the electrical current detectors depicted in Figure 21;

Figure 23 illustrates, by way of example, a second location of two electric current detectors in relation to the main conductors for supplying electrical energy in an detector device, by way of example, according to an embodiment and

Figure 24 illustrates a graphical representation comparing a predicted current with the measured currents for the electrical current detectors depicted in Figure 23.

For simplicity and clarity of illustration, the Figures of the drawings illustrating the general manner of construction and descriptions and details of well known features and techniques can be omitted to avoid an unnecessarily confusing description of the invention. Furthermore, the elements in the Figures of the drawings are not necessarily drawn to scale. As an example, the dimensions of some of the elements in the Figures can be exaggerated in relation to the

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other elements to help improve knowledge of the embodiments of the present invention. The same numerical references in different Figures indicate the same elements.

The terms first, second, third, fourth and the like in the description and in the claims, if any, are used to distinguish between similar elements and not necessarily to describe a particular chronological or sequential order. It is to be understood that the terms so used are interchangeable under suitable circumstances, such as the embodiments described herein, are, by way of example, capable of operation in sequences other than those illustrated or in any way described herein. Furthermore, the terms include and have and any of its variants are intended to cover a non-exclusive inclusion, such as a process, method, system, article, device or apparatus that comprises a list of elements, it is not necessarily limited to said elements, rather, it may include other elements not expressly mentioned or inherent in said process, method, system, article, device or apparatus.

The terms left, right, front, back, top, bottom, top, bottom and the like in the description and in the claims, if any, 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 suitable circumstances, such as the embodiments of the invention described herein, being, by way of example, capable of operation in other orientations than those illustrated or in any other way, here described.

The terms couple, couple, couple, couple and the like are to be understood and refer, in a broad sense, to the connection of two or more elements or signals, by electrical, mechanical and / or any other means. Two or more

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Electrical elements can be electrically coupled but not mechanically coupled in any other way; two or more mechanical elements may be mechanically coupled, but not electrically or otherwise coupled; two or more electrical elements may be mechanically coupled, but not electrically or otherwise coupled. The coupling can be for any period of time, eg, permanent or semi-permanent or only for an instant.

The term electrical coupling and the like is to be understood broadly and to include coupling involving any electrical signal, be it an electrical power supply signal, a data signal and / or other types or combinations of electrical signals. The term mechanical coupling and the like are to be understood broadly and include mechanical coupling of all types.

The absence of the term removable, removable and the like near the word coupled and the like does not mean that the coupling, etc., in question is or is not removable. Detailed description of embodiments of the invention

Some embodiments may refer to a method of using an energy consumption measuring device. The power consumption measurement device may be mechanically coupled to a surface of a circuit breaker box that is superimposed on at least part of one or more main power supply conductors for a structure power power infrastructure. The method may include: determining one or more first magnetic field readings from the one or more main power supply conductors using one or more detectors in the power consumption measurement device; after determining the one or more first magnetic field readings, the electrical coupling of a first calibration charge to the electrical power infrastructure; while the first load of

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Calibration remains electrically coupled to the electrical power infrastructure, determining one or more second magnetic field readings from the one or more main power supply conductors using the one or more circuit breakers in the power consumption measurement device; calibrating the energy consumption measurement device using at least in part the first or more magnetic field readings and the one or more second magnetic field readings, after calibrating the energy consumption measurement device, ia determination of one or more third magnetic field readings from the one or more main conductors of the electrical energy supply using the one or more detectors in the energy consumption measurement device and the determination of an electrical power used by the electrical energy infrastructure of the structure using at least one or more third magnetic field readings and one or more calibration coefficients. Calibration of the energy consumption measurement device may include determining one or more first calibration coefficients for the energy consumption measurement device using at least in part the one or more first magnetic field readings and the one or more second readings of the magnetic field.

Other embodiments may refer to a method of calibrating a magnetic field detecting device. The magnetic field detecting device is coupled to a first surface of a circuit breaker box. The circuit breaker box is superimposed on a building's electrical power infrastructure. The electrical energy infrastructure has a first phase shunt and a second phase shunt. The magnetic field detector device can include two or more magnetic field detectors. The method may include: determining a first amplitude and a first phase angle of a first magnetic field in the two or more field sensors

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Magnetic magnetic field detector device; receiving communication that a first load is coupled to the first phase shunt of the electrical power infrastructure; while the first charge is coupled to the first phase shunt, the determination of a second amplitude of a second phase angle of a second magnetic field in the two or more magnetic field sensors of the magnetic field detecting device; receiving communications that a second load is coupled to the second phase shunt of the electric power infrastructure; while the second load is coupled to the first phase shunt, 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 detecting device and determining one or more calibration coefficients for the magnetic field detecting device at least in part using the first amplitude and the first phase angle of the first magnetic field in 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 the third amplitude and the third phase angle of the third magnetic field in the two or more magnetic field sensors.

Other embodiments may refer to a system for monitoring the use of electrical energy in a building's electrical energy infrastructure. The building includes a breaker box and electrical power supply conductors for the building's electrical power infrastructure. The system may include: (a) a power consumption measurement device configured to couple to a first surface of the circuit breaker box, the circuit breaker box being superimposed on at least part of the electrical power supply conductors for the electrical energy infrastructure, presenting the device for measuring the consumption of

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power one or more magnetic field sensors; (b) a first calibration device configured to electrically couple to the electrical power infrastructure, the first calibration module comprising one or more first calibration charges and (c) a calibration module configured to operate on a first processor and configured to calibrate, at least in part, the energy consumption measurement device using the data obtained from the one or more magnetic field sensors of the energy consumption measurement device. The energy consumption measurement device can be configured to obtain at least part of the data while at least one or more first calibration charges are electrically coupled to the power infrastructure and while the energy consumption measurement device is coupled to the first surface of the circuit breaker box.

In other embodiments, a magnetic field detector device may include: (a) at least two magnetic field sensors configured to detect a magnetic field in a current circulating detector; (b) a phase detector electrically coupled to the outputs from the at least two magnetic field sensors and (c) a phase indicator electrically coupled to the phase detector. The phase indicator may include a monitor that indicates when the at least two magnetic field sensors are in a predetermined position relative to the current flowing conductor.

FIG. 1 illustrates a view of an exemplary electrical power supply monitoring system 100 coupled to a circuit breaker panel 190, in accordance with a first embodiment. Figure 2 illustrates a block diagram of an electrical power supply monitoring system 100, according to the first embodiment. Figure 3 illustrates a sectional view of a panel of circuit breakers 190 along conductor 3-3, according to the first embodiment.

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The electrical power supply monitoring system 100 can also be considered a system for monitoring the electrical power utilization of a structure (ie, a building). The electrical power supply monitoring system 100 may also be considered a device and system for determining the predicted current used by one or more electrical devices (ie, the load) in a structure. The electrical power supply monitoring system 100 is by way of example only and is not limited to the embodiment presented herein. The system of electrical power supply monitoring forms 100 can be used in numerous or exemplary ways, not the panel breakers of different embodiments, specifically illustrated or described herein.

In some exemplary embodiments, electrical power supply monitoring system 100 may include: (a) at least one detector device 110 (ie, a power consumption measurement device); (b) at least one computer computing unit 120 and (c) at least one calibration device 180.

In some exemplary embodiments, system 100 can be used on panels from different manufacturers and on different types of circuit breakers from the same manufacturer. In addition, in some exemplary embodiments, system 100 can be easily installed by a non-specially trained person (i.e., a non-electrician) without opening the circuit breaker panel box and exposing the conductors of Non-isolated electrical energy, located inside.

Furthermore, as illustrated in Figure 1, a conventional circuit breaker box or circuit breaker panel 190 may include: (a) two or more individual circuit breakers 191; (b) two or more main circuit breakers 192; (c) a panel 196 with an exterior surface and (d) a door 197 that provides access to the

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INDUSTRIAL breakers 191 and 192. At least a portion of the main power supply drivers 193, 194, and 195 may be located within breaker panel 190. The term Breaker Panel may also refer to and include fuse boxes, which are still prevalent in buildings with older electrical systems. The electrical power infrastructure of a structure may include at least one panel of circuit breakers 190 and main power supply conductors 193, 194, and 195. In some embodiments, by way of example, circuit breaker panels may also refer to to any type of electrical power distribution panel used to supply electricity to a structure.

The main electrical power supply circuit breakers 193, 194 and 195 are electrically coupled to the main circuit breakers 192 and supply the electrical power to electrical devices (ie the load) in the structure. Panel 196 is superimposed on at least part of the main electrical power supply conductors 193, 194, and 195 and associated circuits to protect people from inadvertent contact of these circuit breakers with circulating electrical energy. Under normal conditions, panel 196 is made of steel or other metal.

Door 197 covers breakers 191 and 192 and is typically closed for aesthetic reasons, but can be opened to allow access to breaker levers 191 and 192 within breaker panel 190. As illustrated in Figure 3, when opens door 197, panel zone 398 may have panel zone depth 399. The depth of panel zone 399 is typically 13 millimeters (mm) to 20 mm to allow door 197 to close without hitting the levers of breakers 189. The depth of panel zone 399 limits the allowable thickness of the detector device 110 which is mounted in panel area 398. That is, in various embodiments, by way of example, the

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detector device 110 can be installed inside¹ IS Ji'fófüñáiaád of panel area 399 so that the door of the circuit breaker panel can be kept closed while the detector device 110 is in operation. In numerous embodiments, by way of example, the detector device 110 has a depth of less than 20 mm. In the same or different embodiments, by way of example, the detector device 110 may have a depth of less than 13 mm.

