MX2014013796A - Power monitoring system and method. - Google Patents

Abstract

A system for monitoring power in accordance with the present disclosure has a first transformer monitoring device that interfaces with a first electrical conductor electrically connected to a transformer at a first location on a power grid. The first transformer measures a first current through the first electrical conductor and a first voltage associated with the first electrical conductor. In addition, the system has a second transformer monitoring device that interfaces with a second electrical conductor electrically connected to the transformer. The second transformer measures a second current through the second electrical conductor and a second voltage associated with the second electrical conductor. Further, the system has logic configured to calculate values indicative of power corresponding to the transformer based upon the first current and the first voltage and the second current and the second voltage.

Description

SYSTEM AND METHOD OF MONITORING OF POWER DESCRIPTION OF THE INVENTION The power or energy is generated, transmitted and distributed to a plurality of destination points, such as, for example, users or user facilities (hereinafter referred to as "user facilities"). User facilities may include multifamily housing (eg, apartment buildings, retirement homes), single-family homes, office buildings, event complexes (eg, multipurpose sports halls or pavilions, hotels, sports complexes), shopping centers , or any other type of building or area to which energy is distributed.

The energy distributed to user installations is typically generated in a power plant. A power plant is any type of facility that generates energy by converting mechanical energy from a generator into electrical energy. The energy to operate the generator can be derived from a number of different types of energy sources, including fossil fuels (for example, coal, oil, natural gas), nuclear, solar, wind, wave or hydroelectric. In addition, the power plant typically generates alternating current (AC) power.

The AC power generated in the power plant typically increases (the voltage is "intensified") and transmits through transmission lines typically to one or more transmission substations. The transmission substations are interconnected with a plurality of distribution substations to which the transmission substations transmit the AC power. The distribution substations typically decrease the voltage of the received AC power (the voltage is "reduced") and transmit the reduced voltage AC power to the distribution transformers that are electrically connected to a plurality of user facilities. In this way, the reduced voltage AC power is distributed to a plurality of user facilities. Such a network or network of interconnected energy components, transmission lines, and distribution lines is often referred to as an electrical network.

Through the electrical network, measurable energy is generated, transmitted and distributed. In this respect, at particular midpoints or destination points through the network, measurements of received and / or distributed energy may indicate the information related to the electrical network. For example, if the distributed energy at the destination points in the network is considerably less than the energy received for example in the distribution transformers, then there may be a system problem that prevents the distribution of energy or the energy may be diverted for malice. Such collection of Energy data in any of the points described in the electrical network and analysis of such data can additionally help the providers to generate, transmit and distribute energy to user facilities.

BRIEF DESCRIPTION OF THE DRAWINGS The present description can be better understood with reference to the following drawings. The elements of the drawings are not necessarily to scale with respect to each other, emphasis in fact is put to clearly illustrate the principles of the description. In addition, similar reference numbers designate corresponding parts through the various views.

FIGURE 1 is a diagram representing an exemplary energy transmission and distribution system according to one embodiment of the present disclosure.

FIGURE 2A is a diagram representing a transformer and meter energy usage data collection system according to an embodiment of the present disclosure.

FIGURE 2B is a diagram representing a line energy usage data collection system according to one embodiment of the present disclosure.

FIGURE 3 is a drawing of a general purpose transformer monitoring device, as represented by FIGURE 2A.

FIGURE 4 is a block diagram representing an exemplary operations computing device, as depicted in FIGURE 2A.

FIGURE 5 is a block diagram depicting an exemplary transformer monitoring device, as depicted in FIGURE 2A.

FIGURE 6 is a drawing of a transformer cylinder according to one embodiment of the present disclosure.

FIGURE 7 is a drawing showing a satellite unit of the transformer monitoring device shown in FIGURE 3 which is installed in the transformer cylinder shown in FIGURE 6.

FIGURE 8 is a drawing showing the satellite unit of the transformer monitoring device shown in FIGURE 3 installed in the transformer cylinder shown in FIGURE 6.

FIGURE 9 is a drawing showing a main unit of the transformer monitoring device shown in FIGURE 3 installed in the transformer cylinder shown in FIGURE 6.

FIGURE 10 is a drawing showing a main unit of the transformer monitoring device shown in FIGURE 8 installed in the transformer cylinder shown in FIGURE 6.

FIGURE 11 is a diagram representing a method for monitoring energy according to the system as depicted in FIGURE 1 for a star transformer configuration.

FIGURE 12 is a diagram representing a method for monitoring energy according to the system as depicted in FIGURE 1 for a delta transformer configuration.

FIGURE 13 is a diagram representing a method for monitoring energy according to the system as shown in FIGURE 1 for an open delta transformer configuration.

FIGURE 14 is a flow chart depicting exemplary architecture and functionality of the power transmission and distribution system as depicted in FIGURE 1.

FIGURE 1 is a block diagram illustrating a power transmission and distribution system 100 for distributing electrical power to one or more user installations 106-111. One or more user installations 106-111 may be commercial user facilities, user residential facilities, or any other type of user installation. A user installation is any structure or area to which energy is distributed.

The transmission and distribution system 100 of The energy comprises at least one transmission network 118, at least one distribution network 119, and the user facilities 106-111 (described hereinafter) interconnected by a plurality of power lines 101a-101j.

In this regard, the power transmission and distribution system 100 is an electrical "network" for distributing electricity generated by an electric power plant 10 to one or more user facilities 106-111 via the transmission network 118 and the distribution network 119. .

Note that power lines 101a and 101b are exemplary transmission lines, while power lines 101c, 10d are exemplary distribution lines. In one embodiment, the transmission lines 101a and 101b transmit high voltage electricity (H OkV or more) and often by overhead power lines. In distribution transformers, the AC power is transmitted over the distribution lines at lower voltage (for example, 25kV or less). Note that in such a mode, the described power transmission uses three-phase alternating current (AC). However, other types of energy and / or energy transmission can be used in other modalities.

The transmission network 118 comprises one or more transmission substations 102 (only one is shown for simplicity). The power station 10 is electrically coupled to the transmission substation 102 via the lines 101a of energy, and the transmission substation 102 is electrically connected to the distribution network 119 via the power lines 101b. As described in the above, the power station 10 (transformers not shown located in the power station 10) increases the voltage of the energy generated before the transmission on the transmission lines 101 a to the transmission substation 102. Note that three wires forming the energy lines 101a are shown indicating that the energy transmitted to the transmission substation 102 is three-phase AC power. However, other types of energy can be transmitted in other modes.

In this respect, in the electrical power station 10, electricity is generated, and the voltage level of the electricity generated is "intensified", that is, the voltage of the energy generated is increased at high voltage (for example, 110 kV or more). ,), to decrease the amount of losses that may occur during the transmission of the electricity generated through the transmission network 118.

Note that the transmission network 118 shown in FIGURE 1 comprises only two sets of transmission lines 101a and 101b (three lines each for three-phase power transmissions as indicated above) and a transmission substation 102. The configuration in FIGURE 1 is only an exemplary configuration. The transmission network 118 may comprise additional transmission substations interconnected by a plurality of additional transmission lines. The configuration of the transmission network 118 may depend on the distance that the increased voltage electricity may need while traveling to reach the desired distribution network 119.

