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Distributech 2015 taking interoperability to the next level

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Riel Substation is Manitoba Hydro’s newest DC Converter Station as well as a major 230/500kV transmission station. Riel covers approximately 40 hectares making it physically one of the largest
substations in North America. The project modifies the existing 500kV international transmission line running from Winnipeg, CA to Minnesota.
This paper presents the analysis of the technical issues encountered during project execution such as engineering design, multivendor integration, GOOSE implementation, network infrastructure and cyber security. It covers also the organizational issues such as customer involvement and standardization, among others, lessons learned and recommendations for future implementations.
This is one of the first complete protection and control automation solution using redundant IEC61850. The technology being implemented within Riel Station is not only one of the largest Digital Control Systems on the continent, but is one of the premier systems in the world today.
As a partner of the Riel initiative, Schneider Electric has completed the engineering, design and manufacturing of protection and control panels for the entire substation using state of the art technologies including but not limited to full redundant system, NERC CIP cyber security compliance, multivendor interoperability and reliability as a top priority with 6 independent fiber optic networks, redundant protections, HMI and networks.
The implemented design permits a cost effective solution using the Ethernet Redundant Networks to communicate with others devices and non-hardwire traditional solution. The protection scheme solution is based on IEC61850, providing the protection functions and logics inside the different relays to
share and capture information required protecting the electrical network and facilitating the monitoring from HMI. By the time this paper will be presented at DTECH 2015, the 230 kV portion of the project will have been commissioned and energized.

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Distributech 2015 taking interoperability to the next level

  1. 1. 1DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Riel Station Taking Interoperability to the Next Level DISTRIBUTECH 2015 San Diego Convention Center, San Diego, Ca, USA February 3, 2015
  2. 2. 2DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Project Background
  3. 3. 3DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Manitoba Hydro – Fast facts ● 548,700 electric customers ● Installed based capacity of 5,685 MW mainly hydraulic ● Service Area: 650,000 km2 ● Capital assets in service exceeding $15 billion ● Exports electricity to three wholesale markets in Canada and the mid- western United States
  4. 4. 4DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Riel Substation ● Sectionalize 500 kV line to Minnesota ● Sectionalize 2-230 kV network lines ● In-service-date Oct 2014 ● Future site of Bipole III (ISD 2018)
  5. 5. 5DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Riel Substation Site
  6. 6. 6DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Technology ● Standard is A & B protection relays from different vendors ● Utilized A & B control systems and networks ● Utilization of IEC 61850 GOOSE messaging for protection & control 6
  7. 7. 7DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Project Overview
  8. 8. 8DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Scope of Work ● Complete solution for Substation Automation (Control & Protection) – Total 77 Panels ● Management, Engineering, Configuration, manufacturing, FAT, and Commissioning SAT ● Based on Schneider Electric PACiS (Protection and Control Integrated System) & SUI (Substation User Interface) Solution. ● High IEC61850 Network Redundancy IEC61850 (Dual-homing + RSTP). ● One configuration software for all substations, with configuration of all bay Controllers, Protective relays (reports) and HMI’s. ● NERC-CIP Compliancy. ● Capable to fulfill current and future’s requirements. ● Thanks to IEC61850, today is a reality – Phase II
  9. 9. 9DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Panels 500kV/230kV 500kV (Scope: detailed design, Manufacture, FAT, SAT support) ● 10 protection panels (16 Relays) + 2POW (6 IEDs), 1 Meters (3 IEDs) + 1 DR ( 2IED) + 1 Tap Controller ● 4 Control Panels (6 C264) ● 2 Server Panels (2 PACiS OI + 2 gateway+ 2 Engineering work stations) ● 2 Alarm annunciators (3 C264) ●Total= 23 panels 230kV (Scope: detailed design, Manufacture, FAT, SAT support) ● 18 protection panels (44 Relays) + 2 DR (2 IEDs), 6 POW (8 IEDs) ● 10 Control Panels (14 C264) ● 4 Server Panels (4 PACiS OI + 2 gateway + 2 engineering work stations) ● 4 Alarm annunciators (4 C264) ● Total= 44 panels