Electrical service for residential and small commercial areas is typically a 240-volt split phase service. The latter refers to the public service that provides two 120V alternating current (AC) supply detectors (eg, electrical power supply conductors 193 and 194) that have 180 degrees of lag, along with a neutral conductor (eg, electrical power supply conductor 195) which can be used for current return from one or the other electrical power supply conductor 193 and 194. Electrical power supply conductors 193, 194, and 195 are the primary power supply conductor (s) that transmit incoming power from the utility before it is divided into branch circuits that serve the various loads. By detecting the magnetic fields generated by the electrical power supply conductors 193, 194 and 195, the system 100 can detect the total current drawn by all charges from the utility, since all charges in the structure are coupled in parallel to the electric power supply conductors 193, 194 and / or 195.

In the United States, many different types of electrical loads are found in a building that has a 240V divided phase utility. Electric loads can be divided into two categories of loads: (a) 120V loads and ( b) 240 V loads.

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120V loads may primarily include lower wattage loads, i.e. loads inserted into standard 120V, 15A or 120V, 20A 3-prong outlets and small utensils with less than ~ 2kW ( kilowatts) of power consumed. These loads are wired into individual circuits between pairs of electrical power supply conductors 193 and 195 (the first phase branch or branch 193-195 of the wired circuit) or a pair of electrical power supply conductors 194 and 195 (the second phase branch of branch 194-195 of the wiring circuit). When wiring a structure, electrical technicians attempt to balance the expected wattage of the loads and outlets on each branch, but this is not an exact process so the current in branch 193-195 and in lead 194-195 they are probably unbalanced because a different total wattage is usually drawn from each pair. When a 120 V load is energized, its current flows from the utility, through electrical power supply line 193 or 194 through main and level circuit breakers to the load, and then back to the 195 electric power supply and back to the public service.

240V loads are typically large utensils (eg, electric dryer, stove, air conditioning compressor, electric base plate heaters) that consume more than two kW (kilowatts). In this case, the charging current flows between the electrical power supply conductors 193 and 194 and no charging current flows through the electrical power supply conductor 195. Due to the 180 degree phase relationship between the voltages on the power supply conductors 193 and 194, the total voltage is 240 V.

Referring again to Figures 1 and 2, the computer computing unit 120 may include: (a) a communication module 221; (b) a processing module 222; (cradle

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power supply source 223 with an electrical connector 128; (d) a user communication device 134; (e) a controller 225, (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 detector 228.

Computer computing unit 120 can be configured to receive the output signal from calibration device 180 and / or detector device 110 through communications module 221 and to process the output signal to determine one or more usage related parameters of the electrical energy of the structure (eg, the electrical energy used by the structure and the electric current in the main conductors of electrical energy supply 193, 194 and 195). In some embodiments, the computing unit 120 may be a personal computer (PC).

Controller 225 can be a microcontroller such as the MSP430 microcontroller, manufactured by Texas Instruments, Inc. In other embodiments, controller 225 is a digital signal processor such as the TMS320VC5505 digital signal processor manufactured by Texas Instruments Inc. or a Blackfin digital signal processor manufactured by Analog Devices Inc.

Processing module 222 can be configured to use current measurements from detector device 110 to determine one or more parameters related to the utilization of electrical energy to the structure (eg, electrical current and electrical power from main supply conductors. electric power 193, 194 and 195). As will be explained later, the calibration calculation module 229 can be configured to use current measurements from detector device 110 to calibrate electrical power supply surface system 100 (eg,

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calculate the calibration coefficients for the detector device 110).

In some embodiments, by way of example, the processing module 222 and the calibration calculation module 229 can be stored in memory 226 and configured for execution in controller 225. When the computer calculation unit 120 is operating, the Program instructions (eg, processing module 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 performing methods 1800 and 2000 (Figures 18 and 20, respectively) as described below.

Calibration charge module 227 can include one or more calibration charges. As will be explained later, the one or more calibration charges may be temporarily electrically coupled to, by way of example, the first phase shunt of the structure's electrical power infrastructure to aid in the calibration of the supply monitoring system. electric power 100.

In some exemplary embodiments, user communication device 134 and control mechanism 132 may be detachable from the rest of computing unit 120 and communicate wirelessly with the rest of the computing unit. computer calculation 120.

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 current flowing through it is equal to the phase angle measured by the electric current detectors 211 minus the phase angle of the voltage measured using the electric voltage detector 228. That is, the phase angle of the current can be calculated by referring to the zero point crossing of the voltage.

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In some embodiments, by way of example, the detector device 110 can communicate the current measurement made by the electric current detectors 211 to the computing unit 120, so that the phase angle of the current can be calculated . In other embodiments, by way of example, computer computing device 120 may communicate the voltage measurement by electrical voltage detector 228 to sensing device 110 so that the phase angle of the current can be calculated. In other embodiments, by way of example, the electrical voltage detector 228 may be located on the calibration device 180.

Electrical power supply source 223 may supply electrical power to communication module 221, to a processing module 222, to a user communication device 134, to a controller 225, to memory 226, to a charging module. calibration 227 and / or a control mechanism 132. In some embodiments, by way of example, electrical power supply source 223 may be coupled to electrical connector 128 which may, in turn, be coupled to a wall outlet in the electrical power infrastructure.

User communication device 134 can be configured to display information to a user. In an exemplary embodiment, user communication device 134 may be a monitor, a touch screen, and / or one or more LEDs (light emitting diodes).

Control mechanism 132 may include one or more buttons configured to at least partly control computer computing unit 120 or at least one user communication device 134. In one exemplary embodiment, the mechanism Control switch 132 may include an on / off switch (i.e., a so-called on / off switch) and / or a

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visual display configured to control what is displayed on the user communication device 134.

Still referring to Figures 1 and 2, the detector device 110 may include: (a) two or more magnetic field sensors or electric current sensors 211; (b) a controller 213; (c) a user communication module 214; (d) a communication module 215; (e) an electrical power supply source 216 and (f) a coupling mechanism 219. Controller 213 can be used to control electrical current detectors 211, user communication module 214, communication module 215, and electrical power supply source 216.

Electric current detectors 211 may include an inductive pickup device, a Hall effect sensor, a magneto-resistive sensor, or any other type of sensor configured to respond to the time-varying magnetic field produced by conductors inside the panel. breakers 190.

In various embodiments, by way of example, detector device 110 may be configured to engage the surface of panel 196 using a coupling mechanism 219. In some embodiments, by way of example, coupling mechanism 219 may include an adhesive, a Velero® material, a magnet or other bonding mechanism.

Communication module 215 may be electrically coupled to electrical current detectors 211 and controller 213. In some embodiments, by way of example, communication module 215 communicates the voltages or other measured parameters using electrical current detectors 211 to the communication module 221 of the computing unit 120. In numerous embodiments, by way of example, communication module 215 and communication module 221 can be wireless transceivers. In some other embodiments, by way of example, electrical signals may be transmitted

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using Wi-Fi (wireless fidelity), the IEEE (Institute of Electrical and Electronics Engineers) 802.11 íbá'láftlBPlCd 'protocol or the Bluetooth 3.0 + HS (High Speed) wireless protocol. In other embodiments, by way of example, these signals can be transmitted through a Zigbee (IEEE 802.15.4 wireless protocol), Wave-Wave, or a proprietary wireless technology standard. In other embodiments, by way of example, communication module 215 and communication module 221 can communicate electrical signals using a wired or cellular connection.

User communication module 214 can be configured to display information to a user. In an exemplary embodiment, the user communication module 214 may be an LCD (liquid crystal display) and / or one or more LED diodes (light emitting diodes).

Controller 213 can be configured to control electrical current detectors 211, communication module 215, user communication module 214 and / or electrical power supply source 216.

Calibration device 180 may include: (a) a communication module 281; (b) an electrical connector 282; (c) a calibration charge module 283; (d) a user communication device 184; (e) a controller 285 and (f) an electrical power supply source 289. In some embodiments, by way of example, the communication module 281 may be similar or the same as the communication module 215 and / or 221. Electrical connector 282 may be an electrical power connector in some embodiments, by way of example. User communication device 184 can be configured to display information to a user. In an exemplary embodiment, user communication device 184 may be one or more LEDs.

<img file="MX338368B_D0030.tif" />

According to Ampere's Law, magnetic fields are generated by conductors through which current flows, as represented in Figure 4. That is, the magnetic field generated by a given conductor is a three-dimensional vector field, which can be decomposed into components in each of the X, Y and Z axes. In an alternating current system, these magnetic fields are variable in time in magnitude, but they maintain the same vector angle with respect to the coordinate base. Thus, when referring to the X axis, as an example, the field can be, at any instant, pointing in the + X axis direction or in the -X direction when AC alternating current reverses its direction at frequency For example, 50 Hz. A magnetic field component, in the X direction, can be referred to as + X or -X, depending on the direction of current flow at a particular instant.

The magnetic field lines obey the so-called Right Hand Rule or Ampere's Law; If the thumb of a person's right hand is aligned with the direction of current flow in the conductor, the field lines wrap the conductor perpendicular to that conductor and in the direction of the person's fingers.

Some embodiments are primarily concerned with the magnetic field component that is oriented perpendicular to the plane of the circuit breaker panel (along the Z axis) because these are the field components that can be easily detected by a magnetic field detector (this that is, a detector device 110) outside the metal cover of circuit breaker panel 190.

As illustrated in Figure 5, since the power supply conductors 193 and 194 have a phase difference of 180 degrees, at any point in time, the direction of the loop of the magnetic field lines is in opposite directions .

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INDUSTRIAL

<img file="MX338368B_D0031.tif" />

Thus, according to Krichhoff's Current Law, the total current through a given supply conductor (i.e., electrical power supply conductors 193, 194, and / or 195) is the sum of all charge currents drawn from that driver. The magnitude of the magnetic field generated by each of the conductors (i.e., the electrical power supply conductor 193, 194, or 195) is therefore directly proportional to the sum of the currents drawn in all branch circuits. connected to that conductor. The direction of the magnetic field lines, from a given conductor, do not change like the currents in the leads.

