Locating electrical faults in power distribution networks

Abstract

Systems and methods for improved power notification messages are disclosed. One disclosed system for improved malfunction notification messages includes a meter including metering, a processor, and a communications module. The metering measures a voltage associated with the grid and determines that a malfunction event has occurred based on detecting an out-of-range voltage associated with the grid for a predetermined number of cycles or a predetermined period of time. The processor determines a disturbance magnitude value associated with the malfunction event from the waveform data. The communications module communicates the malfunction notification message and the disturbance magnitude to a central system, where the disturbance magnitude value is a value representative of a probability that a fault causing the malfunction is located in an area of ​​the grid.

Description

[Technical field]

[0001] The present disclosure relates generally to an improved power outage notification messaging scheme that may be used to determine the location of a fault in an electrical grid. [Background technology]

[0002] An electric power grid is made up of many interconnected devices across a large geographic area. The interconnected devices are generally used to monitor and distribute power to user premises and may include power assets such as transformers, protection devices such as switches, line sections, and meters associated with the user premises. Devices such as meters and other sensors are distributed throughout the electric power grid to measure consumption and monitor characteristics of the grid such as voltage, current, and power. The meters and sensors report the characteristics of the grid to a central system. Summary of the Invention [Problem to be solved by the invention]

[0003] The central system and the meter typically communicate in a scheduled manner or in response to the occurrence of an event, such as a malfunction. If a meter detects a malfunction event, it notifies the central system by logging the event or by sending a malfunction notification message. However, the malfunction notification message lacks detailed information regarding the location of the fault that caused the malfunction. Due to the complex nature of the power grid, the first meter to detect a malfunction is not always the meter closest to the fault that caused the malfunction. Thus, there is a need for an improved malfunction notification message scheme that indicates the location of the fault that caused the malfunction. [Means for solving the problem]

[0004] The present disclosure includes a meter that may be connected to an electrical grid, the meter including instrumentation for measuring waveform data associated with the electrical grid, a communication component such as a communication module for communicating with a central system, and a processing unit for determining that a failure has occurred, generating a power failure notification message, and determining a disturbance magnitude value, also referred to as a distance to fault value.

[0005] In one embodiment, the meter determines whether an event has occurred, such as a momentary malfunction, a persistent malfunction, or other event, and the meter adjusts operation based on the event. For example, if the event is a momentary malfunction, the meter may store the disturbance magnitude value in memory and wait to transmit information regarding the malfunction and the disturbance magnitude value until the meter is interrogated or the meter transmits a scheduled communication.

[0006] In other examples, such as when a sustained malfunction occurs, the meter may transmit a malfunction notification message and a disturbance magnitude value to the central system without being interrogated by the central system. For example, the meter may include preset instructions to transmit a malfunction notification message and a disturbance magnitude value after the meter detects a voltage associated with the grid outside a predetermined range for a predetermined period of time.

[0007] These examples are mentioned not to limit or define the scope of the present subject matter, but to provide examples to aid in its understanding. Exemplary examples are described in the detailed description, and further explanation is provided therein. Advantages offered by various embodiments may be further understood by studying this specification and / or by practicing one or more embodiments of the claimed subject matter. [Brief description of the drawings]

[0008] [Figure 1]4 is a flow chart illustrating an example method of operating a meter that transmits a malfunction notification message. [Diagram 2] 4 is a flow chart illustrating an exemplary method of operation of a meter during a momentary malfunction. [Diagram 3] 4 illustrates the operation of an exemplary meter during a sustained malfunction. [Figure 4] 4 illustrates the operation of an exemplary meter during a momentary malfunction. [Diagram 5] 4 is a flow chart illustrating an exemplary method of operating a meter that stores disturbance magnitude values ​​in a memory. [Figure 6] FIG. 2 is a block diagram illustrating components of an exemplary meter. [Figure 7] FIG. 1 is a block diagram illustrating a portion of an example electrical grid. [Figure 8] FIG. 1 is a block diagram illustrating an example communication network for an electrical grid. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0009] These and other features, aspects, and advantages of the present disclosure will be better understood when the following detailed description is read in conjunction with the accompanying drawings.

[0010] Aspects of the present disclosure relate to a system for transmitting improved malfunction information. An malfunction notification message indicates that a malfunction has occurred in the electrical grid and is generated at a meter if the meter detects a malfunction. The meter determines that a malfunction has occurred when a characteristic of the electrical grid measured by the meter, such as voltage or current, is outside a predetermined range of values ​​for a predetermined period of time.