  10. 10. 10DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Panels 12.47kV and IEC61850 12.47kV (Scope: detailed design, Manufacture, FAT, SAT support) ● 4 protection panels (10Relays). ● 2 Control Panels (2 C264). ● 2 Server Panels (2 PACiS OI + engineering work stations). ● 2 Alarm annunciators (2 C264) ● Total: 10 panels IEC61850 (Scope: Goose implementation, Test philosophy, Net. topology) ● 500kV and 230kV: 50BF entirely implemented with goose. ● 12.47kV: 50BF and Bus bar protection using blocking schemes. ● Dual redundant network using dual homing and RSTP protocol to enhance network reliability
  11. 11. 11DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 General System Architecture ● Two different systems distributed among several buildings to: ● Supervise, ● Control, ● Protection system ● Only one supervising ring with all the information coming from different voltage levels 12.47/230/500 kV, and the control as per voltage level and system A or B. ● All protections and bay controllers use IEC61850 to: ● « Service report» sent directly to the control system. ● GOOSE messages between relay for protection functions. Building CBF1 Bay 3 & Bay 4 Busbar A1 & B1 Transformer SST1 Bay 9 & Bay 10 Busbar A2 & B2 Transformer SST2 Bank 1 Bank 1 M602F & REACTOR D603M & Bay 1 Capacitor Bank 46kV Bank 1 M602F & REACTOR D603M & Bay 1 Capacitor Bank 46kV Revenue Metering SYSTEM « A » 230 kV SYSTEM « B » 230 kV SYSTEM « B » 500 kV SYSTEM « A » 500 kV Gateway IEC/IEC Building CBF3 Building CBF2 Bay 3 & Bay 4 Busbar A1 & B1 Transformer SST1 Bay 9 & Bay 10 Busbar A2 & B2 Transformer SST2 Bank 1 Building CBF4 Building CBE1 Building CBE2 Building SS1L Building SS2L SST1 SST2 Gateway DNP3.0 H162H162H162H162H162H162 RSG2100 RSG2100 RSG2100 RSG2100 RSG2100 RSG2100 RSG2100 H162 H162 Gateway IEC/IEC Gateway IEC/IEC Gateway IEC/IEC Gateway IEC/IEC Gateway IEC/IEC Gateway IEC/IEC Gateway IEC/IEC RSG2100 HMI HMI HMI HMI HMI HMI HMI Central PC To Industrial Data Network (Remote access for Engineering) Gateway DNP3.0 Gateway DNP3.0 To DNP3.0 SCADA (Main) - 230kV To DNP3.0 SCADA (Secondary) - 230kV To DNP3.0 SCADA (Main) - 500kV To DNP3.0 SCADA (Secondary) - 500kV 12,47 kV HMI
  12. 12. 12DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 ● Time synchronization via GPS, broadcasted using SNTP ● System compliant with NERC-CIP Standards ● Distributed Logics & interlocks, Control Uniqueness in a per VL basis. ● Synchro-check function integrated in Bay Controller ● Future expansion consideration (actually 40% of final project) System Characteristics Redundancy notion at all levels: • Acquisition: bay controllers and protective relays • IEC61850 network: SE Dual homing + RSTP • Different Point-of-Control at different levels • SCADA, redundant DNP3.0 link per voltage level
  13. 13. 13DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 SAS Architecture LEGEND C264 or Bay controller IED (Protection Relay) Ethernet Switch Ruggedcom RSG2100 Gateway A300 (IEC/IEC or DNP 3.0) HMI (Pacis OI Server & Client Or Pacis Engineering Workstation) Ethernet Switch MiCOM H36x GPS SNTP (Not provided by Areva T&D)
  14. 14. 14DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 • C264: Bay Controller • RED 670 Line Protection • SEL 487E: Transformer Diff Relay • SEL487B: Busbar Protection Relay • SEL421: Line Protection Relay • GE D90+: Line Protection Relay • SEL451: Stand Alone Protection Relay (cap Bank) • P991: Test Block • P992: Multi Finger Plug • MVAJ105: Hand and electrical reset trip relay • C264: Bay Controller • P546: Universal Line Protection for Breaker and Half application, with current diff and sub-cycle distance elements • P643: Transformer or Reactor Protection • P746: Busbar protection for 8 feeders • P143: Feeder Management Relay • P991: Test Block • P992: Multi Finger Plug • MVAJ105: Hand and electrical reset trip relay Third Party products: • TAPCON 260: voltage regulator from MR Rheinhausen • TESLA 3000 from ERLPhase • RSG2100/2200: Ruggedcom Switch • ION 7650: Revenue Metering from Schneider Primary Protection Backup Protection Interoperability
  15. 15. 15DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 230 kV Protection System