System 100 can be configured to detect magnetic fields generated by at least electrical power supply conductors 193 and 194 to address all three possible load cases: (a) 120V load between shunt 193-195; (b) 120 V load between branch 194-195 and (c) 240 V load between branch 193-194. In most practical cases, it is not necessary to detect the magnetic field generated by the electrical power supply conductor 195 (that is, the neutral conductor) because any current drawn through the electrical power supply conductor 195 is supplied by the electrical power supply conductor 193 or 194.

Figure 6 illustrates, by way of example, an electrical current detector 211, according to the first embodiment. In these exemplary embodiments, the electric current detector may include: (a) one or more detectors 641 and 642; (b) one or more amplifiers 647 and 648; (c) one or more filters 649 and 650; (d) one or more 651 phase detectors; (e) at least one differential amplifier 652 and (f) at least one digitizer 653.

In some exemplary embodiments, system 100 may be configured to assist the user in proper placement of detector device 110 by indicating convenient placement with the user communication module.

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<img file="MX338368B_D0032.tif" />

214. In some exemplary embodiments, system 100 may determine proper placement by detecting a phase difference of approximately 180 degrees between detectors 641 and 642 that are arranged on opposite sides of a conductor (i.e., the conductor of electric power supply

193

194)

In the same or different examples, the user communication module 214 can be placed with the detector device 110 or the user communication module 214 can be used and can be remote and linked to the detector device 100 through a wireless network.

Detector 641 can include: (a) a ferromagnetic core 643 and (b) a detector coil 644 wound around a ferromagnetic core 643. Detector 642 can include: (a) a ferromagnetic core 645 and (b) a detector coil 646 wound around ferromagnetic core 645. In various embodiments, by way of example, detectors 641 and 642 may be 2.5 millimeters (ram) to 12.7 runde diameter. In other embodiments, by way of example, the electric current detector 211 only includes detector 641 and does not include detector 642, amplifier 647, filter 649, phase detector 651 and / or differential amplifier 652. In this alternate embodiment, filter 649 or 650 is coupled to a digitizer 653. In other embodiments, electric current detector 211 includes four, six, eight, or ten detectors.

The purpose of the ferromagnetic cores 643 and 645 is to concentrate the magnetic field from the detector coils 644 and 646 to provide a higher output voltage from the sensors at the output terminals of the detector coils 644 and 646. The voltage at the output of Detector coils 644 and 646 are provided by Faraday's Law. That is, the voltage depends on the applied AC alternating magnetic field, the physical dimensions of the coil and the connecting wires, the number of wire turns in the coil and the magnetic permeability.

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INDUSTRIAL

<img file="MX338368B_D0033.tif" />

of the nucleus. In other embodiments, by way of example, detectors 641 and 642 do not include ferromagnetic nuclei 643 and

645, respectively.

As illustrated in Figure 7, when electrical current detector 211 is coupled to circuit breaker panel 190, one of detectors 641 and 642 may be located on either side of a conductor (i.e., the electrical power supply conductor 193 or 194). In this embodiment, the voltage induced in detector 641 is 180 degrees out of phase with detector 642 because the magnetic field penetrates detector 642 from the underside, while the magnetic field penetrates detector 641 from the upper part.

Figure 8 graphically represents the phase relationship between the voltage at detectors 641 and 642. Referring to Figure 8, when AC alternating current circulates in the conductor (that is, electrical power supply conductor 193 or 194) induces a voltage V (sensor) on the detector coils 644 and

646. This voltage, V (sensor) is proportional to the current I (sensor) flowing through the conductor (that is, the power supply conductor 193 or 194), that is, V (sensor) = k * I (sensor ). The constant of proportionality k can be determined by drawing a known current through the conductor by temporarily connecting a calibration load (that is, calibration load module 283 or 227 (Figure 2)) to a circuit served by the conductor (that is, the electrical power supply conductor 193 or 194) and measuring the induced voltage at detectors 641 and 642 (Figure 6). In some cases, more than one known current can be drawn to establish a multipoint calibration of the proportionality constant.

Referring again to Figure 6, this configuration of two detectors (that is, detectors 641 and 642) can be used to provide a detector device 110 that communicates

<img file="MX338368B_D0034.tif" />

mexican institute ^{D £ LA} and^rofficia K¹industryX

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automatically to a user who has been placed rn-nxctamrintp with respect to a given current circulating conductor, while rejecting interference from other sources, including other nearby conductors. This capability is useful in the electrically noisy environment found on a circuit breaker panel, where there are numerous conductors near a particular conductor of interest.

More specifically, in some embodiments, the output of each of detectors 641 and 642 can be amplified using amplifiers 648 and 647, respectively, and then filtered using filters 650 and 649, respectively. The output of filters 650 and 649 can be presented to phase detector 651 coupled to a phase indicator 619 on user communication module 214 (eg, one or more LEDs). User communication module 214 is configured to

641

642 They have been indicating to the user that the detectors are correctly positioned with respect to a given conductor with current circulation. The user may be instructed to move the sensor through the area where the main power supply conductors are to be located and for movement once the phase indicator provides an indication that the phase difference between the signals of detectors 641 and 642 is approximately 180 degrees. By way of example, when the signals from detectors 641 and 642 are approximately 180 degrees out of phase, a green LED could be illuminated on top of detector device 110.

Amplifiers 648 and 647 and filters 650 and 649 are optional in some embodiments, by way of example. The purpose of amplifiers 648 and 647 and filters 650 and 649 are to increase the signal level while rejecting noise at unwanted frequencies and thereby increasing the signal-to-noise ratio of signals. of the

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<img file="MX338368B_D0036.tif" />

641 and 642 detectors 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 filters or active filters of agglomerated elements implemented with operational amplifiers. In general, Filters 650 and 649 are bandpass filters configured to transmit AC line frequency (eg, 60 Hz in the United States and Canada or 50 Hz in

Europe and Japan) at the same time that out-of-band noise is rejected.

Phase detector 651 can be an analog phase detector circuit or a digital phase detector. A digital phase detector can be implemented with combinational logic, programmable logic, or software in a controller. In one embodiment, an integrated phase detector circuit, such as the phase detector contained in the Type 4046 or 74HC4046 phase locked loop controllers, manufactured by Texas Instruments Inc., can be used in this regard. In other embodiments, phase detector 651 is implemented by digitizing detector signals with an analog-to-digital converter, and then a tangent arc function is applied to the vector of samples received from detectors 641 and 642. In another embodiment, the filtering and phase detection functions are combined using a periodgram-based maximum probability estimator, such as a complex Fast Fourier Transform (FFT) algorithm to determine the magnitude and phase angle of the signal at only the AC line frequency, while rejecting noise at other frequencies.

The phase indicator 619 can be any device that indicates to a user that the desired phase relationship between the input signals from detectors 641 and 642 has been reached. In some embodiments, the phase indicator can be

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one or more LEDs. In other embodiments, &lt;* 1 - phase indicator 619 may be a graphical or numerical display such as a liquid crystal display (LCD) or audio tone indicating to the user that the voltages of detectors 641 and 642 are almost 180 degrees lag.

Differential amplifier 652 can be used to combine the signals from detectors 641 and 642 to provide a voltage or current signal proportional to the current in the main power supply conductor, once the phase relationship has been established correct. This signal can be used as an input for calculations performed by controller 213. In the same or different embodiment, by way of example, communication module 215 can be used to transmit data to the computing unit including information: (a) the proper placement of detectors 641 and 642 as indicated by the relationship of detectors in addition to (b) the differentially detected signal from detectors 641 and 642.

Turning to another embodiment, Figure 9 illustrates, by way of example, a detector device 910, according to a second embodiment. FIG. 10 illustrates, by way of example, a detector device 910 in electrical power supply conductors 193 and 194 according to the second embodiment. In this exemplary embodiment, a linear array array of detectors 941i, 9412, ..., 941n can be used where N is a number between 2 and 10. In another embodiment, by way of example, N may be other numbers such as 4, 6, 8, 20, 50, or 100. One purpose of this linear array array of detectors is to allow controller 213 to select, automatically , one or more pairs of detectors 941χ, 9412, -, 941n, so that the user does not have to manually position the detector device 910 in the correct position. In some embodiments, the detector device 910 can be used instead

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0038.tif" />

of the detector device 110 in the system 100 represented in Figure 1.

Referring to Figures 9 and 10, in this form of

<td>realization</td><td>mode</td><td>for example,</td><td>the detector device</td><td> 910</td><td>can</td>

<td>will include)</td><td>the</td><td>detectors</td><td>941i, 941₂, ..., 941_n;</td><td>(b)</td><td>the</td>

<td>amplifiers</td><td> 647</td><td>and 648; (c)</td><td>filters 649 and 650;</td><td>(d)</td><td>the</td>

phase detectors 651; (e) differential amplifier 652; (f) digitizer 653 and (g) at least one multiplexer 955 and 956.

As illustrated in Figure 10, the linear array of detectors 941i, 9412, ..., 941n is coupled to multiplexers 955 and 956, which select at least one detector from among detectors 941i, 9412, ... , 941n for use as a magnetic field sensor to provide a signal proportional to the current in the main power supply conductors 193 and / or 194.

In another embodiment, more than one conductor of power supply conductors 193 and 194 are simultaneously detected by detector device 910. In this embodiment, controller 213 controls multiplexers 955 and 956 so that they are selected. two different detectors from among the detectors 941i, 9412, ..., 941n that are adjacent to two different electric power supply conductors 193 and 194, with current circulation. In this embodiment, controller 213 controls multiplexers to select detectors based on the amplitude or phase angle of the detector signal. In some embodiments, multiple detectors among the detectors 941i, 9412, ..., 941n are multiplexed under the control of controller 213 to select different detectors, each having preferential magnetic field coupling to one conductor different with current circulation.

Referring again to Figure 1, the system 100 may use calibration in some embodiments,

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<img file="MX338368B_D0039.tif" />

By way of example, to achieve an accurate current measurement on the power supply conductors 193 and 194. The potential for calibration may be due to poorly controlled installation geometry, for example, when the detector device 110 or 910 (Figure 9) is installed on an inefficiently trained user.

