Operating Reliability Subcommittee Presentations. February 10-11, 2015

Transcription

1 Operating Reliability Subcommittee Presentations February 10-11, 2015

2 Presentation 1 ORS February 10, 2015

3 EInet Transition Efforts All current RC nodes on NERCNet have placed orders for new network EIDSN Technical Committee meeting weekly (includes all EIDSN charter members) EIDSN Technical Committee leadership team is meeting with EInet network vendors Sprint and AT&T Circuit orders being placed Requires dual billing (NERC and EIDSN) 2

4 EInet Transition Efforts (continued) Issue being addressed with Co-Lo sites for network encryption Hub sites not included in original RFP or network design Addition of these sites have been approved by EIDSN board Encryption not available until Co-Lo sites are available Canvassing nodes to determine who is willing to test in this mode Note: Half of current NERCnet is not encrypted Encourage your nodes to allow this testing to proceed 3

5 EInet Transition Efforts (continued) Expecting to start testing network connections in March-April/2015 Current completion date is May/2015 Testing Einet is in parallel to NERCNet 4

6 Issues with Transition NERCNet has the following types of connections: Frame (Option 1) encrypted MPLS (Option 2) not encrypted Verizon originally stated that Frame is to be decommissioned 12/31/2015 Overall driver for completion but EIDSN working towards May/2015 5

7 Issues with Transition (continued) NERC notified DEWG/TWG on December 2 9th, 2014 that Verizon has moved the frame decommission date to June/2015 NERC stated that they were going to decommission the entire NERCNet on this new date Following are the sites on each of the NERCNet options: 6

8 Current NERCNet implementation (option 1) CPL Dominion Duke Ercot FPL IESO ISONE HQ MISO NBPC NERC NYISO PJM SC SCEG SEPA SOCO SPP TVA PEAK Yadkin SAFNR 7

9 Current NERCNet implementation (option 2) CPL Dominion Duke Ercot FPL IESO ISONE HQ MISO NBPC NERC NYISO PJM SC SCEG SEPA SOCO SPP TVA PEAK Yadkin SAFNR Sites in red lose connectivity in June/2015 8

10 Issues with Transition (continued) Critical that option 1 sites get their testing completed Have no other options as Verizon is not responding to requests on NERCNet Majority of RC nodes can communicate on NERCNet after June/2015 DEWG asking ORS to request that NERC not decommission the MPLS network until EInet is completed Let each node determine when to decommission This is a contingency only at this time (not a schedule issue) 9

11 DEWG activities DEWG is still a NERC committee, NOT an EIDSN committee Misconception that DEWG transitioned to EIDSN Based on same path as IDCWG Last scheduled meeting is July/2015 as a wrapup of efforts Based on current EInet completing in May/2015 DEWG developed an activity list for transition Part of the ORS materials Also being sent to EIDSN 10

12 DEWG Activity List Overview Governance of Real-Time Data Exchange Support real-time data requirements and modeling including compliance Technical Matter Experts Support ICCP protocol efforts Support industry vendors Standards committees Coordinate ICCP testing and implementation efforts by RCs Maintain procedures for ICCP and Synchrophasor Outages 11

13 DEWG Activity List Overview (continued) Maintain FTP site for modeling files Vet user access alias for notifications Data repository of meeting minutes and documents Coordinate Synchrophasor updates Owner of national Synchrophasor IDs Own and maintain multiple documents to (eg.): Define maintenance process Data requests Data dictionary Node responsibilities 12

14 DEWG Activity List Overview (continued) Maintain unique registry of ICCP remotes and measurement prefixes Maintain unique registry of Synchrophasor IDs Enforce periodic update of data dictionaries for ICCP and Synchrophasor data Defines modeling data available to be shared with RCs Standard formats 13

15 DEWG concerns Committee wants to emphasize that these functions should continue somewhere Data will continue to flow Inefficient Leads to multiple ad-hoc process, no standards/process Leads to additional work due to no governance 14

16 DEWG concerns (continued) Committee recommends one of the following options: Functions stay at NERC NERC has stated that they expect the DEWG to follow the same path as the IDCWG and the IDC consortium ORS Move group to another committee 15

17 EIDSN DEWG concerns (continued) Exploratory meetings are occurring DEWG chairman discussing concerns with EIDSN Executive Director EIDSN s board would have to approve this expansion Current Technical Committee Charter only has network implementation and associated governance Please let committee know if there is any new direction 16

18 Final This is my last ORS meeting as chairman of DEWG I ve enjoyed working with the ORS I m sure our paths will cross again in the future 17

19 Presentation 2 Project Real-time Monitoring and Analysis Capabilities Mark Olson, Standards Developer Operating Reliability Subcommittee February 10, 2015