[0011] Momentary and persistent faults differ from one another based on the length of time the fault lasts for the meter to determine whether the fault is momentary or persistent, which may be determined by the utility provider and regulatory bodies and may be preset in the meter.

[0012] The behavior of the meter may vary based on whether the malfunction is persistent or momentary. If the meter determines that the malfunction is persistent, the meter may transmit a malfunction notification message including a disturbance magnitude value to a central system or other remote system. The malfunction notification message alerts the central system about the malfunction, and the disturbance magnitude value provides probabilistic information about whether the location of the cause of the malfunction is closest to the meter that transmitted the disturbance magnitude value.

[0013] If the meter determines that the malfunction is momentary, the meter may store the disturbance magnitude value in a memory, such as a buffer, and await transmission of the disturbance magnitude value.

[0014] The disturbance magnitude value is determined by the meter from waveform data collected by the meter before and after the time of the power outage. The disturbance magnitude value indicates the distance of the meter to the fault compared to other meters. For example, if the fault corresponds to a downed line, a meter connected to the downed line may determine a disturbance magnitude value that indicates the meter is closer to the fault than a disturbance magnitude value determined by a meter connected to a different line.

[0015] A larger or more extreme disturbance in the waveform data indicates that the meter is closer to a fault than another meter with a smaller or more damped disturbance. A disturbance includes a variation or deviation from a nominal operating condition that indicates a potential fault. In one embodiment, the disturbance magnitude value is represented by a value between 0 and 1, where a higher value indicates that the meter is closer to a fault than a lower value. Exemplary disturbance magnitude values ​​may be based on voltage characteristics, such as the voltage crossing a voltage threshold and the change in voltage over time, including how quickly the voltage decays, spikes in the voltage, or other changes in the voltage. For example, unplanned outages may have irregular patterns of voltage decay and recovery, as faults caused by tree branches, animals, or other factors may be intermittent and may occur before a stable fault current triggers the opening of a grid switch. In one embodiment, the disturbance magnitude value may be calculated using an RMS average of each line cycle incremented by half a period. If this value falls below a threshold which triggers calculation of a disturbance magnitude value, subsequent values ​​after the initial voltage decay may be evaluated. RMS values ​​higher than a second threshold may be summed over up to a fixed number of half cycle periods to determine a disturbance magnitude value for the meter. Then, if a persistent malfunction occurs, disturbance magnitude values ​​for additional meters may be determined to estimate which meters may be closest to the fault. In other embodiments, a transient calculation may be used to evaluate each sample in the waveform against a threshold in terms of its absolute value.

[0016] Because an outage tends to affect multiple devices and locations, the central system may receive multiple outage notification messages and disturbance magnitude values. When the central system receives the disturbance magnitude values, it determines the area in which the outage is located. The central system uses the disturbance magnitude values ​​and maintains topology and geographic information of the power grid to determine the likely location of the fault.

[0017] Exemplary Methods of Operation Figures 1, 2, and 5 are flow charts illustrating example methods of meter operation. In some embodiments, some of the steps in the flow charts of Figures 1, 2, and 5 are implemented as program code executed by a processor of the meter. In some embodiments, the steps shown in Figures 1, 2, and 5 may be performed in a different order, or one or more steps may be skipped. Alternatively, in some embodiments, additional steps not shown in Figures 1, 2, and 5 may be performed.

[0018] 1, 2, and 5 each show a meter collecting waveform data from the grid. The waveform data may include voltage waveform data, current waveform data, or other types or combinations of waveform data. The waveform data may relate to a single phase or multiple phases of the grid. The meter may buffer the waveform data so that it is available for analysis, including calculation of disturbance magnitude values. In one embodiment, the meter buffers approximately 30 cycles of waveform data. For simplicity, voltage waveform data and voltage are used in this embodiment.

[0019] Exemplary Methods of Operation of a Meter During a Persistent Malfunction 1 is a flow chart illustrating an exemplary method of operation of a meter for transmitting a malfunction notification message. The method begins at step 100, where the meter collects waveform data including voltage associated with the electrical grid.

[0020] The meter detects an out-of-range voltage at an interface connected to the grid for a predetermined number of cycles, step 101, and the meter determines that a malfunction event has begun based on the out-of-range voltage, step 102. In other embodiments, the meter may determine that a malfunction event has occurred based on the out-of-range voltage for a predetermined period of time.