  16. 16. 16DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 230 kV, SLD, CT & PT and Protection Zones 52-16F 52-15F 52-14F 52-13F 52-17F 52-18F 52-19F 52-20F 52-12F 52-11F 52-10F 52-09F 52-5F 52-6F 52-7F 52-8F 230kV Bus B1 230kV Bus A1 52-41F 52-24F 52-23F 52-22F 52-21F BAY 2 BAY 3 BAY 4 BAY 9 BAY 10 50:5 50:5 230kV Bus A2 M32R M33R M86V M87V Bank T71 52- 121L 52- 221L 12.47kV 12.47kV 52-16F 52-15F 52-14F 52-13F 52-17F 52-18F 52-19F 52-20F 52-12F 52-11F 52-10F 52-09F 52-5F 52-6F 52-7F 52-8F 230kV Bus B1 230kV Bus A1 52-41F 52-24F 52-23F 52-22F 52-21F 11T87A/SST2 11L21A/L18F 11L21A/L22F 11L87A/L15F 11L87A/L9F 11T87A/SST1 3 1 31 3 3 3 3 3 3 3 3 3 3 BAY 2 BAY 3 BAY 4 BAY 9 BAY 10 600:5 50:5 4000:5 4000:5 11B87A/SST1 V-18F V-22F 4000:5 4000:5 4000:5 4000:5 4000:5 600:5 50:5 4000:5 4000:5 4000:5 230kV Bus A2 M32R M33R M86V M87V Bank T71 11B87A/SST2 4000:5 1 3 52- 121L 3 1 3 52- 221L 12.47kV 12.47kV T71A 3 11B87A/B1F 11B87A/A1F 11B87A/A2F 52-16F 52-15F 52-14F 52-13F 52-17F 52-18F 52-19F 52-20F 52-12F 52-11F 52-10F 52-09F 52-5F 52-6F 52-7F 52-8F 230kV Bus A1 52-41F 52-24F 52-23F 52-22F 52-21F 11T87A/SST2 11L21A/L18F 11L21A/L22F 11L87A/L15F 11L87A/L9F 11T87A/SST1 3 BAY 2 BAY 3 BAY 4 BAY 9 BAY 10 600:5 50:5 11B87A/SST1 4000:5 600:5 50:5 230kV Bus A2 M32R M33R Bank T71 11B87A/SST2 4000:5 52- 121L 52- 221L 12.47kV 12.47kV T71A 11B87A/B1F 11B87A/A1F 11B87A/A2F M87VM86V 230kV Bus B1
  17. 17. 17DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Bay 2 Actual Protection Scheme (Phase 1)
  18. 18. 18DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Bay 2 Protection Scheme (Expansion)
  19. 19. 19DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 12 kV Protection System
  20. 20. 20DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Actual 12.47kV SLD/Protection System
  21. 21. 21DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 12.47kV Protection system specification. ● Customer requirements. ● Highly segmented BB. ● Conventional functions: 50/51, 51/51N, 50BF. ● Customer asked: What can we do to clear Bus faults without using conventional BB protections (costly at this voltage level) or partial BB protection? ● Basic design study. ● After studding the problem and cost restriction we chose the implementation of BB protection with blocking scheme. The blocking is performed by means of Goose messages allowing us a fault clearance time of 50-55ms and an appropriate selectivity.
  22. 22. 22DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 BB Blocking Scheme, fed from SST1 52-106F 52-109F 52-115F 52-122F 52-121F 11F/121L 11F/106L 11F/109L 11F/115L 11F/122L FW FW 52-215F 52-209F 52-206F 52-222F 52-221F11F/221L 11F/215L 11F/209L 11F/206L 11F/222L FWFW 52- 8F 52- 7F A1 B1 52- 18F 52- 17F A2 B1 11T87A/ SST1 11T87A/ SST2 50/51 BLk BLkBLk 50BF 11B87A /SST1 50/51 BLk BLk BLk BLk 50BF 50BF 50BF 50BF 50BF 50BF BLk 50BF 50BF IEDProtection Relay 50BF Goose Blocking GooseWired Trip Wired BF
  23. 23. 23DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Testing in a IEC61850 Environment ● Customer requiremets. ● Physical blockage of goose messages by means of test switch. ● Indication to the Control system that a specific relay is under test. ● Ability to Block subscribed messages in the relay under test. ● Ability to block published message at the subscriber level. DDB #064 En. Subs. Goose DDB #065 En. Pub. Goose DDB #1888 Virtual Output01 DDB #1889 Virtual Output02 Allow Goose Messages from this relay to enter the logic of the other relays Inputs for TEST MODE Under Test & DDB #205 I>3 Timer Block DDB #210 IN1>3 Timer Blk DDB #834 Virtual Input 3 DDB #835 Virtual Input 4 DDB #034 BLK I>3 frm 106L DDB #035 BLK I>3 frm 109L DDB #832 Virtual Input 1 DDB #833 Virtual Input 2 & & Blk I>3 from106L Allow Gosse from106L Blk I>3 from109L Allow Gosse from109L 1 Bus Bar Blocking Scheme 1 2 TST(Blk I>3 from 106L) &DDB #851 Virtual Input 20 DDB #852 Virtual Input 21 TST(Blk I>3 from 109L) & DDB #032 Sub Goose Enable
  24. 24. 24DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Conclusion ● More than one thousand signals involved in protection schemes and system control implemented in IEC61850 with GOOSE and reports messages for the three voltage levels. ● Significant reduction in wiring between panels and buildings, that lowers the risk of bad connections. ● In a traditional wired substation inter-wire faults are detected once the functionality is not available. In IEC61850 substations FO faults are signaled immediately avoiding potential malfunctions. ● The usage of IEC61850 allowed MH to engineer substation expansions without inter wiring complications. This minimizes down time and potential wiring errors. Substation upgrades may be securely tested in an emulated environment. ● Improved system reliability due to the use of: ● System A & B protection relays. ● Protective relay with dual redundant fiber ports fitted. ● Dual Homing mechanism with 0 changeover time. ● Dual ring switches with eRSTP protocol .
  25. 25. 25DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015 Thanks for your attention Daniel Boucher, Utility Segment Manager Dan.Boucher@schneider-electric.com Schneider Electric, North America Operations Claudio Rimada, Senior Engineering Manager claudio.rimada@schneider-electric.com Schneider Electric, EAC-NAM

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