Case Study: Inglewood Distribution Automation. April 5 th, 2018 NWESS

Transcription

1 Case Study: Inglewood Distribution Automation April 5 th, 2018 NWESS

2 Outline Introduction to Puget Sound Energy (PSE) Distribution Automation Overview Project Implementation DA Scheme Example Adaptive Setting Groups Device Coordination Design Challenges Standardizing Equipment Special Considerations

3 Puget Sound Energy (PSE) PSE is Washington State s oldest and largest utility Served the Puget Sound egion for over 135 years 1.1 million electric customers 400+ substations 300+ distribution substation feeder circuits Primarily a distribution focused electric utility OT ANGELES AM SAN JUAN JEFFESON MASON SHELTON OAK HAO POT TOWNSEND OLYMPIA THUSTON CENTALIA CHEHALIS ANACOTES ISLAND EMETON KITSAP LANGLEY AINIDGE ISLAND GIG HAO ELLINGHAM MOUNT VENON MAYSVILLE EDMONDS SEATTLE TACOMA EVEETT MONOE DUVALL EDMOND ELLEVUE ENTON KENT PUYALLUP AUUN WHATCOM SKAGIT PIECE SNOHOMISH INDEX KING NOTH END LACK DIAMOND ENUMCLAW CHELAN WENATCHEE CLE ELUM KITTITAS ELLENSUG KITTITAS YAKIMA LEWIS YAKIMA

4 Distribution Automation Overview PSE Formed a task force in 2015 for vendor proposals Project benefits estimated at 20x their initial cost Per Project reliability benefits 5,000 Customer Interruptions reduced 700,000 Customer Minutes of Interruption reduced

5 Approaches to Distribution Automation Several Different Approaches to DA Fault Targeting Only Switches Exposes Entire Feeder to momentary outages Little to no coordination study High Speed Communications GOOSE Cost Prohibitive equires new equipment PSE s Hybrid Approach Designing the DA scheme around protection requirements and fundamentals

6 FLIS PSE Protective Devices TU (emote Terminal Unit) EMS (Energy Managemnet System) SCADA Operator Control FLIS Software

7 System One Line KNM #2 23 ING #1 X N.O. X636 X1424 X420 X5408 X1829 N.O. N.O. X76976

8 51P/51G PU Levels KNM #2 PH 720 G 360 ING #1 N.O. PH 400 G 340 NA PH 300 G 300 PH 720 G 360 PH 400 G 340 PH 720 G 360 PH 300 G 300 NA N.O. N.O. PH 400 G 340

9 Typical Distribution Time Current Curves 10 TIME (SECONDS) Fault Current 1 Damage Curve Fuse Curves ΔCTI CUENT (AMPEES) 0.1k 1k 10k Transformer reaker ecloser 1 ecloser 2

10 Line Lengths KNM #2 ING # mi 1.35 mi 0.5 mi mi Z L mi 1.4 mi 1.45 mi 0.6 mi 1.5 mi

11 Adaptive Setting Group Example - Fault KNM #2 ING #1

12 Adaptive Setting Group Example - Fault KNM #2 EMS FLIS (DA) EMS ING #1 ECLOSE 79LO 10s SCADA OPEN

13 Adaptive Setting Group Example - estoration KNM #2 ING #1

14 Adaptive Setting Group Example - estoration KNM #2 ING #1 PH 720 G 360 PH 300 G 300 Coordination? I L I L PH 300 G 300 I L I L NA I L PH 400 G 340

15 Coordination Options Let the devices miscoordinate DA software can detect this Event analysis and troubleshooting What happens if DA scheme is off? High Speed Communications GOOSE Existing infrastructure does not support GOOSE Expensive to implement Turn all devices into smart switches Exposes all customers to fault No ability to sectionalize system if DA scheme is off

16 PSE s Hybrid Approach to DA schemes Design protection system as normal Any devices that cannot be coordinated are turned into automated fault targeting switches Take each feeder contingency separately Fault Tripping Off Mode Program separate setting groups into reclosers Setting the 51P and 51G elements emoving the 51P1T and 51G1T elements from the trip equation DA system enables setting group during feeder reconfiguration Greater Flexibility in choosing which devices operate for faults Directionality can still be used for separate feeder pickups in the forward or reverse direction (requires voltage sensing)

17 Adaptive Setting Group Example SG2 KNM #2 ING #1 PH 720 G 360 PH 300 G 300 I L I L I L Switch Mode I L Switch Mode I L PH 400 G 340