[0021] If the meter determines that a malfunction event has begun, the meter determines a disturbance magnitude value based on the waveform data collected by the meter and transmits the disturbance magnitude value to the meter's communications module (step 103).

[0022] The meter may continue to operate for a short period of time after the malfunction event begins, but then transitions to low power mode (step 104). When in low power mode, the meter operates in a state to reduce power consumption. While in low power mode, the meter may stop powering components and stop operating background functions. While in low power mode, the meter may also reduce its refresh rate and disable the meter's interface.

[0023] If the voltage detected by the meter is outside the predetermined voltage range for a predetermined period of time after the initiation of the malfunction event, the meter determines that a persistent malfunction has occurred, step 105. A utility provider or regulatory body may set a predetermined voltage range and a predetermined time period for the out-of-range voltage to determine whether an event is a persistent malfunction.

[0024] In response to determining that a sustained malfunction has occurred, the meter generates a malfunction notification message (step 106). The disturbance magnitude value sent to the communications module in step 103 and the malfunction notification message are then sent to the central system (step 107). The meter may send the malfunction notification message and the disturbance magnitude value separately, sequentially, or simultaneously. In other embodiments, the malfunction notification message includes the disturbance magnitude value as part of the malfunction notification message.

[0025] Exemplary Methods of Operation of a Meter During a Momentary Malfunction FIG. 2 is a flow chart illustrating an exemplary method of operation of a meter during a momentary malfunction.

[0026] The method begins at step 200, where the meter collects waveform data including a voltage associated with an electrical grid. The meter detects an out-of-range voltage at an interface connected to the electrical grid for a predetermined number of cycles (step 201), and based on the detected out-of-range voltage continuing for the predetermined number of cycles or a predetermined period of time, the meter determines whether a malfunction event has begun (step 202). The predetermined number of cycles and the predetermined period of time may be adjustable by the utility provider or a regulatory body.

[0027] The meter may continue to operate for a short period of time after the malfunction event begins, during which it determines a disturbance magnitude value. The meter transmits the disturbance magnitude value to a communications module associated with the meter (step 203). At some point after transmitting the disturbance magnitude value to the communications module, the meter begins to operate in a low power mode (step 204). While in the low power mode, the meter reduces power consumption to extend the length of time the meter may operate without being powered by the power grid. For example, the meter may reduce background processing, stop powering components, or place other components, such as the communications module, in an idle mode.

[0028] When the malfunction event ends, i.e., the voltage returns to an acceptable voltage range for a predetermined period of time or number of cycles, the meter determines that the malfunction event was an instantaneous malfunction (step 205). The meter may store a disturbance magnitude value in memory, which may be associated with the instantaneous malfunction event and may further be associated with additional information about the instantaneous malfunction event (step 206). The disturbance magnitude value may be stored in a buffer or other storage device.

[0029] The central system may query the meter for information regarding the instantaneous malfunction event, including the disturbance magnitude value, or the meter may include the disturbance magnitude value in a scheduled communication to the central system.

[0030] Exemplary Behavior of a Meter During a Persistent Malfunction Figure 3 illustrates an exemplary operation of a meter during a sustained malfunction event. A graph 300 represents the voltage at the meter's interface connected to the grid over time. Below the graph is a block diagram showing the operation of the meter over the same time period. On the left side of Figure 3, during normal operating mode 301, the voltage is within normal operating range and the meter operates normally.

[0031] Graph 300 also shows a voltage spike representative of a fault, followed by a sustained malfunction event, occurring at 302. The fault occurring at 302 may be caused by a downed power line, a destroyed transformer, or other occurrence that results in a malfunction.

[0032] In some examples, graph 300 may not include an identifiable fault occurring at 302. The voltage at the meter may decay or drop over a period of time until the voltage falls outside a predetermined range without first spiking. For example, a meter located further away from the fault may only detect a voltage decay without detecting a voltage spike. In another example, where a power asset degrades over time resulting in a less efficient power asset, a meter monitoring the power asset or premises associated with the power asset may detect a decay in voltage over a longer period of time.