Figure 11 illustrates an exemplary embodiment of the calibration device 180, according to the first embodiment. Calibration device 180 is depicted in Figure 11 as a single-circuit calibration device that is configured to switch a single calibration load to a single incoming conductor [ie, a power supply conductor 193 and 194) for complete a circuit between the incoming conductor, the single calibration load, and the neutral or return conductor (that is, electrical power supply conductor 195). The switching signal is used to temporarily complete the circuit with the calibration load, which is used by the 1800 calibration method depicted in Figure 18.

In some exemplary embodiments, the calibration load module 283 may include: (a) a switched load 1105; (b) a 1171 transformer; (c) a 1172 filter; (d) a level converter 1173 and (e) a quadrature wave generating device 1174. The switched load 1105 may include: (a) a switch 1187 and (b) a calibration load 1188. Controller 285 may include: (a) an 1177 analog to digital converter; (b) a 1176 digital input and (c) an 1186 temperature sensor.

In the embodiment depicted in Figure 11, the calibration load module 283 may be designed to calibrate the measurement of a single conductor with current flow (a feeder to the branch circuit) that is measured by the detector device 110. In this embodiment, a

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0040.tif" />

1188 single calibration load is switched by the connintaHnr n ci between the line conductor (eg, main power supply conductors 193 and 194) and the neutral conductor (eg, main power supply conductor 195) under control of a switching signal from a 285 controller. In the United States, the switched load 1105 can be used with a 120V outlet. In other countries, the 1105 switched load can be used with 240 V and other electrical voltage outputs.

It should be noted that although the 1188 calibration load and the calibration load in Figures 14 through 17 are drawn as a resistor, the 1188 calibration load and other calibration loads depicted in Figures 14 through 17 can be any load that includes a reactive load, such as an inductor or capacitor, with or without a resistive component.

Also, the calibration load can be a load with a variable resistance. Furthermore, it should be noted that although switch 1187 and other switches, depicted in Figures 14 through 17, are drawn as mechanical relay switches, the switches may be another form of switching device. By way of example, the switches may be semiconductor switches such as solid state relays, triaos, transistors such as FETs (field effect transistors), SCRs (silicon controlled rectifiers), BJTs (bipolar junction transistors), or IGBTs (insulated gate bipolar transistors) or other controllable switching devices.

As illustrated in Figure 11, communication module 281 is coupled to controller 285 to allow the transfer of calibrated current measurements from calibration device 180 to computer computing unit 120. In some embodiments, by way of For example, the communication module 281 may include a receiver and a transmitter. Communication module 281 can include any form of communication device

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0041.tif" />

communication, wired or wireless, qpft. fnnc-íono³ ψν.ΐτ frequency and with any data link protocol. In one embodiment, communication module 281 includes a 2.4 GHz transceiver, part number CC2500, available from Texas Instruments Inc. In another embodiment, communication module 281 includes a 900 transceiver. MHz, reference number CC2010, available from Texas Instruments Inc. In some embodiments, communication module 281 can communicate using any of the following WiFi communication protocols (IEEE 802.11), Zigbee (IEEE 802.15.4), ZWave, or the SimpliciTI protocol. In another embodiment, a data communication protocol of

<td colspan="2">own technology.</td><td>In</td><td colspan="2">Another way</td><td>of realization,</td><td>the</td><td>link</td><td>of</td>

<td>communications</td><td colspan="2">i between the</td><td>module</td><td colspan="2">communication 215 and</td><td>the</td><td>modules</td><td>of</td>

<td>communication</td><td> 281</td><td>me</td><td>221 se</td><td colspan="2">get through</td><td>of the</td><td colspan="2">driver</td>

<td>supervised.</td><td>In</td><td>this</td><td>shape</td><td>of</td><td>realization i</td><td>the</td><td>link</td><td>of</td>

<td>communication</td><td>this</td><td colspan="2">constituted</td><td>by</td><td>the communication</td><td>by</td><td>line</td><td>of</td>

power (PLC) formed by injecting a transmitted signal into at least one branch circuit conductor to which the calibration device is coupled.

In the example depicted in Figure 11, the electrical power supply source 289 may include said electrical power supply source 289 with an isolation transformer and a DC direct current supply. The electrical power supply source 289 converts the incoming line voltage from an AC alternating current supply line voltage, such as 120 V in the United States and Canada or 220 V in Europe, to a low DC direct current voltage, such as 3.3 V or 5 V DC to the power controller 213 and other elements of the calibration device 180.

Controller 285 can receive a sample of the incoming AC alternating current line voltage, converted by level converter 1173 to a low voltage signal from

<img file="MX338368B_D0042.tif" />

<img file="MX338368B_D0043.tif" />

AC alternating current that is proportional to the line voltage Hs incoming AC alternating current. In some embodiments, the incoming AC supply line voltage is 120 V AC, while the AC AC low voltage signal is within the range of 0 to 3.3 V. In some embodiments, the 1173 level converter is used to shift the low voltage signal from a bipolar signal that toggles between + V and -V to a unipolar signal between 0 V and VDD, or another range of unipolar signals that is within the valid voltage range of the 1177 analog to digital converter. An 1177 analog to digital converter can sample the incoming low voltage signal as depicted in Figure 12. In the same or different embodiment, the filter 1172 can restrict the frequency range of the low voltage signal to the AC line frequency.

In numerous embodiments, by way of example, the 1177 analog-to-digital converter may be integrated with controller 285 or may be detached from controller 213 but coupled to controller 285. The sampled AC ac line voltage allows controller 213 to measure the incoming AC ac line voltage to more accurately calibrate system 100 by calculating the current drawn by the 1188 calibration load given 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 with the AC line voltage.

In some embodiments, controller 285 uses a quadrature wave low voltage signal to develop a phase reference. In this embodiment, the quadrature wave generation device 1174 creates the quadrature low voltage signal. The quadrature low voltage signal can be a quadrature wave that has the same

<img file="MX338368B_D0044.tif" />

IMPI ^J MEXICAN INSTITUTE

OF THE PROPERTY

INDUSTRIAL period and the zero crossing timing which (The low voltage AC alternating current signal. This relationship between the quadrature wave signal and the low voltage signal is depicted in Figure 13. In some embodiments , the 1174 quad wave device may include a Schmitd trigger, a comparator, or a digital logic gate such as an inverter or transistor level shifter. The square wave amplitude is chosen to be a logic level that is compatible with the 285 controller. The square wave signal does not contain information about the amplitude of the incoming AC AC line voltage, but it does contain phase information because the Positive and negative sloping edges of the square wave signal are synchronous with the zero crossings of the incoming AC AC line voltage.

In some embodiments, the phase reference derived from the low voltage signal or its square wave counterpart is used to measure the relative phase angle between the calibrated current measurement reported by the detector device 110 and the line voltage of the incoming power. This measurement of the relative phase angle between voltage and current is used to accurately account for the power factor of the reactive loads connected to the electrical power supply conductor that is measured by the sensing device 110. The factor of Power is the cosine of the phase angle between the voltage and current waveforms. This power factor can be calculated directly from a sampled low voltage signal or can be calculated indirectly, in the case of the square wave low voltage signal, by adjusting a sinusoid of the appropriate frequency to the edge transitions in the signal of square wave.

The power factor is the ratio of the actual power of the current flowing in the conductor compared to the apparent power of the current circulating in the conductor. In

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<img file="MX338368B_D0045.tif" />

In some embodiments, it is preferable to inform the user of the system 100 of the actual power of the current flowing in the electric power supply conductors 193, 194 and 195 for a better approximation of the reading of an electric power meter supplied by public services. In this embodiment, the phase information, provided by the low voltage signal, is critical to properly calculate the predicted power.

Because the 1188 calibration load dissipates current when activated using switch 1187, the 1188 calibration load is subject to heating. This heating can impair the safe operation of the 1188 calibration charge by causing thermal damage to the 1188 calibration charge itself or to other components within the housing of the calibration device 180 or to people or things in close proximity to the calibration device 180.

In some embodiments, controller 285 includes a temperature sensor 1186, such as a bimetal thermostat, thermistor, or semiconductor temperature sensor. In some embodiments, the temperature sensor 1186 interrupts the switching signal to deactivate calibration load 1188 when said calibration load 1188 or the housing of calibration device 180 is too hot.

In other embodiments, controller 285 checks the temperature reading of temperature sensor 1186 before activating calibration load 1188 to ensure that calibration load 1188 or the housing of calibration device 180 is not too hot when beginning of the calibration process. In another embodiment, controller 285 may perform extrapolation to determine if calibration load 1188 is likely to become too hot after a typical period of operation of the load.

<img file="MX338368B_D0046.tif" />

Mexican Institute of Industrial Property

<img file="MX338368B_D0047.tif" />

1188 calibration. In this embodiment, controller 285 acts to defer the calibration process until the process can be completed without the 1188 calibration load or the housing of the calibration device 180 becoming too hot.

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 locations of the processor that runs the calibration process to obtain a current measurement. calibrated.

In a first method, controller 285 is co-located with, and controls, calibration load module 283. Controller 285 can further obtain sensor readings from detector device 110 (through the communication module 281) and controller 213. Controller 285 performs the calibration process (described below with reference to Figure 18) and obtains the measurement of the calibrated current. In these exemplary embodiments, the calibration calculation module 229 may be located in the calibration device 180 and not in the computer calculation unit 120.

In the first method, where controller 285 executes the calibration process, communication module 281 receives incoming signal measurements from detector device 110 and / or computer computing unit 120. Controller 285 can calculate the calibrated current measurements using the 2000 method in Figure 20. After calculating the calculated current measurements, the calibration device 180 can communicate the calibrated current measurements to the computer computing unit 120 for display or other uses.

In a second method, a remote processor, such as controller 225 (Figure 2) or controller 213 (Figure 2), operationally commands calibration load 1188 to turn on and off and this controller (controller 225 or controller 213)

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INDUSTRIAL

<img file="MX338368B_D0048.tif" />

Perform the 1800 calibration method depicted in Figure 18 and obtain the calibrated current measurement as described in Method 2000 in Figure 20.