The distribution network 119 transmits electricity from the transmission network 118 to the user facilities 106-111. In this regard, the distribution network 119 comprises a distribution substation transformer 103 and one or more distribution transformers 104 and 121. Note that the configuration shown in FIGURE 1 comprising the distribution substation transformer 103 and two distribution transformers 104 and 121 and showing the distribution substation transformer 103 physically separated from the two distribution transformers 104 and 121 in a configuration copy. Other configurations are possible in other modalities.

As an example, the distribution substation transformer 103 and the distribution transformer 104 can be housed or combined together in other configurations of the distribution network 119 (as well as the distribution substation transformer 103 and the distribution transformer 121). In addition, one or more transformers can be used to condition electricity, that is, transform the voltage of electricity, at a level of acceptable voltage for distribution to user facilities 106-111. The distribution substation transformer 103 and the distribution transformer 104 can "reduce", that is, decrease the electricity voltage received from the transmission network 118, before the distribution substation transformer 103 and the transformers 104, 121 of distribution transmit electricity to their intended destinations, for example, user facilities 106-111.

As described above, in operation, the power station 10 is electrically coupled to the transmission substation 102 via the power lines 101a. The power plant 10 generates electricity and transmits to electricity generated by the power lines 101a to the transmission substation 102. Prior to transmission, the power plant 10 increases the electricity voltage so that it can be transmitted over greater distances efficiently without loss affecting the quality of the distributed electricity. As further indicated in the foregoing, the electricity voltage may need to be increased to minimize energy losses since electricity is transmitted on the power lines 101b. The transmission substation 102 forwards the electricity to the distribution substation transformer 103 of the distribution network 119.

When electricity is received, the transformer 103 of the distribution substation decreases the electricity voltage in a range that is useful by the distribution transformers 104, 121. Likewise, the distribution transformers 104, 121 can also decrease the received electricity voltage in a range that is useful by the respective electrical systems (not shown) of the user facilities 106-111.

In one embodiment of the present disclosure, the distribution transformers 104, 121 are electrically coupled to the data collection system 105 of the distribution transformer. The data collection system 105 of the distribution transformer of the present disclosure comprises one or more electrical devices (the number of devices is based on the number of transformers being monitored) (not shown) that measure the operational data by one or more electrical interfaces with the distribution transformers 104, 121. Exemplary operational data includes data related to electricity that is distributed or transmitted from distribution transformers 104, 121, eg, power measurements, energy measurements, voltage measurements, current measurements, etc. In addition, the data collection system 105 of the distribution transformer can collect operational data related to the environment in which the distribution transformers 104, 121, for example, are located. temperature within the distribution transformers 104, 121.

According to one embodiment of the present disclosure, the data collection system 105 of the distribution transformer is electrically interconnected with the power lines 101c, 10d (for example, a set of three power lines, if the power is three-phase) which provide electricity to the distribution transformers 104, 121. In this way, the data collection system 105 of the distribution transformer collects the data, which represents the amount of electricity that is distributed to the distribution transformers 104, 121. In another embodiment, the data collection system 105 of the distribution transformer is electrically interconnected with the power lines 101e-101j (i.e., the power lines that distribute power to the user's facilities 106--111 or any other lines of power from the distribution transformer that transmits energy to the electric network to user facilities 106-111).

In addition, each user installation 106-111 comprises an electrical system (not shown) for distributing electricity received from the distribution transformers 104, 121 to one or more electrical ports (not shown) of the user installation 106-111. Note that the electrical ports can be internal and external ports.

The electrical system of each user installation 106-111 is interconnected with a corresponding user installation electrical meter 112-117, respectively. Each electric 112-117 meter measures the amount of electricity consumed by the electrical system of the user facilities to which they are attached. To charge a user who is responsible for the user's installation, an electric power company (for example, a utility company or a measurement company) retrieves the data indicative of the measurements made by the electrical 112-117 meters and it uses such measurements to determine the dollar amount of the user's bill representative of how much electricity has been consumed in the user installation 106-111. Notably, the readings taken from meters 112-117 reflect the actual amount of energy consumed by the electrical system of the respective user facility. Thus, in one embodiment of the present description, the meters 112-117 store data indicative of the energy consumed by the users.

During the operation, the meters 112-117 can be consulted using any number of methods to retrieve and store data indicative of the amount of energy consumed by the electrical system of the respective user installation of the meter. In this regard, public service personnel can physically go to the facilities 106-111 and read the respective meter 112-117 of the user installation. In such a scenario, the staff can enter the data indicative of the readings in an electronic system, for example, a portable device, a personal computer (PC), or a laptop computer. Periodically, the data entered can be transmitted to the analysis repository. Additionally, the data recovery of the meter can be electronic and automatic. For example, meters 112-117 can be communicatively coupled to a network (not shown), e.g., a wireless network, and periodically meters 112-117 can automatically transmit data to a repository, described herein with reference to FIGURE 2A.

As will be further described herein, meter data (not shown) (ie, data indicative of readings taken by meters 112-117) and transformer data (not shown) (ie, data indicative of readings taken. by the transformer data collection system 105) can be stored, compared, and analyzed to determine if particular events have occurred, for example, whether the electricity that is produced or produced between the distribution transformers 104, 121 and the facilities 106-111 or to determine whether energy usage trends indicate a need or requirement for additional power supply equipment. In this case, with Regarding the theft of analysis, if the amount of electricity received in the distribution transformers 104, 121 is much greater than the cumulative total (or aggregate) of the electricity that is distributed to the user facilities 106-117, then there is a possibility that an offender may be stealing electricity from the public utility that provides the power.

In one embodiment, the power transmission and distribution system 100 further comprises a line data collection system (LDCS) 290. The LDCS 290 collects the line data of transmission lines 101b-101d. The line data are measured energy / electricity indicative data. Such data can be compared, for example, with the meter data (collected in the user facilities 106-111 described further herein) and / or the transformer data (collected in the distribution transformers 104, 121 described further in FIG. present) to determine the electricity losses along the electric grid, the use of electricity, the need for energy, or the energy consumption metrics of the electric network. In one embodiment, the collected data can be used to determine if electricity is stolen or has occurred between a transmission substation and a distribution substation or a distribution substation and a distribution transformer (ie the power transformer). distribution that transmits the energy to the user installation). Note that the LDCS 290 is coupled to the transmission lines 101b, 101c, and lOld, respectively, thereby coupling to the medium voltage (MV) power lines. The LDCS 290 measures and collects operational data, as described above. In one embodiment, the LDCS can transmit operational data, such as, for example, power, energy, voltage, and / or current, related to the lines 101b, 101c, and lOld of MV energy.

FIGURE 2A depicts the data collection system 105 of the transformer according to one embodiment of the present disclosure and a plurality of meter data collection devices 986-991. The transformer data collection system 105 comprises one or more transformer monitoring devices 243, 244 (FIGURE 1). Note that only two transformer monitoring devices 243, 244 are shown in FIGURE 2A but additional transformer monitoring devices can be used in other embodiments, one or a plurality of transformer monitoring devices for each distribution transformer 104, 121 ( FIGURE 1) is monitored, which is described in more detail in this.

Notably, in one embodiment of the present disclosure, the transformer monitoring devices 243, 244 are coupled to the secondary side of the transformer. transformers 104, 121 of distribution, respectively. In this way, the measurements by the transformer monitoring devices 243, 244 are taken, in effect, in the distribution transformers 104, 121 between the distribution transformers 243, 244 and the user installations 106-111 (FIGURE 1) .