[0033] While in normal operating mode 301, the meter performs normal operations. The meter continues to perform normal operations until it detects an out-of-range voltage at 303. At the beginning of time period 303, the meter detects a voltage indicative of a power malfunction, for example, a voltage having an amplitude less than 80% of the nominal required amplitude. The meter monitors the voltage for a predetermined length of time (e.g., two cycles), shown in FIG. 3 as trigger 304. If the voltage remains out-of-range for a predetermined period of time, representing trigger 304, the meter determines that a malfunction has begun, shown at 305. The length of time for trigger 304 may also be based on a predetermined number of cycles of the voltage monitored by the meter and a predetermined number of out-of-range maxima or minima.

[0034] The meter determines a disturbance magnitude value during T1 306 using waveform data collected by the meter prior to the start of the malfunction event and up until the time the meter calculates the disturbance magnitude value. During T1 306, the meter continues to operate, prepares to operate in low power mode 308, and transmits the disturbance magnitude value to the communications module. The length of time T1 306 may be fixed or variable. In some embodiments, the time T1 306 may cover 10-100 line cycles. In other embodiments, the disturbance magnitude value may be calculated using 10 line cycles before T1 306 in addition to 30 line cycles of data after T1 306 for calculating the disturbance magnitude value. The meter may prepare to transition to the low power mode by operating the communications module in an idle mode, powering down components such as WiFi-related components, shutting down volatile memory, stopping background functions, and other actions that reduce the power consumption of the meter.

[0035] At 307, the meter transitions to operate in a low power mode 308. If the malfunction persists until 309, the meter determines that the malfunction is a persistent malfunction and transmits a malfunction notification message and a disturbance magnitude value to the central system. The meter may power down at 309 after transmitting the malfunction notification message and the disturbance magnitude value.

[0036] The length of time that the meter continues to operate after the onset of a malfunction event may be based on the technical specifications of the meter, such as the battery capacity, the power consumption of the meter in normal operating mode and low power mode, and other technical specifications of the meter. In one embodiment, the meter may operate for about 2 seconds after the onset of a malfunction event before shutting off power at 309. In this embodiment, T1 is about 200 milliseconds and the time in low power mode is about 1800 milliseconds. In another embodiment, the meter may operate for about 30 seconds after the onset of a malfunction event. In such an embodiment, T1 306 may be 500 milliseconds and the low power mode 308 may last for 30 seconds.

[0037] Example behavior of a meter during a momentary malfunction Figure 4 illustrates the operation of a meter during a momentary malfunction event. Graph 400 represents the voltage at the meter's interface connected to the grid over time. Below the graph is a block diagram showing the operation of the meter over the same time period. On the left side of Figure 4, during normal operating mode 410, the voltage is within normal operating range and the meter operates normally. Graph 400 further illustrates a fault occurring at 402 followed by a subsequent momentary malfunction.

[0038] The meter continues to operate normally in normal operating mode 401 until 403. At the beginning of time period 403, the meter detects a voltage indicative of a power malfunction, for example a voltage having an amplitude less than 80% of the required nominal amplitude or voltage out of a predetermined voltage range. The meter monitors the voltage for a predetermined length of time, shown in FIG. 4 as trigger 404, and if the voltage remains outside the predetermined voltage range, the meter determines that a malfunction event began at time 405.

[0039] During time period T1 406, the meter determines a disturbance magnitude value, transmits the disturbance magnitude value to the communications module, and prepares the meter for low power mode 408. The meter may prepare to transition to low power mode 408 by operating the communications module in an idle mode, removing power from components such as WiFi-related components, shutting down volatile memory, stopping background functions, and other actions that reduce the power consumption of the meter.

[0040] At 407, the meter transitions to a low power mode 408 where it remains until the meter detects that the malfunction event has ended, e.g., the meter detects an in-range voltage for a predetermined period of time or number of cycles. Once the meter detects that the malfunction event has ended at 409, the meter transitions to a normal operating mode 410.

[0041] In Figure 4, because power is restored to the meter before the meter determines that the malfunction was a sustained malfunction, the meter determines that the malfunction was a momentary malfunction event. In some embodiments, after the meter determines that the malfunction was a momentary malfunction event, the meter stores the disturbance magnitude value that was previously transmitted to the communications module during T1. The disturbance magnitude value may be stored with other information related to the momentary malfunction event, as described above with respect to Figure 2.

[0042] The meter may receive a message from the central system indicating that maintenance is to be performed on the grid at a scheduled time, in such an embodiment, the meter may decide not to send a malfunction notification message or determine a disturbance magnitude value during the scheduled maintenance.

