Process, Device and System For Volt/VAR Optimization

• US 20120182157A1
• Filed: 01/13/2012
• Published: 07/19/2012
• Est. Priority Date: 01/14/2011
• Status: Active Grant

• Current Assignee: Trilliant Holdings, Inc. (Trilliant Networks Incorporated)
• Original Assignee: Trilliant Incorporated (Trilliant Networks Incorporated)
• Inventors: Carr, Jim
• Granted Patent: US 9,282,383 B2
• Time in Patent Office: Days
• US Class Current: 340/870.02
• CPC Class Codes: G01D 4/002 Remote reading of utility meters
• CPC Class Codes: G01D 4/004 Remote reading of utility meters to a fixed location
• CPC Class Codes: G01D 4/006 Remote reading of utility meters to a non-fixed location, i.e. mobile location
• CPC Class Codes: H04Q 2209/25 using a mesh network, e.g. a public urban network such as public lighting, bus stops or traffic lights
• CPC Class Codes: H04Q 2209/60 for transmitting utility meters data, i.e. transmission of data from the reader of the utility meter
• CPC Class Codes: H04Q 9/00 Arrangements in telecontrol or telemetry systems for selectively calling a substation from a main station, in which substation desired apparatus is selected for applying a control signal thereto or for obtaining measured values therefrom
• CPC Class Codes: Y02B 90/20 Smart grids as enabling technology in buildings sector smart grids supporting the management or operation of end-user stationary applications in general, or like technologies with no associated climate change mitigation effect Y04S20/00
• CPC Class Codes: Y04S 20/221 General power management systems
• CPC Class Codes: Y04S 20/222 Demand response systems, e.g. load shedding, peak shaving
• CPC Class Codes: Y04S 20/30 Smart metering, e.g. specially adapted for remote reading

Abstract

Embodiments of the invention propose volt/VAR optimization that may be time synchronized and automated based on actions invoked at a control system utilizing a smart grid solution that incorporates metering end points which are capable of reporting to a utility the information that is needed by the utility or to another system for making real time decisions on events that may occur at the distribution level. Embodiments of the invention incorporate large numbers of end points (e.g., smart meters) which a utility can use to determine how any event or events it may invoke at the grid level affect its compliance at the end user level.

Claims

1. A system comprising:

a first mesh gate associated with a first network in communication with a first meter associated with a circuit, the first meter adapted to read first meter information over a period of time and the first mesh gate adapted to transmit the first meter information over a second network;

a second meter synchronized with the first meter and associated with the first mesh gate of the first network, the second meter associated with the circuit and adapted to read second meter information over the period of time, the first mesh gate further adapted to transmit the second meter information over the second network; and

a server adapted to receive the first and second meter information from the first mesh gate via the second network,

wherein the first mesh gate transmits the first meter information and the second meter information in response to a switching event impacting the circuit.

2. A system according to claim 1, wherein the first and second meter information comprises one or more of the group consisting of voltage data, phase angle data, and VAR.

3. A system according to claim 2, wherein the first and second meter information comprises voltage data.

4. A system according to claim 3, wherein the voltage data comprises one or more of the group consisting of instantaneous voltage, average voltage over the period of time, high voltage over the period of time, and low voltage over the period of time.

5. A system according to claim 1, wherein the first and second meter information are transmitted in real-time or near real-time.

6. A system according to claim 1, wherein the switching event comprises activation of a tap changer or capacitor bank on the circuit.

7. A system according to claim 1, wherein the first and second meters transmit synchronized first and second meter information at time intervals during the period of time.

8. A system according to claim 7, wherein the period of time comprises from about 1 minute to about 20 minutes.

9. A system according to claim 7, wherein the time interval is about one minute.

10. A system according to claim 1 wherein the server determines if the switching event had the desired effect, based on the first and second meter information.

11. A system according to claim 1 further comprising a control system in communication with the server, the control system analyzing the first and second meter information to determine if a second switching event is required.

12. A system according to claim 1, wherein the first and second meter information are transmitted for the period of time before the switching event and after the switching event.

13. A system according to claim 1, wherein the switching event is issued when a voltage at the first or second meter falls below a certain threshold.

14. A system according to claim 1, wherein the switching event is issued when a voltage at the first or second meter is above a certain threshold.

15. A system according to claim 1, wherein the first and second meter information is employed to prepare a compliance report.

16. A method comprising:

in response to an issued switching event, receiving, by a head end server associated with a mesh network, a first meter information from a first meter associated with the mesh network and associated with a circuit;

in response to the issued switching event, receiving, by the head end server, a second meter information from a second meter synchronized with the first meter, the second meter associated with the mesh network and the circuit;

transmitting, by the head end server, the first and second meter information to a utility server;

determining, by the utility server, based on the first and second meter information, the effect of the switching event.

17. A method according to claim 16, wherein the first and second meter information comprises one or more of the group consisting of voltage data, phase angle data, and VAR.

18. A method according to claim 16, wherein the first and second meter information comprises voltage data.

19. A method according to claim 16, wherein the voltage data comprises one or more of the group consisting of instantaneous voltage, average voltage over the period of time, high voltage over the period of time, and low voltage over the period of time.

20. A method according to claim 16, wherein the first and second meter information are transmitted in real-time or near real-time.

21. A method according to claim 16, wherein the switching event comprises activation of a tap changer or capacitor bank on the circuit.

22. A method according to claim 16, wherein the synchronized first and second meter information are received from the first and second meters at a time interval during a period of time.

23. A method according to claim 22, wherein the period of time comprises from about 1 minute to about 20 minutes.

24. A method according to claim 22, wherein the wherein the first and second meter information are requested for the period of time before the switching event and after the switching event.

25. A method according to claim 22, wherein the time interval is about one minute.

26. A method according to claim 16 further comprising determining, by the utility server, based on the first and second meter information, that a second switching event is required.

27. A method according to claim 16, wherein the switching event is issued when a voltage at the first or second meter falls below a certain threshold.

28. A method according to claim 16, wherein the switching event is issued when a voltage at the first or second meter is above a certain threshold.