Electrical network topology determination

Patent metadata

Field	Value
Publication number	US-10459016-B2
Application number	US-201715831028-A
Country	US
Kind code	B2
Filing date	Dec 4, 2017
Priority date	Dec 2, 2014
Publication date	Oct 29, 2019
Grant date	Oct 29, 2019

Abstract

Determination of electrical network topology and connectivity are described herein. A zero-crossing is indicated at a time when the line voltage of a conducting wire in an electrical grid is zero. Such zero-crossings may be used to measure time within a smart grid, and to determine the connectivity of, and the electrical phase used by, particular network elements. A first meter may receive a phase angle determination (PAD) message, including zero-crossing information, sent from a second meter, hereafter called a reference meter. The first meter may compare the received zero-crossing information to its own zero-crossing information. A phase difference may be determined between the first meter and the reference meter from which the PAD message originated. The first meter may pass the PAD message to additional meters, which propagate the message through the network. Accordingly, an electrical phase used by meters within the network may be determined.

First claim

What is claimed is:

1. A method, comprising:
sending a broadcast timing signal to a plurality of meters;
receiving a first difference value and a second difference value, from a first meter and a second meter, respectively, wherein the first difference value and the second difference value are based on elapsed time between the broadcast timing signal and a first zero-crossing time of the first meter and a second zero-crossing time of the second meter, respectively;
determining a phase of a power line to which each of the first meter and the second meter are connected, using the first difference value and the second difference value, respectively;
receiving data describing a first voltage event and receiving data describing a second voltage event, occurring at the first meter and the second meter, respectively;
comparing the data describing the first voltage event and the data describing the second voltage event; and
determining, based at least in part on the comparing, and based at least in part on the phase of the power line to which each of the first meter and the second meter are connected, if the first voltage event and the second voltage event are the same event.

2. The method of claim 1 , wherein the method additionally comprises:
refreshing data indicating the phase of the power line to which each of the first meter and the second meter are connected;
wherein the refreshing increases accuracy of smart grid analytics software applications running on a server performing the method.

3. The method of claim 1 , wherein the broadcast timing signal is sent by a first cellular tower, and the method additionally comprises:
sending a second broadcast timing signal from a second cellular tower;
determining respective phases to which each of a plurality of meters are connected, using the second broadcast timing signal; and
providing the determined respective phases of each of the plurality of meters to an analytics software application running on a server.

4. The method of claim 1 , wherein the broadcast timing signal is sent by a cellular tower, and the method additionally comprises:
receiving data from a meter in communication with the cellular tower and in communication with a mesh network; and
determining phases to which each of a plurality of meters on the mesh network are connected based in part on the received data.

5. The method of claim 1 , wherein the broadcast timing signal is sent by a first cellular tower, and the method additionally comprises:
collecting data obtained by at least one of the plurality of meters, wherein the data is obtained using a mesh network to which the at least one of the plurality of meters is connected.

6. The method of claim 1 , wherein the method additionally comprises:
resetting a threshold to which voltage events are compared, wherein the threshold is based on a ranking of voltage events seen by metrology devices associated with the plurality of meters; and
detecting the first voltage event exceed the reset threshold.

7. The method of claim 1 , wherein the first difference value and the second difference value are expressed as a period of time or a phase angle.

8. One or more computer-readable media storing computer-executable instructions that, when executed, cause one or more processors to perform acts comprising:
sending a broadcast timing signal to a plurality of meters;
receiving a first difference value and a second difference value, from a first meter and a second meter, respectively, wherein the first difference value and the second difference value are based on elapsed time between the broadcast timing signal and a first zero-crossing time of the first meter and a second zero-crossing time of the second meter, respectively;
determining a phase of a power line to which each of the first meter and the second meter are connected, using the first difference value and the second difference value, respectively;
receiving data describing a first voltage event and receiving data describing a second voltage event, occurring at the first meter and the second meter, respectively;
comparing the data describing the first voltage event and the data describing the second voltage event; and
determining, based at least in part on the comparing, and based at least in part on the phase of the power line to which each of the first meter and the second meter are connected, if the first voltage event and the second voltage event are the same event.

9. One or more computer-readable media as recited in claim 8 , wherein the acts additionally comprise:
refreshing data indicating the phase of the power line to which each of the first meter and the second meter are connected;
wherein the refreshing increases accuracy of smart grid analytics software applications running on a server performing the method.

10. One or more computer-readable media as recited in claim 8 , wherein the broadcast timing signal is sent by a first cellular tower, and the acts additionally comprise:
sending a second broadcast timing signal from a second cellular tower;
determining respective phases to which each of a plurality of meters are connected, using the second broadcast timing signal; and
providing the determined respective phases of each of the plurality of meters to an analytics software application running on a server.

11. One or more computer-readable media as recited in claim 8 , wherein the broadcast timing signal is sent by a cellular tower, and the acts additionally comprise:
receiving data from a meter in communication with the cellular tower and in communication with a mesh network; and
determining phases to which each of a plurality of meters on the mesh network are connected based in part on the received data.

12. One or more computer-readable media as recited in claim 8 , wherein the broadcast timing signal is sent by a first cellular tower, and the acts additionally comprise:
collecting data obtained by at least one of the plurality of meters, wherein the data is obtained using a mesh network to which the at least one of the plurality of meters is connected.

13. One or more computer-readable media as recited in claim 8 , wherein the acts additionally comprise:
resetting a threshold to which voltage events are compared, wherein the threshold is based on a ranking of voltage events seen by metrology devices associated with the plurality of meters; and
detecting the first voltage event exceed the reset threshold.

14. One or more computer-readable media as recited in claim 8 , wherein the first difference value and the second difference value are expressed as a period of time or a phase angle.

15. A computing device, configured to perform acts comprising:
sending a broadcast timing signal to a plurality of meters;
receiving a first difference value and a second difference value, from a first meter and a second meter, respectively, wherein the first difference value and the second difference value are based on elapsed time between the broadcast timing signal and a first zero-crossing time of the first meter and a second zero-crossing time of the second meter, respectively;
determining a phase of a power line to which each of the first meter and the second meter are connected, using the first difference value and the second difference value, respectively;
receiving data describing a first voltage event and receiving data describing a second voltage event, occurring at the first meter and the second meter, respectively;
comparing the data describing the first voltage event and the data describing the second voltage event; and
determining, based at least in p

Assignees

• Itron Inc

Inventors

• Driscoll Timothy James
• Van Wyk Hartman
• Sonderegger Robert
• Higgins Chris

Classifications

• G01R19/2513

  Arrangements for monitoring electric power systems, e.g. power lines or loads; Logging · CPC title

• G01D4/006

  Remote reading of utility meters to a non-fixed location, i.e. mobile location · CPC title

• G01D4/004

  Remote reading of utility meters to a fixed location · CPC title

• G01D4/002 Primary

  Remote reading of utility meters · CPC title

• G01R25/00 Primary

  Arrangements for measuring phase angle between a voltage and a current or between voltages or currents · CPC title