Method for Calibrating Sensors in a Power System

• US 20130262012A1
• Filed: 03/30/2012
• Published: 10/03/2013
• Est. Priority Date: 03/30/2012
• Status: Active Grant

• Current Assignee: GE Infrastructure Technology, LLC (General Electric Company)
• Original Assignee: General Electric Company
• Inventors: O'Sullivan, Charles Brendan, McCormack, Michael Anthony
• Granted Patent: US 9,685,823 B2
• Time in Patent Office: Days
• US Class Current: 702/104
• CPC Class Codes: H02J 13/00016 using a wired telecommunication network or a data transmission bus
• CPC Class Codes: H02J 13/00034 the elements or equipment being or involving an electric power substation
• CPC Class Codes: H02J 2203/20 Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
• CPC Class Codes: Y02E 60/00 Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
• CPC Class Codes: Y04S 40/124 using wired telecommunication networks or data transmission busses
• CPC Class Codes: Y04S 40/20 Information technology specific aspects, e.g. CAD, simulation, modelling, system security

Abstract

A system that includes a controller configured to receive data corresponding to at least a portion of a power system and one or more sensor measurements from one or more sensors in the power system. The controller may then generate a model of the power system based on at least a portion of the data and at least a portion of the sensor measurements such that the model may include one or more model measurements that correspond to the sensor measurements. After generating the model of the power system, the controller may determine one or more correction factors for the sensor measurements based on at least a portion of the sensor measurements and the model measurements, apply the correction factors to the sensor measurements to generate corrected sensor measurements, and determine one or more properties of the power system based on the corrected sensor measurements.

Claims

1. A system, comprising:

a controller configured to;

receive data corresponding to at least a portion of a power system;

receive one or more sensor measurements from one or more sensors in the power system;

generate a model of the power system based on at least a portion of the data and at least a portion of the sensor measurements, wherein the model comprises one or more model measurements that correspond to the sensor measurements;

determine one or more correction factors for the sensor measurements based on at least a portion of the sensor measurements and the model measurements;

apply the correction factors to the sensor measurements to generate corrected sensor measurements; and

determine one or more properties of the power system based on the corrected sensor measurements.

2. The system of claim 1, wherein the received data comprise:

one or more locations of the sensors in the power system;

accuracy data for the sensors;

one or more network topologies in the power system;

one or more locations of one or more switches in the power system;

one or more conductor types for one or more conductors in each network topology;

one or more conductor lengths for the conductors in each network topology;

one or more impedance values for the conductors in each network topology;

or

any combination thereof.

3. The system of claim 1, wherein the controller is configured to receive the sensor measurements from one or more pole-mounted combination sensors, one or more pole-mounted voltage sensors, one or more line-mounted voltage sensors, or any combination thereof.

4. The system of claim 1, wherein the controller is configured to generate the model of the power system by simulating one or more voltages for one or more nodes on the power system based on the at least a portion of the data and the at least a portion of the sensor measurements, wherein the at least a portion of the sensor measurements comprises measurement data received from a portion of the sensors disposed on power equipment that is coupled to directly to a power station in the power system.

5. The system of claim 4, wherein the voltages correspond to the model measurements.

6. The system of claim 1, wherein the controller is configured to determine the correction factors by:

determining one or more differences between the model measurements and the sensor measurements; and

generating the correction factors based on the differences.

7. The system of claim 1, wherein the properties of the power system comprise:

one or more locations of one or more faults in the power system;

one or more volt-ampere-reactive (VAR) measurement for the power system;

one or more power measurements for the power system;

one or more power flow measurements for the power system;

or

any combination thereof.

8. The system of claim 1, wherein the controller is configured to generate the model of the power system on a quasi-continuous basis.

9. The system of claim 1, wherein the controller is configured to send the correction factors to the sensors.

10. The system of claim 1, comprising:

a power station having the controller;

a substation having the controller;

or

any combinations thereof.

11. A sensor, comprising:

a controller configured to;

send a first set of one or more sensor measurements from the sensor to a data processing station;

receive one or more correction factors for the sensor measurements, wherein the correction factors are determined based on a model of a power system, and wherein the model is generated based on at least a portion of data corresponding to at least a portion of the power system and at least a portion of a second set of sensor measurements; and

apply the correction factors to the sensor measurements to generate corrected sensor measurements for determining one or more properties of the power system.

12. The sensor of claim 11, wherein the first set of the sensor measurements comprise one or more voltages, one or more currents, one or more phases, one or more frequencies, one or more line droop angles, one or more line accelerations, or one or more line temperatures of one or more conductors that correspond to the sensors.

13. The sensor of claim 11, wherein the data processing station is located in a power station in the power system, a substation in the power station, a relay in the power station, or any combination thereof.

14. A non-transitory computer-readable medium having computer executable code stored thereon, the code comprising instructions for:

receiving data corresponding to at least a portion of a power system;

receiving one or more sensor measurements from one or more sensors in the power system;

generating a model of the power system based on at least a portion of the data and at least a portion of the sensor measurements, wherein the model comprises one or more model measurements that correspond to the sensor measurements;

determining one or more correction factors for the sensor measurements based on at least a portion of the sensor measurements and the model measurements; and

sending the correction factors to the sensors.

15. The non-transitory computer-readable medium of claim 14, wherein the code comprises instructions for:

receiving one or more corrected sensor measurements from the sensors; and

determining one or more properties of the power system based on the corrected sensor measurements.

16. The non-transitory computer-readable medium of claim 14, wherein the instructions for receiving the sensor measurements comprise instructions for:

receiving the sensor measurements from the sensors in a power station of the power system, wherein the power station is configured to generate electrical power;

receiving the sensor measurements from the sensors in one or more substations coupled to the power station, wherein the substations distribute the electrical power downstream;

or

any combination thereof.

17. The non-transitory computer-readable medium of claim 14, wherein the instructions for sending the correction factors comprises instructions for sending the correction factors to one or more relays configured to forward the correction factors to the sensors.

18. The non-transitory computer-readable medium of claim 14, wherein the instructions for receiving the data comprise instructions for:

receiving one or more conductor types for one or more conductors in the power system;

receiving one or more conductor lengths for the conductors;

receiving one or more impedance values for the conductors;

or

any combination thereof.

19. The non-transitory computer-readable medium of claim 14, wherein the sensors are configured to measure voltage based on one or more effective capacitance values in one or more conductors and ground.

20. The non-transitory computer-readable medium of claim 19, wherein the sensors are configured to measure one or more voltages, one or more currents, one or more phases, one or more frequencies, one or more line droop angles, one or more line accelerations, or one or more line temperatures of the conductors.