Additionally, the transformer monitoring devices 243, 244, the meter data collection devices 986-991, and a transaction calculation device 287 can communicate over a network 280. The network 280 can be any type of network over the network. which devices can transmit data, including, but not limited to, a wireless network, a wide area network, a large area network, or any type of network known in the art or developed in the future.

In another embodiment, the data 935-940 of the meter and the data 240, 241 of the transformer can be transmitted by a direct connection to the operation calculation device 287 or manually transferred to the operations calculation device 287. As an example, the meter data collection devices 986-991 can be connected directly to the operations calculation device 287 via an address connection, such as for example a carrier line TI (TI). Also, meter data 935-940 can be collected by an electronic device portable (not shown) that is then connected to the operations calculation device 287 for the transfer of collected meter data to the operations calculation device 287. In addition, the meter data 935-940 can be collected manually through visual inspection by the public service personnel and provided to the transaction calculation device 287 in a particular format, for example, separate values with comma (CSV).

Note that in other embodiments of the present disclosure, the meter data collection devices 986-991 may be the meters 112-117 (FIGURE 1) themselves, and the meters 112-117 may be equipped with network communication equipment (not shown] and logic (not shown) configured to retrieve readings, store readings, and transmit readings taken by the meters 112-117 to the operations calculation device 287.

The transformer monitoring devices 243, 244 are electrically coupled to the distribution transformers 104, 121, respectively. In one embodiment, the devices 243, 244 are electrically coupled to the distribution transformers 104, 121, respectively, on a secondary side of the distribution transformers 104, 121.

Transformer monitoring devices 243, 244 each comprise one or more sensors (not shown) that are interconnected with one or more power lines (not shown) that connect the distribution transformers 104, 121 to the user facilities 106-111 (FIGURE 1). In this way, one or more sensors of the transformer monitoring devices 243, 244 detect electrical characteristics, for example, voltage and / or current, present in the power lines as energy is distributed to the facilities 106-111 of user through power lines 101e-101f. Periodically, the transformer monitoring devices 243, 244 detect such electrical characteristics, translate such characteristics detected in the transformer data 240, 241 indicative of electrical characteristics, such as for example, energy, and transmit the data 240, 241 of the transformer to the transformer. device 287 for calculating operations through the network 280. Upon reception, the operations calculation device 287 stores the received data 240, 241 of the transformer.

Note that there is a transformer monitoring device depicted for each distribution transformer in the exemplary system, i.e., a transformer monitoring device 243 for monitoring the transformer 104 (FIGURE 1) and the transformer monitoring device 244 for monitoring the transformer. transformer 121 (FIGURE 1). There may be additional transformer monitoring devices to monitor additional transformers in other modalities The meter data collection devices 986-991 are communicatively coupled to the network 280. During the operation, each meter data collection device 986-991 detects electrical characteristics of the electricity, for example, voltage and / or current, which are transmitted by the distribution transformers 104, 121.

Each meter data collection device 986-991 translates the characteristics detected in meter data 935-940, respectively. The data 935-940 of the meter is data indicative of electrical characteristics, such as, for example, energy consumed in addition to specific measurements of voltage and / or current. In addition, each meter data collection device 986-991 transmits the meter data 935-940, respectively, to the operation calculation device 287 via the network 280. Upon receipt, the operation calculation device 287 stores the data 935-940 of the meter received from the meter data collection devices 986-991 indexed (or integrated) with a unique identifier corresponding to the meter data collection device 986-991 that transmits the meter data 935-940.

In one embodiment, each meter data collection device 986-991 may comprise automatic meter reading (ARM) technology, ie, logic (not shown) and / or hardware, or technology of Automatic Metering Infrastructure (AMI), for example, logic (not shown) and / or hardware for collecting and transmitting data to a central repository, (or more central repositories) for example, the 287 operations calculation device.

In such modality, the ARM technology and / or the AMI technology of each device 986-991 collect data indicative of electricity consumption by its energy system of the respective user facility and other diverse diagnostic information. The meter logic of each meter data collection device 986-991 transmits the data to the operation calculation device 287 via network 280, as described above. Note that the implementation of ARM technology can include hardware such as, for example, portable devices, mobile devices and network devices based on telephony platforms (wired and wireless), radio frequency (RF), or power line communications (PLC) .

Upon receipt, the operations calculation device 287 compares the meter data aggregated from those meters corresponding to a single transformer with the data 240, 241 of the transformer received from the transformer that provided the data 240 241 of the transformer.

In this way, assume that the meter data collection devices 986-988 are coupled with the meters 112-114 (FIGURE 1) and transmit the meter data 935-937, respectively, and the distribution transformer 104 is coupled to the meter. 243 transformer monitoring device. In such a scenario, the electricity of the meter of the meters 112-114 provided by the distribution transformer 104 and consumed by the electrical system of the respective user installation 106-108. Therefore, the operations calculation device 287 adds (e.g., sums) data contained in the meter data 935-937 (e.g., energy usage recorded by each meter 112-114) and compares the aggregate with the data 240 of the transformer provided by the transformer monitoring device 243.

If the operations calculation device 287 determines that the amount of energy that is distributed to the user facilities 106-108 connected to the distribution transformer 104 is substantially less than the amount of energy that is transmitted to the distribution transformer 104, the device 287 of operations calculation can determine that the theft of energy (or electricity) occurs between the distribution transformer 104 and the user installations 106-108 to which the distribution transformer 104 is connected.

In one embodiment, the operations calculation device 287 can store data indicating electricity theft. In another embodiment, the operations calculation device 287 may be monitored by a user (not shown), and the operations calculation device 287 may initiate a visual or audible warning that energy (or electricity) theft is occurring. This process is described further herein.

In one embodiment, the operation calculation device 287 identifies, stores, and analyzes meter data 935-940 based on a particular unique identifier associated with the meter 112-117 to which the data collection devices 986-991 of the meter are coupled. measurer. In addition, the operation calculation device 287 identifies, stores and analyzes the transformer data 240, 241 based on a unique identifier associated with the distribution transformers 104, 121 transmitting the transformer data 240, 241 to the calculation device 287 of the transformer. operations.

In this manner, in one embodiment, before transmitting the operations calculation device 287, both the meter data collection devices 986-991 and the transformer monitoring devices 243, 244 are integrally filled with a unique identifier (it is say, a unique identifier that identifies the meter data collection device 986-991 and a unique identifier that identifies transformer monitoring device 243, 244). In addition, each meter data collection device 986-991 can be filled with the unique identifier of the transformer 104, 121 to which the meter data collection device 986-991 is connected.

In such an embodiment, when the meter data collection device 986-991 transmits the data 935-940 of the meter to the operation calculation device 287, the operation calculation device 287 can determine which distribution transformer 104 or 121 serves to the individual user facilities 106-111. As an example, during the configuration of a portion of the network (ie, the power transmission and distribution system 100) comprising the distribution transformers 104, 121 and the meters 112-117, the operations calculation device 287 can receiving configuration data from the distribution transformers 104, 121 and the meter data collection devices 986-991 that identify the device from which it was sent and a unique identifier that identifies the component to which the device 986-990 is connected; Meter data collection.