When the second method is being used with controller 225 in calibration control, controller 225 receives a message through a communication link from controller 285. In some embodiments, controller 225 sends a message to activate the calibration load for a 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 1188 is activated until a disconnect message is received by controller 285 or until the operational termination of a timeout timer or activation of the temperature sensor 1186 indicating that the 1188 calibration charge or its housing is too hot.

In other embodiments, controller 285 independently makes a decision to activate the calibration load for a particular period of time. In some embodiments, by way of example, controller 285 switches calibration load 1188 by activating and deactivating it for a particular period of time, while at the same time, earlier or later, it sends a notification to controller 225 indicating that 1188 calibration load has been activated. In this embodiment, controller 213 uses a time offset, known between messages received from controller 285, to synchronize the flow of the calibration procedure to the calibration load 1188, with the on / off times indicated by a message received from controller 285 through a communication link. In other embodiments, by way of example, controller 285 activates

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INDUSTRIAL

<img file="MX338368B_D0049.tif" />

and disables the 1188 calibration load «apnonria chía is known for controller 213 and / or 225 (Figure 2).

Figure 11 illustrates, by way of example, the switched load 1105 in the calibration device 180. Other possible configurations of the switched load are shown in Figures 14 to

17.

More specifically, Figure 14 illustrates an exemplary embodiment of the switched load 1405, according to a third embodiment. The switched load 1405 may include: (a) switches 1187 and 1442, and (b) calibration loads 1188 and 1441. In this embodiment, the switched load 1405 replaces the switched load 1105 on the calibration device 180, which is depicted in Figures 2 and 11.

In this embodiment, the switched load 1405 can be configured to calibrate the measurement of a single conductor with current flow (a feeder to the branch circuit labeled Line) that is measured by the detector device 110. In this embodiment, Controller 285 can switch between calibration loads 1188 and 1441 to provide two different measurement sets for use in the calibration process. In other exemplary embodiments, the switched load 1405 may include three or more switches of three or more calibration loads.

Figure 15 illustrates, by way of example, the switched load 1505, according to a fourth embodiment. The switched load 1505 may 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 depicted in Figures 2 and 11.

In this embodiment, the switched load 1505 can be designed to calibrate the measurement of two current-carrying conductors (one branch circuit feeder labeled Line 1 and Line 2) that are measured by the device

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<img file="MX338368B_D0050.tif" />

detector 110. In this embodiment, two distinct calibration loads 1588 and 1541 can be switched between individual line conductors and the neutral conductor, under the control of a switching signal from controller 285. Controller 285 can control the signals switch to electrically couple the calibration load as follows:

<td>Switch authorized</td><td>Load of calibration coupled</td><td>Effect</td>

<td>Switch 1587</td><td>Load of</td><td>Allow the</td>

<td>It is authorized</td><td>calibration 1541</td><td>calibration one measurement of a feeder to a circuit of derivation Labeling Line 1</td>

<td>Switch 1542</td><td>Load of</td><td>Allow the</td>

<td>It is authorized</td><td>calibration 1588</td><td>calibration one measurement of a feeder to a circuit of derivation Labeling Line 2</td>

<td>Switches</td><td>Loads of</td><td>Allow the</td>

<td>1587 and 1542 are</td><td>1541 calibration and</td><td>calibration of the</td>

<td>authorized</td><td> 1588</td><td>feeders to circuits of derivation labeled Line 1</td>

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MEXICAN INSTITUTE OE INDUSTRIAL property

<td></td><td></td><td>and Line 2</td>

<td>Nor the switch 1587 nor the switch 1542 are authorized</td><td>None</td><td>None</td>

Figure 16 illustrates, by way of example, a switched load 1605, according to a fifth embodiment. The switched load 1605 may include: (a) switches 1687, 1642, and 1643 and (b) calibration loads 1588 and 1541. In this embodiment, the switched load 1605 replaces the load 1105 in the calibration device 180 of the Figures 2 and 11.

In this embodiment, the switched load 1605 can also be configured to calibrate the measurement of more than one conductor with current flow (a feeder to the branch circuit labeled Line 1 and Line 2) that is measured by the detector device 110. In this embodiment, two distinct calibration loads 1588 and 1541 are switched to allow calibration loads 1588 and 1541 to be connected individually with neutral return or in a pair for the Line 1 - Line 2 pair that is common in a Split phase electrical power supply system. Controller 285 can control the switching signals to electrically couple the calibration loads as follows:

<td>Switch authorized</td><td>Load of calibration coupled</td><td>Effect</td>

<td>Switches</td><td>The load of</td><td>Allow the</td>

<td>1643 and 1642 are</td><td>calibration 1541</td><td>calibration one</td>

<td>authorized</td><td>with neutral return</td><td>measurement of a</td>

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<td></td><td></td><td>feeder to circuit of derivation Labeling Line 1</td>

<td>Switches</td><td>The load of</td><td>Allow the</td>

<td>1643 and 1687 are</td><td>calibration 1588</td><td>calibration one</td>

<td>authorized</td><td>with neutral return</td><td>measurement of a feeder to circuit of derivation Labeling Line 2</td>

<td>Switches</td><td>The loads of</td><td>Allow the</td>

<td>1643, 1642 and 1687</td><td>1541 calibration and</td><td>calibration of</td>

<td>are authorized</td><td>1588 with return neutral</td><td>feeders to circuits of derivation labeled Line 1 and Line 2</td>

<td>Switches</td><td>The loads of</td><td>Allow the</td>

<td>1642 and 1687 are</td><td>1541 calibration and</td><td>calibration of a</td>

<td>authorized but</td><td>1588 in series between</td><td>electrical system of</td>

<td>not the switch 1643</td><td>Line 1 and Line 2</td><td>divided phases from a device single calibration divided phases</td>

<td>None of the 1643 switches, 1642 and 1687 are authorized</td><td>None</td><td>None</td>

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0052.tif" />

Figure 17 illustrates, by way of example, a switched load 1705, according to a sixth embodiment. The switched load 1705 may include: (a) switches 1787, 1742, and 1743 and (b) the 1788 calibration load. In this embodiment, the switched load

1705 it replaces the switched load 1105 on the calibration device 180 as depicted in Figures 2 and 11.

In this embodiment, the switched load 1705 is also configured to calibrate the measurement of more than one current circulating conductor (a feeder to the branch circuit labeled Line 1 and Line 2) that is measured by the detector device 110. In In this embodiment, a single 1788 calibration load is switched to allow for calibration of two conductors plus one neutral as is common in a split phase power supply system. Switches 1787 and 1743 can be single-acting double-pole switches (SPDT). The 1787 and 1743 switches can be used with the 1788 calibration load to couple different combinations of the branch circuit conductors. The switched charge 1705 may be more economical to implement compared to the switched charge 1605 (Figure 16) due to the single calibration charge used. Controller 285 can control the switching signals for electrical coupling of the calibration loads as follows.

<td>Switch authorized</td><td>Load of calibration coupled</td><td>Effect</td>

<td>Switch 1787</td><td>The load of</td><td>Allow the</td>

<td>is in the</td><td>1788 calibration</td><td>calibration one</td>

<td>position 1 the</td><td>with neutral return</td><td>measurement of a</td>

<td>switch 1743</td><td></td><td>feeder to</td>

<td>is in the</td><td></td><td>circuit of</td>

<td>position 1 and the</td><td></td><td>derivation</td>

<img file="MX338368B_D0053.tif" />

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<td>switch 1742 is in the position 1</td><td></td><td>Labeling Line 2</td>

<td>Switch 1787</td><td>The load of</td><td>Allow the</td>

<td>is in the</td><td>1788 calibration</td><td>calibration of a</td>

<td>position 0 the switch 1743 is in the position 1 and the switch 1742 is in the position 1</td><td>with neutral return</td><td>feeder to circuit of derivation Labeling Line 1</td>

<td>Switch 1787</td><td>The load of</td><td>Allow the</td>

<td>is in the</td><td>calibration 1788 in</td><td>calibration of a</td>

<td>position 0 the</td><td>series between the</td><td>electric system</td>

<td>switch 1743</td><td>Line 1 and Line 2</td><td>divided phases</td>

<td>is in the</td><td>without any return</td><td>From a</td>

<td>position 0 the switch 1742 is in the position 1</td><td>neutral</td><td>device calibration of divided phases only</td>

<td>Switch 1787 is in the position 0 or 1, the switch 1743 is in the position 0 or 1 and switch 1742 is in the position 0 (is</td><td>None</td><td>None</td>

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0054.tif" />

—Mu

<td>say a position disconnected)</td><td></td><td></td>

In numerous exemplary embodiments, both phase lines of the electrical infrastructure need to be calibrated. Consequently, one of the calibration devices in Figures 11 and 14 to 17 would need to be inserted into the first phase shunt and the second phase shunt. In the exemplary embodiment shown in Figure 2, the calibration device 180 is the first calibration device and the computing unit 120 includes the second calibration device. In other embodiments, by way of example, a single calibration device (eg, a calibration device with one of the switched loads 1505, 1605, or 1705) can be coupled to a 240V outlet, which is attached to the first and second phase leads.

In the embodiment where one of the calibration devices of Figures 11 and 14 to 17 is inserted into each of the first phase shunt and the second phase shunt, the calibration devices need to be able to communicate with each other, with the detector device and the computer calculation unit. Several different communication methods could be put into practice. By way of example, all of the calibration devices could receive and transmit data. In other embodiments, by way of example, one calibration device (eg, the calibration device 180 in Figure 1) could transmit data and the second calibration device (eg, the calculation unit 120 in Figure 2) could receive data.

