Online protection coordination for distribution management system

• US 9,053,020 B2
• Filed: 10/11/2012
• Issued: 06/09/2015
• Est. Priority Date: 10/11/2012
• Status: Active Grant

• Current Assignee: Hitachi Energy Limited
• Original Assignee: ABB Research Ltd. (ABB Ltd.)
• Inventors: Ishchenko, Dmitry, Li, Zhao, Stoupis, James D., Bass, Martin, Peterson, William L., Wickramasekara, M. Gamini
• Primary Examiner(s): BUTLER, SARAI E
• Application Number:
  US13/649,701
• Publication Number:
  US 20140108851A1
• Time in Patent Office: 971 Days
• Field of Search: 714/4.1, 714/25
• US Class Current: 1/1
• CPC Class Codes: G06F 11/07 Responding to the occurrence of a fault, e.g. fault tolerance
• CPC Class Codes: H02H 3/006 Calibration or setting of parameters
• CPC Class Codes: H02H 7/28 for meshed systems
• CPC Class Codes: H02H 7/30 Staggered disconnection
• CPC Class Codes: H02J 3/00125 Transmission line or load transient problems, e.g. overvoltage, resonance or self-excitation of inductive loads H02J3/01 takes precedence

Abstract

A method for automatic protection coordination in a power system network comprises identifying radial source-to-load paths and fault protection devices in the source-to-load paths, for a portion of the power system network to be coordinated. Device settings data for fault protection devices are retrieved, including multiple preconfigured settings for some devices. Fault currents for each of multiple possible electrical faults in said portion of the power system network are predicted, and a selectivity check for each pair of fault protection devices that are adjacent to one another in an identified radial source-to-load path is performed, for each of one or more of the predicted fault currents, taking into account multiple preconfigured settings for remotely controllable fault protection devices. A combination of settings for remotely controllable fault protection devices that minimizes selectivity violations among the pairs is selected, and necessary change-setting commands are sent to remotely controllable fault protection devices.

Claims

1. A method for automatic protection coordination in a power system network that includes one or more power sources and multiple fault protection devices, wherein a plurality of the fault protection devices are remotely controllable and have multiple preconfigured settings, the method comprising:

identifying radial source-to-load paths and fault protection devices in said source-to-load paths, for a portion of the power system network to be coordinated, based on stored topology data for said portion;

retrieving protection device settings data for identified fault protection devices, including the multiple preconfigured settings for remotely controllable fault protection devices in said portion of the power system network;

calculating predicted fault currents for each of a plurality of possible electrical faults in said portion of the power system network, based on the stored topology data;

performing a selectivity check for each pair of fault protection devices that are adjacent to one another in an identified radial source-to-load path, for each of one or more of the predicted fault currents, taking into account multiple preconfigured settings for remotely controllable fault protection devices;

selecting a combination of settings for remotely controllable fault protection devices, based on the selectivity check, to minimize selectivity violations among the pairs;

sending a change-setting command to remotely controllable fault protection devices for which settings have changed, based on the selected combination of settings.

2. The method of claim 1, further comprising identifying the portion of the power system network to be coordinated in response to an outage event in the power system network.

3. The method of claim 1, wherein the protection device settings data for identified fault protection devices comprise a single time-current characteristic for each of a plurality of non-remotely controllable fault protection devices and two or more time-current characteristics for each remotely controllable fault protection devices, each of the two or more time-current characteristics for each remotely controllable fault protection device corresponding to one of multiple preconfigured settings for the remotely controllable fault protection device.

4. The method of claim 1, wherein calculating predicted fault currents for each of a plurality of possible electrical faults in said portion of the power system network comprises predicting fault currents for each of a plurality of fault types at each of a plurality of nodes in the portion of the network to be coordinated.

5. The method of claim 4, wherein the plurality of fault types includes one or more fault types selected from the group consisting of:

a three-phase fault;

a line-to-line fault;

a line-to-ground fault; and

a line-to-line-to-ground fault.

6. The method of claim 1, wherein performing the selectivity check for each pair of fault protection devices that are adjacent to one another in an identified radial source-to-load path comprises, for at least one pair, identifying all combinations of settings for the pair that do not present a selectivity violation.

7. The method of claim 1, wherein performing the selectivity check for each pair of fault protection devices comprises, for at least one pair and one predicted fault current, evaluating selectivity at each of multiple currents in a range extending up to the predicted fault current.

8. The method of claim 1, wherein performing the selectivity check for each pair of fault protection devices is based on a pre-determined coordination time interval, wherein the coordination time interval defines a minimum time separation between time-current characteristics of coordinated devices at each predicted fault current.

9. The method of claim 1, wherein selecting the combination of settings to minimize selectivity violations among the pairs comprises selecting a combination for which no selectivity violations exist or, if no such combination exists, selecting a combination that minimizes an aggregate violation of coordination time intervals.

10. The method of claim 1, wherein selecting the combination of settings to minimize selectivity violations among the pairs comprises selecting a combination for which no selectivity violations exist or, if no such combination exists, selecting a combination for which a minimum number of selectivity violations exist.