18 Alternate Feed Distinct PU/TD KNM #2 PH 720 G 360 ING #1 PH 400 G 340 I L Switch Mode PH 300 G 300 New TD=3.4 I L I L Switch Mode I L NA

19 Non Fault Tripping Mode 10 TIME (SECONDS) Fault Current 1 Damage Curve Transformer Fuse Curves ecloser 2 ΔCTI reaker ecloser 1 ecloser with non fault tripping CUENT (AMPEES) 0.1k 1k 10k

20 Design Challenges Integrating DA scheme into existing infrastructure Documentation Maintaining Protection Standards Proper CTI Margins etween Devices Ensure EOL clearing criteria is met Increased load limits, while maintaining sensitivity Standardizing Future Equipment Minimum requirements for device to be included in DA 51T, 52A, Amps, HLWS ecloser Controllers

21 Microprocessor ased Feeder reaker

22 Can you automate this please? Older Electromechanical based design PSE has over 1,260 Feeder reaker relay Set 10% Modern Day microprocessor based relay sets 20% First Generation Microprocessor based relay sets 70% Electromechanical relay packages

23 Trip Indication elays + TI HLWS DC 51P 51G 50P 50G - TC SHUNT VAISTO (MAGNETIC ACTUATED MECHANISM)

24 Trip Indication elays

25 Documentation Standardize on minimum requirement for relay to be integrated into DA Scheme Device Type Generation of Device Voltage Sensing What DNP points were available How were these points going to be mapped into the SCADA/EMS system Setting group documentation for planners and operators

26 IED-EMS Maps for DA IED TU/EMS Modern Day SV5T (Overcurrent Pickup) LT15 (Overcurrent Trip) 07 (Latch eset) 52A O/C (Status, OC::CC) 79LO (eclosing Lock Out Status) HLWS (LT06,Status, ON::OFF) SUPV/LOCAL (LT03, Status) UF Trip Alarm (XFM or reaker) XXX_OCPICKUP XXX_FLT_TIP ESET XXX XXX_ECL_LKO XXX_HLWS XXX_LCL_MT XXX_UF_TP_S A C D F G H Signifies point is latched closed, once picked up. Latched points must be reset before they are cleared. Signifies control point in EMS. First Generation PUA (Overcurrent Pickup) 51P* (Phase TOC Trip Alarm) 51N* (Neutral TOC Trip Alarm) 52A O/C (Status, OC::CC) 79LOA (ecloser Lockout Alarm) ST_ALMS_LED (Alarm eset) HLWS (Status, ON::OFF) SUPV/LOCAL (Status) UF Trip Alarm (XFM or reaker) XXX_OCPICKUP XXX_FLT_TIP XXX XXX_ECL_LKO ESET XXX_HT_LN_WK XXX_LCL_MT XXX_UF_TP_S A C D F G H

27 Setting Group Tables for econfiguration NAME IED LOAD LIMIT (A) SETTING GOUP FO ECONFIGUATION KNM-23 ING-13 ING-15 KNM-23 X636 XXX ### ING-13 X1424 XXX ### ING-13 X5408 XXX ### ING-15 X1829 XXX ### ING-15 X420 XXX ### ING-15 X76976 XXX ### ING-13 EM ### ING-15 EM ### KNM-23 EM ### SETTING GOUP 1 ECLOSE WILL TIP FO FAULTS DOWNSTEAM SETTING GOUP 2 ECLOSE WILL SIGNAL AND TAGET ONLY FO FAULTS DOWNSTEAM

28 Load Encroachment on non-directional elements PSE has a protection design standard of ensuring bolted end of line (EOL) faults cover 150% of the phase and ground pickups Maintains standard pickup values for reclosers down the feeder Allows higher load limit of circuit than 51P set point

29 Load Encroachment on a non-directional element Proper Supervision is required Operates purely off Positive Sequence Susceptible to assertion during unbalanced faults Unbalanced faults contain all three sequence components 32Q & 32QF set above highest normal imbalance of the system 50P set higher than load limit, absolutely a fault ZLOAD LOP 50P ZLOAD 32QF 32Q 51PTC

30 Future Topics and Discussions Distributed Generation applications in DA schemes Sectionalizer mode for reclosers Event Analysis DMS system integration Staffing Support

31 Questions?

32 Extra Slides Curve Shaving 10 Portion of Curve emoved TIME (SECONDS) Desired Load Limit = 50P 51PTC = 50P 1 Transformer reaker ΔCTI Margin ecloser 1 CUENT 0.1k (AMPEES) 1k 10k ecloser 2