In some embodiments, the two calibration devices can be in radio communication. As an example, the communication module 281 and the communication module

221 Figure 2 may include radio equipment. The 'IMPI

<img file="MX338368B_D0055.tif" />

CALIBRATION INSTITUTE OF PROPERTY calibration devices are configured to determine if they are in electrical phase shunts riifprpntaa mmuniranrin oi phase phase of 60 Hz observed to the other calibrators. In some embodiments, by way of example, a single calibration device can wirelessly communicate to the other calibration device when a zero cross occurs in the electric 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 shunt. If there is an offset between the observed zero crossing and the received message, the calibration devices are installed on different electrical phase leads.

In the same or different embodiment, by way of example, user communication device 184, in calibration device 180 (Figure 1) may include a single red / green LED diode. A green LED diode can indicate that two calibration devices are correctly installed in the two different phases. By way of example, the user first installs the calibration device 180 of Figure 1 (that is, the transmitting calibration device) into an arbitrary electrical outlet. Next, the user installs the computer computing unit 120 of Figure 1 (that is, the receiving calibration device) into another electrical outlet. The LED of user communication device 184 may light red to indicate that they are both in the same phase or green if they are in different phase leads. The user can move the second calibrator to different power outlets until the green indicator on user communication device 184 is displayed.

In another embodiment, wireless communication may also exist between each of the detector device 110, the calibration device 180, and the computing unit.

<img file="MX338368B_D0056.tif" />

- 44 - IMPI

COMPUTER MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY 120. In this embodiment, the detector device 110 can detect the two electrical phases in the circuit breaker panel. When the calibration device 180 cycles through its electrical charges, the calibration device 180 can notify detector device 110 and detector device 110 that it can determine which phase calibration device 180 it is coupled to. Computer computing unit 120 can also communicate to detector device 110 when it begins its charging cycle. Detector device 110 observes at which phase angle these changes are occurring to deduce that the calibrators are installed in two different phases.

In another embodiment, by way of example, a non-wireless communication method may be used for communication between the calibration device 180 and the computing unit 120. In these embodiments, by way of example, the modules of Communication 221 and / or 281 can include a signal injector and / or a signal receiver. In this embodiment, by way of example, calibration device 180 and computer computing unit 120 can send a signal through the electrical power infrastructure. As an example, a simple 1 kHz tone (kilohertz) can be used. In the same or different embodiments, by way of example, the signal consists of an amplitude modulated voltage injected into one or more conductors of the electrical energy infrastructure. In another embodiment, the signal consists of an amplitude modulated current drawn from the electrical power infrastructure. In another embodiment, the signal consists of a frequency modulated current or voltage. In one embodiment, the computer computing unit 120 can be designed as a signal transmitter while the calibration device 180 can be designed as the receiver. When the 180 calibration device is inserted into a power outlet

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0057.tif" />

Electrical, user communication device 184 can turn on a green LED if it cannot detect the presence of the signal that is transmitted by the first device. If the calibration device 180 and the computer computing unit 120 are coupled to separate phase shunts, the calibration device 180 and the computer computing unit 120 would not be able to detect signals placed in the electrical power infrastructure by the other unit.

If the calibration device 180 detects the signal, then a red light may indicate that the two calibration devices are in the same phase. At this point, the user may be instructed to move one or the other of the calibration device 180 or the computer computing unit 120 to a different electrical outlet. In another embodiment, instead of communication modules 221 and 281 that include a signal injector and / or receiver, communication modules 221 and 281 may include power line communication (PLC) modules to enable the device of calibration 180 and to the computing unit 120 to communicate through the electrical energy infrastructure.

Turning to another embodiment, FIG. 18 illustrates a flow chart for one embodiment of a method 1800 for calibrating an electrical power monitoring system, in accordance with one embodiment. Method 1800 is by way of example only and is not limited to the embodiments presented herein. Method 1800 can be used in numerous different or exemplary embodiments, not specifically illustrated or described herein. In some embodiments, the activities, procedures, and / or processes of method 1800 can be performed in the order presented. In other embodiments, the activities, procedures and / or processes of method 1800 can be performed in any other suitable order. In other embodiments, one or more of the activities, procedures, and / or processes in ^ eT ^ metO 'can be combined or omitted. -

LÍISTITUTO MEXICANO 'DE LA PROPERTY

<img file="MX338368B_D0058.tif" />

Method 1800 can be considered to describe a general method of calibrating a detector device. This method may involve determining one or more calibration coefficients that can be used to calculate the predicted current in the electrical power infrastructure in the structure in method 2000 in Figure 20. The method described below can be used to calculate, precisely, the calibration coefficients regardless of the position of the detector device 110 (Figure 1) on panel 196 (Figure 1) with the exception of the following points: (a) if the electric current detectors 211 (Figure 2) are positioned away from the main power supply conductors 193 and 194 (Figure 1) so that almost no discernible signal is measured from the main power supply conductors electric power 193 and 194 and (b) if all of the electric current detectors 211 (Figure 2) are placed very close to the neutral electric power supply conductor 195 (Figure 1) and away from the electrical power supply conductors 193 and 194.

The method 1800 depicted in Figure 18 includes an activity 18 60 for obtaining and storing one or more first reference baseline measurements. In some exemplary embodiments, the detector device 110 (Figure 2) can be used to obtain first baseline measurements of reference using electric current detectors 211 (Figure 2). These first reference baseline measurements may include the rated current flowing in at least one of the electrical power supply conductors 193 and 194 (Figure 1) due to electrical devices that are consuming electrical energy. In addition, on each sensor (eg, detectors 641 and 642 (Figure 6) or detectors 941i, 941₂, ..., 941n

IMPI

MEXICAN INSTITUTE

OF THE PROPERTY V ^ s ^ ÍS &amp; íCZaÚ '

INDUSTRIAL XaBy (Figure 9)), an amplitude and phase measurement can be performed. Each reading of the amplitude, L, will be remembered or llUlllbltí L_orldn and each phase reading, 0, is memorized with the name 0_orid-N, where N is the number of the detector. In some embodiments, by way of example, the first reference baseline measurement is performed on the first phase shunt and on a second phase shunt.

In some exemplary embodiments, Activity 1860 further includes determining the amplitude and phase angle of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some exemplary embodiments, the electrical voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.

Subsequently, the method 1800 of Figure 18 includes a time coupling activity 1861 of a first known calibration charge to the first phase shunt. In some embodiments, by way of example, the calibration device 180 (Figures 1 and 11) can be coupled to one of the calibration loads at the switched loads 1105, 1405, 1505,

1605 or 1705 of Figures 11, 14, 15, 16 and 17, respectively.

Next, the method 1800 of Figure 18 includes an activity 1862 of obtaining and memorizing one or more first calibration measurements in the first phase derivation. In some embodiments, by way of example, detector device 110 (Figure 2) can be used to obtain the first calibration measurements of electric current detectors 211 (Figure 2). In some embodiments, by way of example, the first calibration measurements are performed while a known calibration load from the switched load 1105, 1405, 1505, 1605 or 1705 of Figures 11, 14, 15, 16 and 17, respectively, it is coupled to the first phase shunt (eg, Line 1 in Figures 15 to 17). This first known calibration charge

IMPI

MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL

<img file="MX338368B_D0059.tif" />

will consume a current L_ACii known. These first calibration measurements can include the current nomirrsrl^,_qvr8'Cruises · ΰΐί püí 'at least one of the electrical power supply conductor 193 and 194 (Figure 1) due to utensils that are consuming electrical power and the first known calibration load.

By way of example, a measurement of amplitude and phase angle is performed on each detector (eg, detectors 641 and 642 (Figure 6) or detectors 941i, 9412, 941n (Figure 9)). Each reading of the amplitude L is memorized with a name such as Lnew-Ni and each reading of the phase angle 0 is memorized with the name such as 0new-Ni, where N is the number of the detector.

In some exemplary embodiments, Activity 1862 also includes determining the amplitude and phase angle of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some exemplary embodiments, the electrical voltage detector 228 of Figure 2 can be used to determine the phase angle of the voltage.

Method 1800 in Figure 18 continues with an activity 1863 of disconnecting the first known calibration load and temporarily coupling a second known calibration load to a second phase shunt. In some exemplary embodiments, the calibration device 180 (Figures 1 and 11) can be coupled to one of the calibration loads on the switched load 1405, 1505, or 1605 of Figures 14, 15, and 16, respectively . In some embodiments, by way of example, the second known calibration charge is coupled to a second phase shunt (eg, Line 2 in Figures 15 to 17).

Subsequently, the method 1800 in Figure 18 includes an activity 1864 for obtaining and storing the second calibration measurements in the second phase derivation. In some embodiments, by way of example, the device

<img file="MX338368B_D0060.tif" />

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY detector 110 (Figure 2) can be used to hhl-ener the second calibration measurements from electric current detectors 211 (Figure 2). These second calibration measurements may include the rated current flowing in at least one of the electrical power supply conductors 193 and 194 (Figure 1) due to the utensils that are consuming electrical power and the second known calibration charge. In some embodiments, by way of example, the second calibration measurements are made while a known calibration charge is coupled to the second phase shunt (eg, Line 2 in Figures 15-17). The second known calibration charge will consume a known current L_ACi-2.

As an example, in each detector (eg, detectors 641 and 642 (Figure 6) or detectors 941i, 941₂, ..., 941n (Figure 9)) an amplitude and phase angle measurement is performed. Each amplitude reading, L, is memorized with the name Lnew-N-2 and each phase angle reading, 0, is memorized with the name 0_newN-2, where N is the number of the detector.

In some exemplary embodiments, Activity 1864 further includes determining the amplitude and phase angle of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some exemplary embodiments, the electrical voltage sensor 228 of FIG. 2 can be used to determine the phase angle of the voltage.

Next, method 1800 of Figure 18 includes an activity 1865 to disconnect any known calibration load (i.e., the second calibration load) from the power supply conductors 193, 194 and / or 195 (Figure 1 ).