FIGURE 2B represents the line data collection system 290 according to one embodiment of the present disclosure. The line data collection system 290 comprises a plurality of monitoring devices 270-272 line and the operation calculation device 287. Each line monitoring device 270-272 communicates with the operation calculation device 287 via the network 280.

With reference to FIGURE 1, the line monitoring devices 270-272 are electrically coupled to the transmission lines 101b, 101c, and lOld, respectively. In one embodiment, each line monitoring device 270-272 comprises one or more sensors (not shown) that are interconnected with the transmission lines 101b, 101c, and lOld connecting the downstream transmission substation 102 to the substation transformer 103 of distribution or connect transformer 103 of distribution substation downstream to distribution transformers 104, 121.

One or more sensors of the line monitoring devices 270-272 detect electrical characteristics, for example, voltage and / or current, present as current flows through the transmission lines 101b, 101c, and 10d, respectively. Periodically, each line monitoring device 270-272 detects such electrical characteristics, translates the characteristics detected in the line data 273-275, respectively, indicative of such characteristics, and transmits line data 273-275 to the calculation device 287 of operations through the network 280. Upon receipt, the operations calculation device 287 stores the line data 273-275 received from the 270-272 line monitoring devices.

FIGURE 3 depicts one embodiment of a general purpose transformer monitoring device 1000 that can be used as the transformer monitoring devices 243, 244 shown in FIGURE 2A and / or line monitoring devices 270-272 (FIGURE 2B ). The transformer monitoring device 1000 can be installed in conductive cables (not shown) and used to collect data indicative of voltage and / or current of the conductor cables to which they are coupled.

The general purpose transformer monitoring device 1000 comprises a satellite unit 1021 that is electrically coupled to a main unit 1001 via a cable 1011. The general purpose transformer monitoring device 1000 can be used in a number of different methods to collect data of voltage and / or current (ie, data 240, 241 of the transformer (FIGURE 2A) of the distribution transformers 104, 121 (FIGURE 1) and of the energy lines 101b-101j.

To collect the voltage and / or current data, the satellite unit 1021 and / or the main unit 1001 is installed around a conductor cable or connectors of conductive cables (also known as "bushing").

In this regard, the satellite 1021 unit of the purpose transformer monitoring device 1000 generally comprises two sections 1088 and 1089 which are hingedly coupled on the hinge 1040. When installed and are in a closed position (as shown in FIGURE 3), the sections 1088 and 1089 are connected together by a latch 1006 and the The conductor cable runs through an opening 1019 formed by coupling the sections 1088 and 1089.

The satellite unit 1021 further comprises a detection unit housing 1005 that houses a current sensing device (not shown) for detecting the current flowing through the conductor cable around which the sections 1088 and 1089 are installed. In one embodiment, the current sensing device comprises an implementation of one or more coreless current sensors as described in the U.S. Patent. Do not. 7,940,039, which is incorporated herein by reference.

The main unit 1001 comprises sections 1016 and 1017 which are hingedly coupled to the hinge 1015. When installed and are in a closed position (as shown in FIGURE 3), the sections 1016 and 1017 are connected together by a latch 1002 and a lead wire runs through an opening 1020 formed by the coupling of sections 1016 and 1017.

The main unit 1001 comprises a detection unit housing section 1018 that houses a device Current detection (not shown) to detect the current flowing through the conductor wire around which the sections 1016 and 1017 are installed. As described in the above with respect to the satellite unit 1021, the current detection device comprises an implementation of one or more Ragowski coils as described in the U.S. Patent. No. 7,940,039, which is incorporated herein by reference.

Unlike the satellite unit 1021, the main unit section 1017 comprises a section 1012 of extended box type housing. Within the housing section 1012 resides one or more printed circuit boards (PCB) (not shown), semiconductor chips (not shown), and / or other electronics (not shown) for performing operations related to the monitoring device 1000 of general purpose transformer. In one embodiment, the housing section 1012 is a substantially rectangular housing; however, accommodations of different size and different shape can be used in other modalities.

Additionally, the main unit 1001 further comprises one or more cables 1004, 1007. The cables 1004, 1007 may be coupled to a corresponding conductor cable or busbars (not shown) and the grounding or reference voltage conductor (not shown). ), respectively, for the corresponding conductor cable, the which will be described later in the present.

Note that the methods according to one embodiment of the present description use the monitoring device 1000 to collect current and / or voltage data. Also, note that the described monitoring device 1000 is connected in a portable and easy manner and / or is coupled to an electrical conductor and / or transformer poles. Due to the non-invasive method for installing the satellite unit and the main unit around a conductor and connecting the wires 1004, 1007 to the connection points, an operator (or public service personnel) does not need to de-energize a transformer 104, 121 for connection to coupling them. In addition, no drilling (or other invasive technique) of the power line is needed during the implementation to the power grid. In this way, the monitoring device 1000 is easy to install. In this way, the implementation to the electrical network is easy to carry out.

During operation, the satellite unit 1021 and / or the main unit 1001 collect the current indicative data through a conductor cable. The satellite unit 1021 transmits its collected data via cable 1011 to the main unit 1001. Additionally, the cables 1004, 1007 can be used to collect voltage indicative data corresponding to a conductor cable around which the satellite unit is installed. The indicative data of The detected current and voltage corresponding to the conductor can be used to calculate the energy usage.

As indicated in the above, there are a number of different methods that can be employed using the general purpose monitoring device 1000 to collect the current and / or voltage data and calculate the energy usage.

In one embodiment, the general purpose transformer monitoring device 1000 can be used to collect voltage and current data from a three-phase system (if multiple general-purpose transformer monitoring devices 100 are used) or a single-phase system.

With respect to a single-phase system, the single-phase system has two conductor cables and a neutral cable. For example, electricity supplied to a common household in the United States has two conducting wires (or live wires) and a neutral wire. Note that the voltage across the lead wires in such an example is 240 Volts (the total voltage supplied) and the voltage across one of the lead wires and the neutral is 120 Volts. Such an example is typically seen as a single-phase system.

In a three-phase system, typically there are three wires and a neutral wire (sometimes there may not be a neutral wire). In a system, the voltage measured on each lead wire is 120 ° out of phase of the voltage at the other two wires. Multiple 1000 general purpose transformer monitoring devices can obtain current readings from each conductor cable and voltage readings between each of the conductor and neutral wires (or obtain voltage readings between each of the conductor wires). Such readings can then be used to calculate the use of energy.

Note that the main unit 1001 of the general purpose transformer monitoring device 1000 further comprises one or more light emitting diodes (LEDs) 1003. The LEDs may be used by logic (not shown but referred to herein with reference to FIGURE 4, as analytical logic 308) to indicate the status, operations or other functions performed by the general purpose transformer monitoring device 1000.

FIGURE 4 represents an exemplary embodiment of the operation calculation device 287 shown in FIGURE 2A. As shown by FIGURE 4, the operations calculation device 287 comprises analytical logic 308, meter data 390, transformer data 391, line data 392, and configuration data 312 all stored in memory 300.

The analytical logic 308 generally controls the functionality of the operations calculation device 287, as will be described in greater detail after this. Should It should be noted that the analytical logic 308 can be implemented in software, hardware, firmware or any combination thereof. In an exemplary embodiment illustrated in FIGURE 4, the analytical logic 308 is implemented in software and stored in the memory 300.