[0043] In further examples, the meter may also be configured to calculate impedance or other characteristics associated with the grid. Using the calculated impedance and other characteristics, the meter may determine if the voltage is likely to be out of range due to a loading problem, such as a higher than expected load from a consumer, and may decide not to send a malfunction message or determine a disturbance magnitude value for the loading problem.

[0044] Exemplary Method for Storing Disturbance Magnitude Values Instead of determining the disturbance magnitude value after a malfunction event begins, the meter may calculate the disturbance magnitude value as the waveform data is collected and store the disturbance magnitude value. The meter may be configured to maintain a predetermined number of the most recent disturbance magnitude values.

[0045] 5 is a flow chart illustrating an example method of operating a meter that stores disturbance magnitude values ​​and uses the stored disturbance magnitude values ​​in reporting sustained malfunction events. The method begins at step 500, where the meter collects waveform data, such as voltage, associated with an electrical grid.

[0046] The meter then determines a disturbance magnitude value based on the collected waveform data (step 501). After calculating the disturbance magnitude value, the meter stores the disturbance magnitude value in memory (step 502).

[0047] The method continues at step 503 where the meter determines whether the meter has detected an out-of-range voltage for a predetermined number of cycles or a predetermined period of time.

[0048] If the voltage is not out of range, the method returns to step 500. If the voltage is out of range, the meter detects the start of a malfunction event. Although Figure 5 shows step 503 following steps 500-502, step 503 may be performed in parallel with steps 500-502.

[0049] After the meter detects the onset of the malfunction event, the meter transmits the stored disturbance magnitude value to the communications module, step 504. If the meter stores multiple disturbance magnitude values, the meter selects the disturbance magnitude value associated with the time period prior to the time identified by the meter as the onset of the malfunction event.

[0050] The meter then operates in a low power mode (step 505), where the meter operates in a state to reduce power consumption. While in the low power mode, the meter may reduce power consumption by turning off power to components and stopping active background functions. While in the low power mode, the meter may also reduce its refresh rate and disable the meter's interface.

[0051] If the voltage detected by the meter remains outside the predetermined voltage range for a predetermined period of time or number of cycles, the meter determines that a sustained malfunction event has occurred (step 506), and in response to determining that a sustained malfunction event has occurred, the meter generates a malfunction notification message (step 507).

[0052] The disturbance magnitude value sent to the communication module in step 504 and the malfunction notification message are then transmitted to the central system (step 508). The meter may transmit the malfunction notification message and the disturbance magnitude value separately, sequentially, or simultaneously. In other embodiments, the malfunction notification message includes the disturbance magnitude value as part of the malfunction notification message.

[0053] In one embodiment, the meter may calculate the disturbance magnitude value after six line cycles. The meter may store the four most recent disturbance magnitude values ​​in a circular buffer that is updated after six line cycles. In such an embodiment, the meter may also include a malfunction detection algorithm that determines that a malfunction has occurred after ten consecutive line cycles in which there are no measurements above the malfunction threshold. If the meter determines that a malfunction has occurred, the meter may transmit a disturbance magnitude value associated with a time window that includes the last line cycle in which a measurement above the malfunction threshold occurred. The meter may find the disturbance magnitude value associated with the line cycle in which a measurement above the malfunction threshold occurred by comparing the start time of the malfunction against the times of other disturbance magnitude values.

[0054] Example Meter The above describes that the meter performs various functions including metering, processing, and communication functions. In some embodiments, these functions may be performed by different components. FIG. 6 shows a meter 600 including a metering component 601, a processing unit 602, and a communication module 603. The processing unit 602 may be configured to execute one or more metering application programs that provide advanced functions including calculation of disturbance magnitude values. It is also referred to herein as an edge intelligence computer (EIC).

[0055] The meter may also include additional components. For example, memory may be a separate component or may be included in one or more of the individual components 601, 602, and 603. A processor or processing unit may also be included in any of the components. The processor may execute computer readable instructions that configure the processor to perform the functions of the meter, including the metering, processing, and communication functions described herein. The instructions may be stored on a computer readable medium.

[0056] The measurement component 601 may measure the voltage, current, or other characteristics of the electrical grid and perform some processing of the measurements, including generating waveform data. The processing unit 602 may process the waveform data to calculate a disturbance magnitude value and transmit the disturbance magnitude value to the communication module. The processing unit may also buffer the waveform data.