The method 1800 in Figure 18 continues with an activity 1866 of obtaining and memorizing one or more second reference baseline measurements. In some embodiments, a

IMPI

MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL

<img file="MX338368B_D0061.tif" />

As an example, the detector device 110 (Figure 2) can be used to obtain the second reference baseline measurements from the electric current detectors 211 (Figure 2). These second reference baseline measurements can include the rated current flowing in at least one of the electrical power supply conductors 193 and 194 (Figure 1) due to the devices that are consuming electrical power. The purpose of this second baseline reading is to ensure that the baseline load observed during Activity 1861 has not changed during the calibration process. If the measurements in Activity 1866 are equal to the measurement since 1861 within a predetermined magnitude, the measurements from Activity 1866 can be discarded. If the measurements in Activity 1866 are outside the predetermined magnitude, the measurement since 1861 can be discarded. In other embodiments, by way of example, activity 1866 may be omitted.

In some exemplary embodiments, Activity 1866 further includes determining the amplitude and phase angle of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some exemplary embodiments, the electrical voltage sensor 228 of Figure 2 can be used to determine the phase angle of the voltage.

Subsequently, the method 1800 in Figure 18 includes an activity 1867 for determining the calibration coefficients. In some exemplary embodiments, Activity 1867 includes applying a detector calibration equation for baseline measurement and each calibration measurement to determine device calibration factors. detector 110 (Figure 1) to provide a calibrated current measurement in the at least one conductor that is detected by the detector device 110. In

IMPI

<img file="MX338368B_D0062.tif" />

MEXICAN INSTITUTE Say THE PROPERTY

INDUSTRIAL

<img file="MX338368B_D0063.tif" />

Calibration calculation 229 (Figure 2) can determine the calibration coefficients as described below.

FIG. 19 illustrates a flow chart for an exemplary embodiment of calibration coefficient determination activity 1867, according to the first embodiment. In some embodiments, by way of example, Activity 1867 may broadly include the calculation of calibration coefficients 0m, Ki, K₂, Yi and Y₂. In other embodiments, by way of example, other calibration coefficients can be determined.

Referring to Figure 19, Activity 1867 includes a 1971 procedure for determining potential calibration coefficients for the first phase shunt. As other examples, for each detector 1 to N inclusive (where N is the number of detectors in the electric current detector), the 1971 procedure may include calculating Xn-i and 0m-ni using Loia-N, 0oia-N, Lcai-i, Lnew-Ni and 0new-Ni, where:

Xn-1 ~ {Lold-N² + Lnew-N- |² "2 * Lold-N * Lnew-N-1 * COS (0_or1d-N - 0 new-N-1)} j / Uu,

0M-N-1 ^- 0bcw-ni "Without ¹ [(Loid-N * Sin (0_orwn - 0new-Ni)) / (Xn-i * L_ACii)]

Furthermore, by way of some examples, if 0m-ni&gt; 18O °, then 0M-N-1 = 0M-N-1-180 °

Xn-i = Xn-i * (- 1)

Activity 1867 in Figure 19 continues with a 1972 procedure of determining potential calibration coefficients for the second phase shunt. In some exemplary embodiments, for each detector 1 to N inclusive, the 1972 procedure may include calculating Xti-2 and 0M-N-2 using L_orid-N, 0old-N, Lcal-2, Lnew-N-2 and 0new-N-2, where:

<img file="MX338368B_D0064.tif" />

<img file="MX338368B_D0065.tif" />

<img file="MX338368B_D0066.tif" />

Y θΜ-Ν-2 ~ 0new-N-2 "YES * [(Lold-N * YES (0_or| dN - 0_new-N-2)) / (Xn-2 * L_ea|.2 ) ]

Furthermore, by way of other examples, if 0m-n-2&gt; 18O °, then

0M-N-2⁼0M-N-2^— 1 80°

Xn-2 = Xn-2 * (- 1)

Subsequently, activity 18 67 in Figure 19 includes a 1973 procedure for checking the validity of measurements. In the 1973 procedure, if 0m-ni = 0m-n-2 within a predetermined tolerance (eg 0.1%, 1%, 5%, 10% or 20%) for each detector 1 to N inclusive, they are maintained measurements for the detector. Yes 0_M~ n-1 0m-n-2, within the predetermined tolerance, phase angles for that detector are discarded.

Next, Activity 1867 in Figure 19 includes a 1974 procedure for determining a statistical mode or, 0mode for 0m-ni for detectors not discarded in the 1973 procedure. By way of other examples, the statistical mode is the angle of phase, which occurs more frequently, within the predetermined tolerance for detectors not discarded in the 1973 procedure.

Activity 1867 in Figure 19 continues with the 1975 procedure for determining a first part of the calibration coefficients. In some embodiments, by way of example, from the remaining detectors, the 1975 procedure includes choosing the sensor with the highest Xn-1 value and assigning Xn-i = Ki and Xn-2 = K2 and 0m-ni = 0m-k. This chosen detector will be referred to as a K detector hereafter. Detector K can be dropped from the list of available detector candidates for the remainder of Activity 1867.

Subsequently, activity 1867 in Figure 19 includes a 1976 procedure for determining a second part of the

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0067.tif" />

calibration coefficients. By way of other examples, from the remaining detectors, the 1976 procedure includes choosing the detector with the highest value Xn-2 and assigning Xn-2 = Yi and Xn-2 = Y2 and 0m-n-2 = 0m-y. This chosen detector will be referred to as detector Y onwards.

Next, Activity 1867 in Figure 19 includes a 1977 procedure for determining a third of the calibration coefficients. By way of other examples, 0m is calculated where:

0M ⁼ [0M-Y ⁺ 0M-k] / 2

The exemplary embodiment of the formulas used to determine the above calibration coefficients are by way of example only. By way of other examples, other formulas (eg, linear, nonlinear, quadratic, and / or iterative equations) can be used to calculate the same or different calibration coefficients.

By way of example, the detector device can be calibrated (and the predicted current determined) using only the detector. In this example mode, the detector is located in a location such that the magnetic field from the main electrical power supply conductors 193 and 194 (Figure 1) is symmetrical in the detector. That is, the magnetic field from the main power supply conductors 193 and 194 (Figure 1) is symmetrical in the detector. Furthermore, in this embodiment, by way of example, the detector Z is in a place where the magnetic field from the main electrical power supply conductor 195 (Figure 1), representing the neutral return conductor, is small and can be ignored.

At this point the detector is called where the magnetic fields are from a symmetric Z detector. In this embodiment, by way of example, the current measured in detector Z is equal to

Lz^—Kz * Lpredicted

<img file="MX338368B_D0068.tif" />

IMPI

INSTITUTO MEXICANO CE THE INDUSTRIAL PROPERTY where Lz is the current measured by the detector Z, constant and L_predicted is the combined current expected in the first phase shunt and in the second phase shunt.

In this embodiment, by way of example, the reference baseline current measurement made at detector Z in activity 1860 or 1866 can be memorized as L_zbaseiíne · The first calibration measurements made in the Z detector can be stored in Lz-_Cai and the current of the first known calibration charge can be ΔΡ. In this embodiment, by way of example, Kz can be calculated where:

Kz⁼ (Lz-cal “Lz-baseline) / ΔΡ

In another embodiment, by way of example, other calibration equations may be used that require more than two calibration measurements. In this embodiment, by way of example, activities 1861-1866 (Figure 18) can be repeated as many times as needed with different calibration loads to obtain the required number of calibration points.

After completing the 1977 procedure, the activity 1867 for calculating the calibration coefficients is completed.

Referring again to Figure 18, method 1800 of Figure 18 continues with an activity 1868 for memorizing the calibration coefficients. In some exemplary embodiments, the calibration coefficients can be stored in memory 226 for calculation unit 120 of the

Figures 1 and 2. In the same or different embodiments, by way of example, the calibration coefficients can be stored in memory of the detector device 110 and / or calibration device 180 of Figure 1. In other embodiments, the calibration coefficients can be transmitted to a distant server for storage and use. After activity 1868, method 1800 is completed.

FIG. 20 illustrates a flow chart for one embodiment of a current determination method 2000.

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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0069.tif" />

provided in the supply conductors of * SU'L! iyla lIl-uLeu m. Método., Method 2000 is merely by way of example and is not limited to the embodiments presented herein. Method 2000 can be used in numerous different embodiments or by way of examples, not specifically illustrated or described herein. In some embodiments, method 2000 activities, procedures, and / or processes can be performed in the order presented. In other embodiments, the method 2000 activities, procedures, and / or processes can be performed in any other suitable order. In other embodiments, one or more of the activities, procedures, and / or processes in method 2000 can be combined or omitted.

Method 2000 describes a general method of determining the predicted electrical power (and / or electrical current) used in electrical power supply conductors. This method involves the use of several predetermined calibration coefficients (see method 18 of Figure 18) to determine the expected current in the electrical power infrastructure of the structure. The method described below can be used to calculate, accurately, the predicted currents regardless of the position of the detector device 110 (Figure 1) on panel 196 (Figure 1) with the exception of the following points: (a) if the electric current detectors 211 (Figure 2) are placed so far from the main power supply conductors 193 and 194 (Figure 1) that almost no discernible signal is measured and (b) if all of the electric current detectors 211 (Figure 2) are located very close to the neutral electric power supply conductor 195 (Figure 1) and away from the electric power supply conductors 193 and 194. In some exemplary embodiments, method 2000 may include, in broad terms, the calculation of the predicted current, Li-p_redicted and L2-_Predicted (as reported by electric utilities

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0070.tif" />

that provide electrical energy) in each branch of the electrical energy infrastructure (eg, the first and second phase shunts).

In some exemplary embodiments, method 1800 in Figure 18 and method 2000 can be combined to create a method of using an energy consumption measurement device. As an alternative, method 1800 in Figure 18, combined with method 2000 can be considered a method of determining the predicted current (and / or electrical power) in the electrical power supply conductors. In these embodiments, method 1800 can be performed once to determine calibration coefficients, and method 2000 can be performed repeatedly before determining the predicted current (and / or electrical power) that is used by charging the build in multiple times.