11. The method of claim 10, further comprising:

determining that there is no combination for which no selectivity violations exist;

selecting a combination for which a minimum number of selectivity violations exist; and

generating a suggested new setting for a first one of the remotely programmable fault protection devices, wherein said suggested new setting would reduce the number of selectivity violations.

12. The method of claim 11, further comprising sending one or more reconfiguration commands to the first one of the remotely programmable fault protection devices to set the first one of the remotely programmable fault protection devices to the new setting.

13. The method of claim 1, further comprising first detecting a fault in the power system network and automatically generating a restoration switching sequence plan, based on the identified fault, wherein said identifying, calculating, performing, selecting and sending operations are performed in response to said detecting and are based on stored topology data that reflects network changes due to the restoration switching sequence plan.

23. The computerized automatic protection coordination system of claim 10, wherein the selectivity analysis module is further configured to:

determine that there is no combination for which no selectivity violations exist;

select a combination for which a minimum number of selectivity violations exist; and

generate a suggested new setting for a first one of the remotely programmable fault protection devices, wherein said suggested new setting would reduce the number of selectivity violations.

24. The computerized automatic protection coordination system of claim 23, wherein the communications module is further configured to send one or more reconfiguration commands to the first one of the remotely programmable fault protection devices to set the first one of the remotely programmable fault protection devices to the new setting.

14. A computerized automatic protection coordination system for use in a power system network that includes one or more power sources and multiple fault protection devices, wherein a plurality of the fault protection devices are remotely controllable and have multiple preconfigured settings, the system including:

a network topology analysis module configured to identify radial source-to-load paths and fault protection devices in said source-to-load paths, for a portion of the power system network to be coordinated, based on stored topology data for said portion;

a fault analysis module configured to calculate predicted fault currents for each of a plurality of possible electrical faults in said portion of the power system network, based on the stored topology data;

a selectivity analysis module configured to

retrieve protection device settings data for each of the identified fault protection devices, including the multiple preconfigured settings for remotely controllable fault protection devices in said portion of the power system network,

perform a selectivity check for each pair of fault protection devices that are adjacent to one another in an identified radial source-to-load path, for each of one or more of the predicted fault currents, taking into account the multiple preconfigured settings for remotely controllable fault protection devices, and

select a combination of settings for the remotely controllable fault protection devices, based on the selectivity check, to minimize selectivity violations among the pairs; and

a communications module configured to send a change-setting command to remotely controllable fault protection devices for which settings have changed, based on the selected combination of settings.

15. The computerized automatic protection coordination system of claim 14, wherein the network topology analysis module is further configured to identify the portion of the power system network to be coordinated in response to an outage event in the power system network.

16. The computerized automatic protection coordination system of claim 14, wherein the protection device settings data for identified fault protection devices comprise a single time-current characteristic for each of a plurality of non-remotely controllable fault protection devices and two or more time-current characteristics for each remotely controllable fault protection devices, each of the two or more time-current characteristics for each remotely controllable fault protection device corresponding to one of multiple pre-configured settings for the remotely controllable fault protection device.

17. The computerized automatic protection coordination system of claim 14, wherein the fault analysis module is configured to calculate predicted fault currents for each of a plurality of possible electrical faults by predicting fault currents for each of a plurality of fault types at each of a plurality of nodes in the portion of the network to be coordinated.

18. The computerized automatic protection coordination system of claim 14, wherein the selectivity analysis module is configured to perform the selectivity check for each pair of fault protection devices that are adjacent to one another in an identified radial source-to-load path by, for at least one pair, identifying all combinations of settings for the pair that do not present a selectivity violation.

19. The computerized automatic protection coordination system of claim 14, wherein the selectivity analysis module is configured to perform the selectivity check for each pair of fault protection devices by, for at least one pair and one predicted fault current, evaluating selectivity at each of multiple currents in a range extending up to the predicted fault current.

20. The computerized automatic protection coordination system of claim 14, wherein the selectivity analysis module is configured to perform the selectivity check for each pair of fault protection devices based on a pre-determined coordination time interval, wherein the coordination time interval defines a minimum time separation between time-current characteristics of coordinated devices at each predicted fault current.

21. The computerized automatic protection coordination system of claim 14, wherein the selectivity analysis module is configured to select the combination of settings to minimize selectivity violations among the pairs by selecting a combination for which no selectivity violations exist or, if no such combination exists, selecting a combination that minimizes an aggregate violation of coordination time intervals.

22. The computerized automatic protection coordination system of claim 14, wherein the selectivity analysis module is configured to select the combination of settings to minimize selectivity violations among the pairs by selecting a combination for which no selectivity violations exist or, if no such combination exists, selecting a combination for which a minimum number of selectivity violations exist.

25. The computerized automatic protection coordination system of claim 14, further comprising a fault recovery module configured to:

detect a fault in the power system network;

automatically generate a restoration switching sequence plan, based on the identified fault; and

inform the network topology analysis module of the restoration switching sequence;

wherein the network topology analysis module, fault analysis module, and selectivity analysis module are configured to operate, in response to said informing, on stored topology data that reflects network changes due to the restoration switching sequence.