[0057] The communications module 603 may transmit a power failure notification message including the disturbance magnitude value to a central system. The communications module may also facilitate other communications between the meter and the central system or other devices.

[0058] In other embodiments, the components may be located differently, functions may be performed by one or more of the components, or components 601, 602, and 603 may be integrated together.

[0059] Example Operating Environment 7 depicts an example electrical grid. The electrical grid includes a generator 710, which may be a power generating facility or a generator at a power generating facility. The generator 710 may generate three-phase alternating current (AC) power and transmit the power via a transmission line 715 to a substation 720.

[0060] Substation 720 includes a transformer 730 that steps down the voltage for customer consumption. The stepped-down power is sent by transmission lines 740a, 740b, and 740c to transformers 750 and 755, which further step down the voltage for customer consumption.

[0061] Transformers 750 and 755 may deliver single-phase or three-phase power to customer premises via meter 760. The meter may monitor characteristics such as current, voltage, and power and may be a polyphase meter. Sensors (not shown in FIG. 7) may also be included throughout the grid and may monitor characteristics of the grid. Additionally, other power assets than those shown may also be included in the grid.

[0062] The central system maintains topological information regarding the geographic locations of meters 760, sensors (not shown), and power assets, and the connections of meters 760, sensors, and other power assets within the power grid.

[0063] In the event of an outage, the central system receives outage notification messages including disturbance magnitude values ​​from the multiple meters 760. Typically, only some of the outage notification messages transmitted by the meters 760 reach the central system, whereby the central system analyzes the received messages and interpolates the outage area based on the received messages and topology information maintained by the central system. Determining the outage area based on the interpolation is also referred to as outage scaling. The system may generate one or more images visually representing the outage area.

[0064] The central system analyzes the disturbance magnitude values ​​to identify local maxima and considers topology information to identify the fault location. In one embodiment, the central system receives power malfunction notification messages from three meters, meter A, meter B, and meter C. The power malfunction notification message from meter A includes a disturbance magnitude value of 0.3, the power malfunction notification message from meter B includes a disturbance magnitude value of 0.8, and the power malfunction notification message from meter C includes a disturbance magnitude value of 0.2. The topology information indicates that meter A is located upstream of meter B (i.e., closer to the power source), meter B is located upstream of meter C, and all three meters are connected to a common power asset. The topology information may be based on a connectivity model, such as a GIS model, maintained in the central system. If topology information is unavailable or incomplete, the central system may use geographic location information for the meters to determine that meters A, B, and C are located in the same geographic area and their disturbance magnitude values ​​should be compared.

[0065] The central system may determine that meter B is closest to the fault because it has the disturbance magnitude value that is the maximum. It may also determine that the likely location of the fault is the line between meters A and B based on the relative disturbance magnitude values ​​for the three meters and the grid model impedance. Because the disturbance magnitude value may depend on whether the fault is upstream or downstream of the meter, the central system may take into account the relative location of the meters in the grid topology when determining the likely location of the fault. The likely location of the fault is not necessarily between the two meters with the highest disturbance magnitude value. The central system may indicate the likely location of the fault on an image of the malfunctioning area.

[0066] Once the central system has determined that an outage exists, it may continue to analyze any newly received power outage notification messaging and disturbance magnitude values ​​to update the outage area and likely fault location. In one embodiment, the analysis is repeated on a cycle, such as every 30 seconds, for as long as the outage exists.

[0067] The likely outage location may be used to control an outage response, which may include determining an outage area and determining an outage response plan, including selecting and reconfiguring power assets to restore power to the premises, identifying assets as priority assets for repair or maintenance purposes, identifying repair or maintenance resources in proximity to the outage location, deploying repair or maintenance resources to an area that includes the likely outage location, and exchanging communications with utility personnel, customers, or others. The disturbance magnitude value may enable faster and more efficient resolution of the outage. Identifying the likely outage location may also enable more specific communications to customers based on the relative distance of the customer premises to the likely outage location, such that different customers in the same outage area are provided with different power restoration prospects.

[0068] The central system may also analyze the disturbance magnitude value associated with the momentary malfunction. The central system may receive a message from the meter that includes the disturbance magnitude value associated with the momentary malfunction. The disturbance magnitude value may be included as additional data in a message (e.g., an event reporting message) that is periodically sent to the central system, or may be included in a message sent to report the momentary malfunction or in response to a request from the central system for information on the momentary malfunction. If the meter initiates a message, it may send the message periodically instead of in response to detecting the momentary malfunction.