Note that analytical logic 308, when implemented in software, can be stored and transported in any computer readable medium for use by or in conjunction with an instruction execution apparatus that can search and execute instructions. In the context of this document, a "computer-readable medium" can be any medium that may contain or store a computer program for use by or in conjunction with an instruction execution apparatus.

The exemplary embodiment of the operation calculation device 287 represented by FIGURE 4 comprises at least one conventional processing element 302, such as a digital signal processor (DSP) or a central processing unit (CPU), which communicates and excites to other elements within the operations calculation device 287 via a local interface 301, which may include at least one bus. In addition, the processing element 302 is configured to execute software instructions, such as the analytical logic 308.

An input interface 303, for example, a keyboard, an alphanumeric keyboard, or a mouse, can be used to inputting data from a user of the operations calculation device 287, and an output interface 304, for example, a printer or display screen (e.g., liquid crystal display (LCD)), can be used to produce data to the user. In addition, a network interface 305, such as a modem, allows the operations calculation device 287 to communicate via the network 280 (FIGURE 2A) to other devices in communication with the network 280.

As indicated in the above, the meter data 390, the transformer data 391, the line data 392, and the configuration data 312 are stored in the memory 300. The meter data 390 is data indicative of the measurements of the meter. use of energy and / or other electrical characteristics obtained from each of the meters 112-117 (FIGURE 1). In this respect, the meter data 390 is a representation of aggregates of the meter data 935-940 (FIGURE 2A) received from the meter data collection devices 986-991 (FIGURE 2A).

In one embodiment, the analytical logic 308 receives the data 935-940 from the meter and stores the data 935-940 of the meter (as data 390 from the meter) so that the data 935-940 of the meter can be recovered based on the transformer 104 or 121 (FIGURE 1) to which the corresponding meter 112-117 of the meter data is coupled. Note that the meter data 390 is dynamic and is collected periodically by the meter data collection devices 986-991 of the meters 112-117. For example, the meter data 390 may include, but is not limited to, data indicative of current measurements, voltage measurements, and / or energy calculations over a period of time by the meter 112-117 and / or by the transformer 104 or 121. The analytical logic 308 can use the collected meter data 390 to determine whether the amount of electricity supplied by the corresponding transformer 104 or 121 is substantially equal to the electricity received in the user premises 106-111.

In one embodiment, each input of the meter data 935-940 in the meter data 390 is associated with an identifier (not shown) that identifies the meter 112-117 (FIGURE 1) from which data 935-940 of the data is collected. measurer. Such an identifier can be generated randomly in the meter 112-117 by logic (not shown) executed in the meter 112-117.

In such a scenario, data indicative of the identifier generated by the logic in the meter 112-117 may be communicated, or otherwise transmitted to the transformer monitoring device 243 or 244 to which the meter is coupled. In this way, when the transformer monitoring devices 243, 244 transmit the data 240, 241 of the transformer, each monitoring device 243, 244 Transformer also transmits its unique meter identifier (and / or the unique identifier of the meter that sent the device 243, 244 transformer monitoring to the meter data). Upon receipt, the analytical logic 308 can store the received data 240, 241 of the transformer (such as transformer data 391) and the unique identifier of the transformer monitoring device 243, 244 and / or the unique meter identifier so that Transformer data 391 can be searched in unique identifiers when performing calculations. further, the analytical logic 308 can store the unique identifiers of the transformer monitoring devices 243, 244 that correspond to the unique identifiers of the meters 112-117 of which the corresponding transformer monitoring devices 243, 244 receive the meter data. . In this way, the analytical logic 308 can use the configuration data 312 when performing operations, such as adding particular meter data inputs in the meter data 390 to compare with the transformer data 391.

Transformer data 391 is data indicative of aggregate energy usage measurements, obtained from distribution transformers 104, 121. Such dynamic data are collected periodically. Note that the data 240, 241 of the transformer comprises the data indicative of current measurements, voltage measurements, and / or calculations of energy for a period of time that indicates the amount of aggregate energy provided to user facilities 106-111. Notably, the data 391 of the transformer comprises the data indicative of the aggregate energy that is sent to a "group", that is, two or more user installations are monitored by the transformer monitoring devices 243, 244, although the Transformer data 391 may comprise energy data that is sent to only a user facility that is monitored by the transformer monitoring device.

In one embodiment, during the configuration of a distribution network 119 (FIGURE 1), the analytical logic 308 may receive data identifying the unique identifier for one or more transformers 104, 121. In addition, when transformer monitoring device 243, 244 is installed and electrically coupled to one or more transformers 104, 121, data indicative of the unique identifier of the transformers 104, 121 can be provided to the meters 112-117 and / or to the operation calculation device 287, as described in FIG. previous. The operation calculation device 287 can store the unique identifiers (i.e., the unique identifier for the transformers) in the configuration data 312 so that each meter 112-117 is correlated in the memory with a unique identifier identifying the transformer distribution of which the user facilities 106-111 associated with the meter 112-117 receive the power.

The line data 273-275 is data indicative of energy usage measurements obtained from the line data collection system 290 along transmission lines 101b-lOld in the system 100. Such data is dynamic and is collected periodically . Note that the line data 273-274 comprises the data indicative of current measurements, voltage measurements, and / or energy calculations over a period of time which indicates the amount of aggregate energy provided to the distribution substation transformer 103 and the transformers 104, 121 of distribution. Notably, the line data 392 comprises the data indicative of the aggregate energy that is sent to a "group," that is, one or more transformers 103 of the distribution substation.

During the operation, the analytical logic 308 receives data 935-940 from the meter via the network interface 305 of the network 280 (FIGURE 2) and stores the data 935-940 of the meter as data 390 of the meter in the memory 300. The data 390 of the meter are stored so that they can be recovered correspondingly to the distribution transformer 104, 121 that supplies the user installation 106-111 to which the meter data corresponds. Note that there are several methods that can be used to store such data including using unique identifiers, as described in the foregoing, or configuration data 312, also described in the foregoing.

The analytical logic 308 can perform a variety of functions to further analyze the power transmission and distribution system 100 (FIGURE 1). As an example, and as discussed in the foregoing, the analytical logic 308 can use the collected transformer data 391, the line data 392, and / or the meter data 390 to determine if the theft of electricity is occurring as along transmission lines 101a, 101b or distribution lines 101c-101j. In this respect, the analytical logic 308 can compare the aggregate energy consumed by the group of user facilities (e.g., user installations 106-108 or 109-111) and compares the calculated aggregate with the actual energy supplied by the corresponding distribution transformer 104 or 121. In addition, the analytical logic 308 can compare the energy transmitted to the distribution substation transformer 103 and the aggregate energy received by the distribution transformers 104, 121, or the analytical logic 308 can compare the energy transmitted to the transmission substation 102 and the aggregate energy received by one or more transformers 103 of the distribution substation.

If the comparisons indicate that the theft of If electricity is produced anywhere in the power and distribution system 100, the analytical logic 308 can notify a user of the operations calculation device 287 that a problem may exist. In addition, the analytical logic 308 can signal a location in the power transmission and distribution system 100 where the theft can occur. In this regard, the analytical logic 308 may have a visual or audible alert to the user, which may include a system map 100 and a visual identifier that locates the problem.