Referring to Figure 20, method 2000 includes an activity 2061 of performing a first set of measurements using a first electrical current detector. In various embodiments, one of the electric current detectors 211 (Figure 2) can be used to perform the first set of measurements. In some exemplary embodiments, Activity 2061 may include measuring an amplitude and a phase angle at detector K. The amplitude reading can be memorized with the name Lk and the phase angle reading can be memorized with the name 0κ ·

In some exemplary embodiments, Activity 2061 also includes determining the amplitude and phase angle of the voltage. The phase angle of the voltage can be used to help calculate the phase angle of the current. In some exemplary embodiments, the electrical voltage detector 228 of Figure 2 can be used to determine the phase angle of the voltage.

<img file="MX338368B_D0071.tif" />

OF INDUSTRIAL PROPERTY

<img file="MX338368B_D0072.tif" />

Subsequently, the method 2000 in Figure 20 includes an activity 2062 for carrying out a second set of measurements using a second electric current detector. In various embodiments, one of the electric current detectors 211 (Figure 2) can be used to perform the first set of measurements. In some embodiments, by way of example, activity 2063 may include measuring an amplitude and a phase angle of the current in detector Y. The reading of the amplitude may be memorized under the name Ly and the reading of the phase angle can be memorized with the name 0y.

In some embodiments, by way of example, activity 2062 also includes determining the amplitude and phase angle of the voltage. As stated above, the phase angle of the current is equal to the phase angle measured by the detector minus the phase angle of the voltage. In some exemplary embodiments, the electrical voltage detector 228 of Figure 2 can be used to determine the phase angle of the voltage.

Next, the method 2000 in Figure 20 includes an activity 2063 for determining a predicted electrical power used in a first phase shunt. In some exemplary embodiments, activity 2063 may include determining the amplitude Li of the first phase shunt and the phase angle 0i of the first phase shunt, using the calibration coefficients 0m, Κι, K2, Yi and Y2, where:

L, = H {(L_K / K₂)² + (LY i Y2)² - 2 * (LK / K₂) * (L_and / AND₂/ Cos (0_K - 0γ)}] / [(K, / K₂) (Y1 / Y2)]

0, = Tan '¹ [{(L_K/ K₂) * Without (0_K - 0_M) - (L_AND/AND₂) * Without (0_and - 0_M)} / {(L_k/ K₂) * Cos (0k - 0_M) (L_and/AND₂) * Cos (0_and-0_m)} ]

In some embodiments, by way of example, the predicted power, Pi-predicted, in the first phase shunt may be the electrical power in the first phase shunt that is

IMPI ^

MEXICAN INSTITUTE

FROM THE CVaunpStL PROPERTY

INDUSTXIAL would report for the electric public services. In some embodiments, the predicted current Li-_predicted in the first phase derivation is:

Pl-predicted⁼V * Li * CoS (0l) where V is the voltage measured in activity 2062.

The method 2000 in Figure 20 continues with the activity 2064 of determining a predicted electrical power used in a second phase shunt. In some embodiments, activity 2064 may include determining the amplitude L2 of the second phase shunt and the phase angle 02 of the second phase shunt using the calibration coefficients 0m, Κι, K2, Yi, and Y2. , where:

L₂ = H {(Lk / K4)² + (Ly / y,)² - 2 * (L_K / K,) * (L_AND/ Y,) * Cos (0K - 0γ)}] / I (KAi&gt; OW) 1 and

0₂ = So⁴ [{(U / K,) * Sm (0_K - 0_M) - (Ly / Y ^ Sin ^ Y - 0_M)} / {(WCo ^ - 0_M) (L_and/ Y,) * Cos (0y -0_M)} ]

In some embodiments, by way of example, the predicted electrical power, P2-predicted, in the second phase shunt may be the electrical power in the second phase shunt as reported by the utility. In some embodiments, the predicted current, P2-predicted in the second phase shunt, is:

P2-predicted⁼V * L2 * COS (02) where V is voltage measured in activity 2062.

In a second embodiment, by way of example, where the detector device is using only one detector Z, the determination of the predicted power, Ppredicted is relatively simple. In this embodiment, by way of example, the Z sensor has been placed in a location such that the magnetic field from the main power supply conductors 193 and 194 (Figure 1) is symmetrical in the Z detector and the detector Z is in a place where the field

MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL

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Magnetic from the main supply conductor of the electrical supply 195 (Figure 1) is of small magnitude and can be ignored.

In this embodiment, by way of example, the electrical power measured in detector Z can be calculated where:

Ppredicted⁼V * Lz / kz and where V is the voltage measured in activity 2,062, Lz is the current measured by detector Z in activity 2061, Kz is a constant (already determined in activity 1867 in Figure 18).

Method 2000 in Figure 20 continues with an activity 2065 of utilization and / or communication of the current expected in the first and second phase shunts. The total predicted electrical power, Ppredicted is the sum of the predicted electrical power in the first phase shunt and the predicted electrical power in the second phase shunt:

Ppredicted⁼P2-predictedtPl-predicted

In some exemplary embodiments, the electrical power used by the load on the structure (i.e., Ppredicted) can be displayed to the user on the user communication device 134 of the computer computing unit 120 (Figures 1 and 2) . In other embodiments, by way of example, the electrical power used (and / or the intended current) may be communicated to the electrical power supplying entity providing the electrical power or may be communicated to other entities.

In other embodiments, the predicted current can be used in unbundling loads based on the step change and phase angle between the observed current and voltage. Computer computing 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 their use. In addition, the disaggregation can be done observing the presence of 120 V and 240 utensils

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V from the current data on each phase shunt. In addition to the staggered changes of the aggregate current, the staggered changes further identifies different (i.e. individual utensils in different in each phase shunt the presence of a load or similar loads installed places in the building). The change in phase angle observed due to an internal reactance of a device allows the identification of inductive loads (i.e. fans, motors, microwaves, compressors). The predicted reactance is not required, since the observed phase angles are sufficient as long as they are associated with a forward device. In some embodiments, by way of example, the momentary change in current consumption in the electrical power infrastructure may constitute a feature of operational initiation of a device, which may characterize residential utensils. This technique involves the use of a template that fits into a known library of starting signatures to classify unknown loads. This characteristic space is much less susceptible to overlap of the 20 device categories and is capable of separating numerous devices with similar load characteristics. As an example, two motors with similar reactive and actual power consumption can have very different starting characteristics and thus be broken down. This method may be suitable for electrical devices that consume large current loads or at least consume large currents during the initiation phase. With the use of these activities, loads can be unbundled in the electrical energy infrastructure.

After activity 2065, method 2000 is completed.

Figure 21 illustrates, by way of example, a first location of two electric current detectors relative to the main electric power supply conductors 193, 194 and 195 (Figure 1), in accordance with one embodiment.

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The location of the two electrical current detectors, depicted in Figure 21 was used for the 1800 test calibration method of Figure 18 and the 2000 current determination method of Figure 20. Loads coupled to the main conductors power supply 193, 194 and 195 (Figure 1) were randomly switched on and off. Although the loads are 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 in Figures 18 and 20 after measurements were made with the two electric current detectors. Figure 22 illustrates a graphical representation comparing the predicted currents with the methods of Figures 18 and 20 compared to the measured currents. As illustrated in Figure 22, the predicted currents accurately reflect the measured currents.

Figure 23 illustrates, by way of example, a second location of two electrical current detectors relative to the main electrical power supply conductors 193, 194 and 195 (Figure 1), in accordance with one embodiment. The location of the two electrical current detectors depicted in Figure 23 was used to test also the calibration method 1800 in Figure 18 and the current determination method 2000 in Figure 20. Loads coupled to main power supply conductors 193, 194, and 195 (Figure 1) were randomly switched on and off. Although the loads were randomly switched on and off, the actual current was measured using a current monitor. The predicted currents were also calculated using the 1800 and 2000 methods after measurements were made with the two electric current detectors. Figure 24 illustrates a graphical representation comparing the currents predicted by the methods of Figures 18

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Although the invention has been described with reference to specific embodiments, it will be understood by those skilled in the art that various changes can be made without thereby departing from the spirit of the inventive idea and the scope of protection of the invention. Accordingly, the inventive idea of ​​the embodiments of the invention is intended to be illustrative of the scope of protection of the invention and is not intended to be limiting. The scope of the invention is intended to be limited only to the extent required by the appended claims. As an example, for an expert in this matter it will be easily evident that activities 1860, 1861, 1862, 1863,

1864, 1865, 1866, 1867 and 1868 represented in Figure 18, the procedures 1971, 1972, 1973, 1974, 1975, 1976 and 1977, represented in Figure 17 and the activities 2061, 2062, 2063, 2064 and 2065, represented in Figure 20 they can be made up of numerous different activities, as well as different procedures and can be carried out by many different modules, in numerous different orders that any element of Figure 1 can be modified and that the above description of some of these embodiments does not necessarily represent a complete description of all possible embodiments.

All elements claimed in any particular claim are essential to the embodiment claimed in that particular claim. Consequently, the replacement of one or more of the claimed elements constitutes a reconstruction and not a repair. Furthermore, benefits, other advantages, and solutions to problems have been described with respect to specific embodiments. The benefits, advantages, solutions to problems and any element or elements that may

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cause any benefit, advantage or solution to problems to occur or that becomes more pronounced, however, they should not be interpreted as typical, required or essential characteristics or elements of any or all of the claims, unless such benefits, advantages, solutions or elements are declared in said claim.

Furthermore, the embodiments and limitations, here disclosed, are not dedicated to the public under the dedication doctrine if the embodiments and / or limitations: (1) are not expressly claimed in the claims and (2) are equivalent or potentially equivalents of express elements and / or limitations in the claims under the doctrine of equivalents.

It is noted that in relation to this date, the best method known by the applicant to put the aforementioned invention into practice, is the one that is clear from the present description of the invention.

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