[0069] The central system may analyze disturbance magnitude values ​​associated with momentary malfunctions periodically, such as once a day. The central system may consider the time associated with disturbance magnitude values ​​received from different meters to determine whether the disturbance magnitude values ​​relate to the same event. In one embodiment, the system uses a predefined time tolerance window (e.g., one minute) to identify disturbance magnitude values ​​associated with the same event.

[0070] The analysis may identify local maxima and take into account topology information to identify locations, similar to the analysis performed for sustained outages. The identified locations may correspond to faults in the power grid, including intermittent faults, or they may correspond to areas that may require maintenance, such as areas around a line that require maintenance to manage surrounding plant or animal access.

[0071] Exemplary Communication Network The central system 804 receives the disturbance magnitude values ​​822 via a communication network such as that shown in Figure 8. Figure 8 illustrates a wireless mesh network 840 that allows meters 860 and sensors 880 to communicate with other meters 860, sensors 880, and other remote devices such as the central system 804.

[0072] The meters 860 and sensors 880 send disturbance magnitude values ​​822 to other meters 860 and sensors 880 to their respective root nodes 864. The meters 860 and sensors 880 may communicate with each other via a variety of wireless and wired communication technologies, including RF, satellite, 3g, 4g, UHB, PLC, WiFi, and other communication technologies.

[0073] The root node may be a personal area network coordinator, gateway, or other device capable of communicating with the central system 804 and other devices in the mesh network. Additionally, the root node 864 forwards the disturbance magnitude value to the central system via the network 810.

[0074] The central system 804 receives disturbance magnitude values ​​from meters 860 and 804 forwarded by root node 864. In some embodiments, meter 860 is configured to stream disturbance magnitude values ​​and other information to the central system 804 by root node 864. The central system 804 may also query meters 860 and sensors 880 for disturbance magnitude values.

[0075] While the subject matter of the present application has been described in detail with respect to certain embodiments thereof, it will be recognized that those skilled in the art, upon understanding the foregoing, may readily make modifications, variations, and equivalents of such embodiments. It is therefore to be understood that the present disclosure is presented for purposes of illustration and not limitation, and is not intended to exclude inclusion of such modifications, variations, and / or additions to the subject matter of the present application as would be readily apparent to one of ordinary skill in the art.

Claims

1. 1. A method for providing malfunction information by a meter, comprising: collecting waveform data including at least voltage or current data for at least one phase of an electrical grid connected to the meter; storing the waveform data in a buffer; detecting a voltage value outside a predetermined voltage range at an interface connected to the grid for a predetermined number of cycles; determining that a malfunction event has commenced based on a voltage value outside the predetermined voltage range continuing for the predetermined number of cycles; determining a disturbance magnitude value based on a determination that the malfunction event has commenced by accessing the stored waveform data and calculating a disturbance magnitude value related to the malfunction event using the stored waveform data collected prior to the commencement of the malfunction event; communicating said disturbance magnitude value to a communication module of said meter; While the above malfunction event continues, entering a low power mode of operation in response to determining that a first predetermined period of time has expired from initiation of the malfunction event; determining that the malfunction event is a sustained malfunction event in response to determining that a second predetermined time period has expired from initiation of the malfunction event; transmitting, by the communication module, a message including the disturbance magnitude value. method.

2. an application program running on said meter calculating said disturbance magnitude value; determining a disturbance magnitude value includes notifying the application program that the malfunction event has begun and causing the application program to access the stored waveform data to calculate the disturbance magnitude value. The method of claim 1.

3. Entering low power mode operation means shutting down the application program; and operating the communication module in an idle mode. The method of claim 2.

4. the meter is a polyphase meter and the voltage or current data for the grid includes voltage or current data for multiple phases. The method of claim 1.

5. the message including the disturbance magnitude value is a malfunction notification message or the message including the disturbance magnitude value is separate from the malfunction notification message; The method of claim 1.

6. the disturbance magnitude value identifying a relative distance of the meter to a fault in the grid associated with the malfunction event compared to other meters in the grid. The method of claim 1.

7. determining that the malfunction event is an instantaneous malfunction event if the malfunction event terminates after expiration of the first predetermined time period and before expiration of the second predetermined time period; and storing information about the instantaneous malfunction event, the information including the disturbance magnitude value. The method of claim 1.