As indicated in the above, the analytical logic 308 can perform a variety of operations and analyzes based on the data received. As an example, the analytical logic 308 can perform a capacity contribution analysis of the system. In this regard, the analytical logic 308 can determine when one or more of the user facilities 106-111 have matching peak power usage (and / or requirements). The analytical logic 308 determines, based on these data, priorities associated with the plurality of user installations 106-111, for example which user installations require a particular peak load and at what time. The loads required by the user installations 106-111 can necessarily affect the capacity loads of the system; in this way, the priority can be used to determine which user facilities 106-111 can benefit from the management of demands.

Additionally, the analytical logic 308 may utilize meter data 390 (FIGURE 4), transformer data 391, line data 392, and configuration data 312 (collectively referred to as "transaction calculation device data") to determine the asset load. For example, analyzes can be performed for substation and feeder loading, transformer load, feeder section load, line section load and cable load. Also, the operations calculation device data can be used to produce detailed voltage calculations and system analysis 100 and / or technical loss calculations for the system components 100, and to compare the voltages experienced in each distribution transformer with the minimum / maximum voltage nominal values of the distribution transformer manufacturer and identify such distribution transformers that are operating outside the range of suggested voltages in the cases of energy drop and power rise, and identify the transformer size and duration information of distribution.

In one embodiment, a utility can install load control devices (not shown). In such an embodiment, the analytical logic 308 can use the operations calculation device data to identify one or more locations of load control devices.

FIGURE 5 represents an exemplary embodiment of the transformer monitoring device 1000 depicted in FIGURE 3. As shown by FIGURE 5, the transformer monitoring device 1000 comprises control logic 2003, voltage data 2001, current data 2002 , and 2020 energy data stored in the 2000 memory.

The control logic 2003 controls the functionality of the operation transformer monitoring device 1000, as will be described in greater detail after this. It should be noted that the control logic 2003 can be implemented in software, hardware, firmware or any combination thereof. In an exemplary embodiment illustrated in FIGURE 5, the control logic 2003 is implemented in software and stored in memory 2000.

Note that the control logic 2003, when stored in software, can be stored and transported on any computer readable medium for use by or in conjunction with an instruction execution apparatus that can search and execute instructions. In the context of this document, a "computer-readable medium" can be any medium that may contain or store a computer program for use by or in conjunction with an instruction execution apparatus.

The exemplary embodiment of the transformer monitoring device 1000 represented by FIGURE 5 comprises at least one conventional processing element 2004, such as a digital signal processor (DSP) or a central processing unit (CPU), which communicates and excites other elements within the transformer monitoring device 1000 via a local 2005 interface, which can include at least one bus. In addition, the processing element 2004 is configured to execute software instructions, such as the control logic 2003.

A 2006 entry interface, for example, a keyboard, an alphanumeric keyboard, or a mouse, can be used to enter data from a user of the transformer monitoring device 1000, and a 2007 output interface, for example, a printer or display screen. display (for example, a liquid crystal display (LCD)), can be used to produce data to the user. In addition, a network interface 2008, such as a wireless modem or transceiver, allows the transformer monitoring device 1000 to communicate with the network 280 (FIGURE 2A).

In one embodiment, the transformer monitoring device 1000 further comprises a communication interface 2050. The communication interface 2050 is any type of interface that when accessed, allows the energy data 2020, voltage data 2001, current data 2002, or any other data collected or calculated by the transformer monitoring device 100 to be communicate with another system or device. As an example, the communication interface may be a serial bus interface that allows a device to serially communicate to retrieve the identified data from the transformer monitoring device 1000. As another example, the communication interface 2050 can be a universal serial bus (USB) that allows a device configured for USB communication to retrieve the identified data from the transformer monitoring device 1000. Other communication interfaces 2050 may use other methods and / or devices for communication including radio frequency (RF) communication, cellular communication, power line communication and WiFi communications. The transformer monitoring device 1000 further comprises one or more voltage data collection devices 2009 and one or more current data collection devices 2010. In this regard, with respect to the transformer monitoring device 1000 depicted in FIGURE 3, the transformer monitoring device 1000 comprises the 2009 voltage data collection device which may include the cables 1004, 1007 (FIGURE 3) They detect voltages in the nodes (not shown) in a transformer to which the cables are connected. As will be further described herein, the control logic 2003 receives data via the wires 1004, 1007 indicative of the voltages in the nodes and stores the data as data 2001 of voltage. The control logic 2003 performs operations on and with the voltage data 2001, including periodically transmitting the voltage data 2001 to, for example, the operation calculation device 287 (FIGURE 2A).

Further, with respect to the transformer monitoring device 1000 depicted in FIGURE 3, the transformer monitoring device 1000 comprises current sensors (not shown) contained in the detection unit housing 1005 (FIGURE 3) and section 1018 of detection unit housing (FIGURE 3), which are described in the foregoing. The current sensors detect the current traveling through the conductive cables (or neutral cables) around which the detection unit housings 1005, 1018 are coupled. As will be further described herein, the control logic 2003 receives data indicative of the satellite detection unit 1021 (FIGURE 3) by the cable 1011 and the data indicative of the current of the current sensor of the main unit 1001 contained in the section 1018 of detection unit housing. The control logic 2003 stores the data indicative of the detected currents as the current data 2002. The 2003 control logic performs operations on and with the current 2002 data, including periodically transmitting the voltage data 2001 to, for example, the operations calculation device 287 (FIGURE 2A).

Note that the control logic 2003 can perform calculations with the voltage data 2001 and the current data 2002 before transmitting the voltage data 2001 and the current data 2002 to the operations calculation device 287. In this regard, for example, the control logic 2003 can calculate the energy usage using the 2001 voltage data and the current 2002 data over time and periodically store the resulting values as energy data 2020.

During operations, the control logic 2003 can transmit data to the operations calculation device 287 via the cables by a power line communication (PLC) method. In other embodiments, the control logic 2003 may transmit the data via network 280 (FIGURE 2A) wirelessly or otherwise.

FIGURES 6-10 represent an exemplary practical application, use and operation of the transformer monitoring device 1000 shown in the drawings in FIGURE 3. In this regard, FIGURE 6 is a transformer cylinder 1022, housing a transformer (not shown). shown), mounted on a public service post 1036. One or more cables 1024-1026 convey the current from the transformer cylinder 1022 to a destination (not shown), for example, user facilities 106-111 (FIGURE 1). Cables 1024-1026 are connected to the transformer cylinder at nodes 1064-1066. Each node 1064-1066 comprises a conductive connector (part of which is sometimes referred to as a busbar).

FIGURE 7 represents the satellite unit 1021 of the transformer monitoring device 1000 which is placed in one of the nodes 1064-1066 (FIGURE 6), that is, in an open position. A technician (not shown), for example, an employee of a public utility company (not shown), uncouples the latch 1006 (FIGURE 3), formed by the decoupled sections 1006a and 1006b, and places the sections 1088 and 1089 around a portion of the node 1064-1066 so that the sensor unit (not shown) interconnects with the node and detects a current flowing through the node. FIGURE 8 represents the satellite unit 1021 of the transformer monitoring device 1000 secured around the node 1064-1066 in a closed position.