8. The meter maintains the buffer to contain waveform data over a predetermined number of the most recent cycles. The method of claim 1.

9. 1. A method for providing malfunction information by a meter, the method comprising: collecting waveform data including at least voltage or current data for at least one phase of an electrical grid connected to the meter; storing the waveform data in a buffer; The method further comprises: retrieving stored waveform data associated with a predetermined time period; using the retrieved waveform data to calculate a disturbance magnitude value based on a waveform characteristic indicative of a malfunction, the disturbance magnitude value corresponding to a time period associated with the retrieved waveform data; storing said disturbance magnitude value; determining a plurality of disturbance magnitude values ​​each associated with a different time period by The method further comprises: determining that a malfunction event has begun; based on a determination that the malfunction event has commenced, retrieving one of the stored disturbance magnitude values ​​corresponding to a time period prior to the commencement of the malfunction event and communicating the retrieved disturbance magnitude value to a communications module; While the above malfunction event continues, entering a low power mode of operation in response to determining that a first predetermined period of time has expired from initiation of the malfunction event; determining that the malfunction event is a sustained malfunction event in response to determining that a second predetermined time period has expired from initiation of the malfunction event; transmitting, by the communication module, a message including the disturbance magnitude value. method.

10. determining that the malfunction event has ended after expiration of the first predetermined time period and before expiration of the second predetermined time period; determining that the malfunction event is an instantaneous malfunction event; and storing information about the instantaneous malfunction event, the information including the disturbance magnitude value for a time period prior to the onset of the malfunction event.

10. The method of claim 9.

11. The method further includes transmitting an event report message; the event report message includes information regarding the instantaneous malfunction event, the information including the disturbance magnitude value regarding the instantaneous malfunction event. The method of claim 10.

12. The sending of the event report message may be in response to a query from a remote system or based on a reporting schedule. The method of claim 11.

13. 1. A system for managing a malfunction event, comprising: The system includes a meter and a central system; The above meter is collecting waveform data including at least voltage or current data for at least one phase of an electrical grid connected to said meter; The waveform data is stored in a buffer. Detecting a voltage value associated with the electrical grid that is outside a predetermined voltage range for a predetermined number of cycles; determining that a malfunction event has commenced based on a voltage value outside the predetermined voltage range continuing for the predetermined number of cycles; determining a disturbance magnitude value by accessing the stored waveform data and calculating a disturbance magnitude value for the malfunction event using the stored waveform data collected prior to initiation of the malfunction event; transmitting said disturbance magnitude value to a communication module of said meter; While the above malfunction event continues, entering a low power mode of operation in response to determining that a first predetermined time period has expired from initiation of the malfunction event; in response to determining that a second predetermined time period has expired from initiation of the malfunction event, determining that the malfunction event is a sustained malfunction event; configured to transmit the disturbance magnitude value as a message by the communication module; The central system is communicating with the meter and with additional meters in the grid; receiving the disturbance magnitude value from the meter; receiving an additional disturbance magnitude value from the additional meter; identifying a fault location based on the disturbance magnitude value and the additional disturbance magnitude value; and configuring to identify an asset of the electrical grid based on the fault location. system.

14. an application program running on said meter calculating said disturbance magnitude value; determining a disturbance magnitude value includes notifying the application program that the malfunction event has begun and causing the application program to access the stored waveform data to calculate the disturbance magnitude value. The system of claim 13.

15. Entering low power mode operation means shutting down the application program; and operating the communication module in an idle mode.

15. The system of claim 14.

16. the central system reconfiguring the identified assets to restore power to at least one premises. The system of claim 13.

17. the central system generates a plurality of distinct malfunction communications for a premises associated with the meter and another premises associated with one of the additional meters based on the disturbance magnitude value and the additional disturbance magnitude value. The system of claim 13.

18. the central system determines a malfunction area using the disturbance magnitude value and the additional disturbance magnitude value and generates an image of the malfunction area, the image including an indication of the fault location. The system of claim 13.

19. determining that the malfunction event has ended after expiration of the first predetermined time period and before expiration of the second predetermined time period; determining that the malfunction event is an instantaneous malfunction event; storing information about the instantaneous malfunction event, the information including the disturbance magnitude value. The system of claim 13.

20. The meter maintains the buffer to contain waveform data over a predetermined number of the most recent cycles. The system of claim 13.

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