FIGURE 9 represents the main unit 1001 of the transformer monitoring device 1000 which is placed in one of the nodes 1064-1066, ie, in an open position. The technician decouples latch 1002, formed by uncoupled sections 1002a and 1002b, and places the sections 1016 and 1017 around a portion of the node 1064-1066 so that the sensor unit (not shown) interconnects with the node and detects a current flowing through the node. FIGURE 10 is a drawing of the transformer monitoring device 1000 secured around the node 1064- 1066. FIGURE 10 represents the main unit 1001 of the transformer monitoring device 1000 secured around the node 1064-1066 and in a closed position.

In one embodiment, the cables 1004, 1007 (FIGURE 3) of the main unit 1001 can be connected to one of the nodes 1064-1066 around which the respective satellite unit 1021 is coupled and one of the nodes 1064-1066 around the which the main unit 1001 is coupled. In this regard, as described above, the cable 1004 comprises a plurality of separate and distinct cables. A cable is connected to the node around which the satellite unit 1021 is coupled, and a cable is connected to the node around which the main unit 1001 is coupled.

During operation, the current sensing device contained in the detection unit housings 1005, 1018 (FIGURE 3) detect the current of the respective nodes to which they are coupled. Additionally, the connections made by the cables 1004, 1007 to the nodes and the reference conductor detect the voltage at the respective nodes, ie, the node around which the main unit is coupled and the node around which the unit is coupled satellite.

In one embodiment, the analytical logic 308 receives current data for each node and voltage data of each node based on the current sensors and the link connections. voltage. The analytical logic 308 uses the collected data to calculate the energy over a period of time, whose analytical logic 308 transmits to the operation calculation device 287 (FIGURE 2A). In another embodiment, the analytical logic 308 can transmit the voltage data and the current data directly to the operations calculation device 287 without performing any calculation.

FIGURES 11-13 further illustrate methods that may be employed using the monitoring device 1000 of FIGURE 3 in a system 100 (FIGURE 1). As described in the foregoing, the monitoring device 1000 can be coupled to a lead wire (not shown) or a bushing (not shown) that connects the lead wire to a transformer cylinder 1022 (FIGURE 6). In operation, the transformer monitoring device 1000 obtains a current and voltage reading associated with the lead wire to which it is coupled, as described above, and the main unit 1001 (FIGURE 3) uses the current reading and the voltage reading to calculate the use of energy.

Note for purposes of the foregoing discussion, a transformer monitoring device 1000 (FIGURE 3) comprises two current sensing devices, including one contained in the housing 1005 (FIGURE 3) and one contained in the housing 1018 (FIGURE 3) of the satellite unit 1021 (FIGURE 3) and the main unit 1001 (FIGURE 3), respectively.

FIGURE 11 is a diagram representing a distribution transformer 1200 for distributing three-phase power, which is indicative of a "star" configuration. In this regard, three-phase power comprises three conductors that provide AC power so that the AC voltage waveform in each conductor is 120 ° apart from each other, wherein 360 ° is approximately one-sixtieth of a second . As described above, the three-phase power is transmitted in three conductor wires and distributed to the distribution substation transformer 103 (FIGURE 1) and the distribution transformer 104 (FIGURE 1) in three conductor wires. In this manner, the receiver distribution transformer 104 has three pairs of windings (one for each received phase input voltage) to transform the voltage of the received energy into a voltage level necessary to distribute to the users 106-108 ( FIGURE 1).

In the distribution transformer 1200, three single-phase transformers 1201-1203 are connected to a common 1204 (neutral) conductor wire. For illustration purposes, each transformer connection is identified as a phase, for example, Phase A / transformer 1201, Phase B / transformer 1202, and Phase C / transformer 1203.

In the modality represented in FIGURE 11, three monitoring devices 1000a, 1000b, and 1000c (each configured substantially similarly to the monitoring device 1000 (FIGURE 3)) are used to obtain data (e.g., voltage and current data) used to calculate the power in the transformer 1200 distribution.

In this regard, at least one of the current detecting devices 1217 of the monitoring device 1000a is used to collect the current data for Phase A. Notably, the detecting device 1217 of the monitoring device 1000a used to collect the current data can be housed in the satellite unit 1021 (FIGURE 3) or the main unit 1001 (FIGURE 3). The lead wire 1004a of the monitoring device 1000a is connected through the Phase A and common 1204 lead wire to obtain voltage data. Note that in one embodiment, both current sensing devices in the satellite unit 1021 and the main unit 1001 (current sensing device 1217) can be coupled around the Phase A conductive cable.

In addition, a current detecting device 1218 of the monitoring device 1000b is used to collect current data for Phase B. As described above with reference to Phase A, the monitoring device 1218 of the monitoring device 1000b used to collect current data can be housed in unit 1021 satellite (FIGURE 3) or the main unit 1001 (FIGURE 3). The lead wire 1004b of the monitoring device 1000b is connected through the Phase B and common lead wire 1204 to obtain voltage data. Similar to the implementation of Phase A described above, in one embodiment the current detection device in the satellite unit 1021 and the main unit 1001 (current detection device 1218) can be coupled around the Phase B conductor cable.

Additionally, a current detecting device 1219 of the monitoring device 1000c is used to collect voltage and current data for Phase C. As described above with reference to Phase A, the device 1219 detection device 1000c The monitoring device used to collect the current data can be housed in the satellite unit 1021 (FIGURE 3) or the main unit 1001 (FIGURE 3). The lead wire 1004c of monitoring device 1000c is connected through the Phase C and common 1204 lead wire to obtain voltage data. Similar to the Phase A implementation described above, in one embodiment the current detection devices in the satellite unit 1021 and the main unit 1001 (current detection device 1219) can be coupled around the Phase C conductor cable.

During monitoring, the 2003 control logic (FIGURE 5) The monitoring devices 1000a-1000c use current measurements and voltage measurements to calculate the total energy. As described above, the energy calculated from the measurements made by the transformer monitoring devices 1000a, 1000b, and 1000c can be used in various applications to provide information related to the power transmission and distribution system 100 (FIGURE 1). 1).

FIGURE 12 is a diagram representing a distribution transformer 1300 for distributing three-phase power, which is indicative of a delta configuration. Such a distribution transformer 1300 can be used as the distribution transformer 104 (FIGURE 1). The distribution transformer 1300 (similar to the distribution transformer 1200 (FIGURE 11)) has three single-phase transformers for transforming the voltage of the received energy into three conductor wires (ie, three-phase power) at a voltage level necessary for supply to the users 106-108 (FIGURE 1).

The distribution transformer 1300 comprises three single-phase transformers 1301-1303. For purposes of illustration, each transformer connection is identified as a phase, eg, Phase A / transformer 1301-transformer 1303, Phase B / transformer 1302-transformer 1301, and Phase C / transformer 1303-transformer 1302.

In the embodiment shown in FIGURE 12, two lOOOd and lOOOe transformer monitoring devices are used to obtain voltage and current data, which are used to calculate the energy in the distribution transformer 1300. In this respect, the 100% transformer monitoring device is coupled around one of the three incoming lead wires, identified in FIGURE 12 as Phase B, and the transformer monitoring device is coupled around another of the three lead wires incoming, identified in FIGURE 12 as Phase C. The lOOOd and lOOOe monitoring devices (each configured substantially similar to the monitoring device 1000 (FIGURE 3)) are used to obtain data (eg, voltage and current data) used to calculate the energy in the distribution transformer 1300.

In this regard, a current detecting device 1318 of the monitoring device 100 is used to collect the current data for Phase B. Notably, the detection device 1318 of the monitoring device used to collect current data can be monitored. stay in the satellite 1021 unit (FIGURE 3) or the main unit 1001 (FIGURE 3). The 1004d voltage leads of the monitoring device are connected through the Phase B conducting wire and the Phase A conducting wire that measures a voltage differential. Notice that in one In this embodiment, both current sensing devices in the satellite unit 1021 and the main unit 1001 (current detection device 1318) can be coupled around the Phase B conductive cable. Also, note that in the delta configuration, Phase A can be designated arbitrarily as "common" so that the energy can be calculated in the voltage differentials between the detected current conductor wires and the designated "common", which in the present modality is Phase A.

In addition, similar to the Phase B measurements, a current detection device 1319 of the monitoring device is used to collect the current data for Phase C. As described above with reference to Phase B, the Detection device 1319 of the monitoring device lOOOe used to collect current data can be housed in the satellite unit 1021 (FIG, 3) or the main unit 1001 (FIGURE 3). The voltage lead wires 1004e of the monitoring device 100 are connected through the Phase C conductive cable and the Phase A conductive cable. Notably, in one embodiment, both current detection devices in the satellite unit 1021 and the The main unit 1001 (the current detection device 1319) can be coupled around the Phase C conductor cable.

During the 2003 logic of monitoring control (FIGURE 5) of the lOOOd and lOOOe monitoring devices use current measurements and voltage measurements to calculate the total energy. As described above, the energy calculated from the measurements made by the lOOOf and lOOOg transformer monitoring devices can be used in various applications to provide information related to the power transmission and distribution system 100 (FIGURE 1).

FIGURE 13 is a diagram representing a distribution transformer 1400 for distributing energy, which is indicative of an open delta configuration. The distribution transformer 1400 has two single-phase transformers for transforming the received voltage into a voltage level necessary for distribution to the users 106-108 (FIGURE 1).

The distribution transformer 1400 comprises two single-phase transformers 1401-1402. In the embodiment shown in FIGURE 13, two lOOOf and lOOOg transformer monitoring devices are used to obtain voltage and current data, which are used to calculate the energy in the distribution transformer 1400.

The lOOOf transformer monitoring device is coupled around one of three lead wires identified in FIGURE 13 as Phase A and the transformer monitoring lOOOg device is coupled around another of the lead wires identified in FIGURE 13 as Phase B. The lOOOf and lOOOg monitoring devices (each substantially configured similar to the monitoring device 1000 (FIGURE 3)) are used to obtain data (e.g., voltage and current data) used to calculate the energy in the monitor. 1400 distribution transformer.

In this regard, at least one of the current detection devices 1418 or 1419 of the monitoring device 100OO is used to collect voltage and current data for Phase A. Although both detection devices are shown coupled around Phase A, both are not necessarily needed in other modalities. Notably, a detection device for the monitoring device 100 used to collect current data may be housed in the satellite unit 1021 (FIGURE 3) or the main unit 1001 (FIGURE 3). The 1004f voltage leads of the monitoring device 100OO are connected through the Phase A conducting wire and grounded. Note that in one embodiment both current sensing devices in the satellite unit 1021 and the main unit 1001 can be coupled around the Phase A conductive cable, as shown.

In addition, the current sensing device 1420 housed in the main unit 1001 (FIGURE 3) of the monitoring device 100OOg the detection device 1421 current housed in the satellite 1021 unit (FIGURE 3) of the lOOOg monitoring device is used to collect current data for Phase B. The 1004g voltage leads of the lOOOg monitoring device are connected through the voltage output of the transformer 1402 secondary.

During monitoring, the 2003 control logic (FIGURE 5) of the lOOOf and lOOOg transformer monitoring devices uses current measurements and voltage measurements to calculate the total energy. As described above, the calculated energy of the measurements made by the lOOOf and lOOOg transformer monitoring devices can be used in various applications to provide the information related to the power transmission and distribution system 100 (FIGURE 1).

FIGURE 14 is a flowchart representing exemplary architecture and functionality of the system 100 depicted in FIGURE 1.

In step 1500, electrically interconnecting a first transformer monitoring device 1000 (FIGURE 3) to a first electrical conductor of a transformer at a first location in an electrical network, and in step 1501, measuring a first current through the first electrical conductor and a first voltage associated with the first electrical conductor.

In step 1502, electrically interconnect a second transformer monitoring device 1000 with a second electrical conductor electrically connected to the transformer, and in step 1503 measuring a second current through the second electrical conductor and a second voltage associated with the second electrical conductor.

Finally, in step 1504, calculate values indicative of energy corresponding to the transformer based on the first current and the first voltage and the second current and the second voltage.

Claims (12)

CLAIMING

1. A system for monitoring energy, characterized in that it comprises: A first transformer monitoring device configured to interconnect with a first electric conductor electrically connected to a transformer in a first location in an electrical network and measure a first current through the first electric conductor, the transformer monitoring device is further configured to measuring a first voltage associated with the first electrical conductor; a second transformer monitoring device configured to interconnect with a second electrical conductor electrically connected to the transformer at the first location in the electrical network and measure a second current through the second electrical conductor, the transformer monitoring device is also configured to measure a second voltage associated with the second electrical conductor; logic configured to calculate values indicative of energy corresponding to the transformer based on the first current and the first voltage and the second current and the second voltage.

2. The system for monitoring energy according to claim 1, characterized in that the first and second transformer monitoring devices comprise a communication interface for interconnecting with a device for recovering data indicative of the energy value, the first current, the first voltage, the second current, or the second voltage.

3. The system for monitoring energy according to claim 1, characterized in that the transformer is a star configuration transformer.

4. The system for monitoring energy according to claim 1, further characterized in that it comprises a third transformer monitoring device configured to interconnect with a third electrical conductor electrically connected to the transformer and to measure a third current through the third electrical conductor, the device Transformer monitoring is also configured to measure a third voltage associated with the third electrical conductor.

5. The system for monitoring energy according to claim 4, characterized in that the transformer is a delta configuration transformer.

6. The system for monitoring energy according to claim 4, characterized in that the transformer is an open delta configuration transformer.

7. A method for monitoring energy, characterized in that it comprises: electrically interconnecting a first transformer monitoring device to a first electrical conductor of a transformer in a first location in an electrical network; measuring a first current through the first electrical conductor and a first voltage associated with the first electrical conductor; electrically interconnecting a second transformer monitoring device with a second electrical conductor electrically connected to the transformer; measuring a second current through the second electrical conductor and a second voltage associated with the second electrical conductor; calculate values indicative of energy corresponding to the transformer based on the first current and the first voltage and the second current and the second voltage.

8. The method for monitoring energy according to claim 7, further characterized in that it comprises: communicatively interconnecting a data recovery device to the first and second transformer monitoring devices; Y recover data indicative of the energy values, the first current, the first voltage, the second current, or the second voltage.

9. The method for monitoring energy according to claim 7, characterized in that the transformer is a delta configuration transformer.

10. The method for monitoring energy according to claim 7, further characterized in that it comprises: electrically interconnecting a third transformer monitoring device with a third transformer electric conductor; Y measuring a third current through the third electrical conductor and a third voltage associated with the third electrical conductor.

11. The method for monitoring energy according to claim 10, characterized in that the transformer is a star configuration transformer.

12. The method for monitoring energy according to claim 10, characterized in that the transformer is an open delta configuration transformer.