20 Purpose Inform the ORS on the status of the project Encourage participation of subject-matter experts in revising the project Standard Authorization Request (SAR) 2 RELIABILITY ACCOUNTABILITY

21 Background Project was initiated in response to work done by the NERC Operating Committee's Real-time Tools Best Practices Task Force (RTBPTF) From 2009 to 2011, a SAR drafting team developed a SAR and technical white paper to establish requirements for the functionality, performance, and maintenance of Real-time Monitoring and Analysis Capabilities. Formal development paused in 2011 Project Page: 3 RELIABILITY ACCOUNTABILITY

22 Background In May 2013, NERC filed revised TOP and IRO Standards Standards did not address directives related to Project FERC concerns with the proposed standards led to rework in Project Revisions to TOP/IRO Standards FERC expressed several concerns, including unresolved directives related to real-time monitoring and analysis capabilities Project addresses FERC issues with exception of realtime monitoring and analysis capabilities 4 RELIABILITY ACCOUNTABILITY

23 Status Project is included in the Reliability Standards Development Plan NERC soliciting nominations for SMEs to replace SAR Drafting Team (SDT) members no longer participating Standards Committee action on February 18 to open the nomination period Purpose: revise the SAR and white paper posted on the project page 5 RELIABILITY ACCOUNTABILITY

24 SAR Revision SDT will review project scope and revise where necessary Project should address recent Industry reports and initiatives Southwest Outage Report Recommendations Independent Experts Review Panel (IERP) Report Address existing directives from FERC Order No. 693 Project should complement proposed TOP and IRO Revisions 6 RELIABILITY ACCOUNTABILITY

25 Project TOP/IRO Revisions Proposed defininition: Real-time Assessment - An evaluation of system conditions using Real-time data to assess existing (pre-contingency) and potential (post-contingency) operating conditions. The assessment shall reflect applicable inputs including, but not limited to: load, generation output levels, known Protection System and Special Protection System status or degradation, Transmission outages, generator outages, Interchange, Facility Ratings, and identified phase angle and equipment limitations. (Real-time Assessment may be provided through internal systems or through third-party services.) Requirements for performing Real-time Assessment are contained in proposed IRO and TOP Requirements for real-time monitoring are contained in proposed IRO and TOP What capabilities should be included in a Reliability Standard to support the proposed TOP and IRO standards? 7 RELIABILITY ACCOUNTABILITY

26 Project Initiation Timeline Reconstitute the SDT: March 2015 SDT nominations in February SAR Revisions and Industry Engagement: April May 2015 Revised SAR to SC in May 8 RELIABILITY ACCOUNTABILITY

27 9 Mark Olson, Standards Developer RELIABILITY ACCOUNTABILITY

28 SPP Reliability: Proxy/EEA Report Presentation 3 February 10, 2015 Don Shipley dshipley@spp.org

29 EEA s: SPP did not have any EEA-3 s during the reporting period. 2

30 Proxy Flowgates for this Period: Statistics from November 1, 2014 February 1, 2015 Flowgate (6007): Gentleman-RedWillow 345kV Flowgate (5221): RedWillow-Mingo 345kV Flowgate (5419): Lydia-Valliant 345kV 3

31 FG 6007 Gentleman-RedWillow 345kV TLR_DATE ReturnToZero TLR_Level 12/31/ :45 01/03/ :00 5

32 FG 6007 Gentleman-RedWillow 345kV Temporary Proxy for: Reducing flows to a level to allow reconfiguration option (RedWillow 1110) to be returned to service due to weather entering area and not cause post contingent loading on the 115kV system once returned Reconfigure option is used to alleviate post contingent voltage and/or thermal issues on the 115kV system around Western Nebraska Western Kansas 5

33 FG 6007 Gentleman-RedWillow 345kV Gentleman - RedWillow 345kV PTDF 115 kv system 6

34 FG 5521 RedWillow-Mingo 345kV TLR_DATE ReturnToZero TLR_Level 12/31/ :20 01/01/ : /02/ :00 01/03/ : /09/ :30 01/09/ : /22/ :30 01/23/ :45 3

35 FG 5221 RedWillow-Mingo 345kV Temporary Proxy for Controlling North South flows across system Maintaining voltage on the 115kV system around Mingo Manage loading on FG 5416 Mingo 345/115 kv FTLO Mingo-Setab 345 kv Manage loading on FG 5526 RedWillow-Mingo 345kV FTLO Axtell-PostRock 345 kv 8

36 FG 5221 RedWillow Mingo 345kV RedWillow- Mingo 345kV PTDF Mingo 345/115 kv Mingo- Setab 345 kv 9

37 FG 5419 Lydia-Valliant 345kV TLR_DATE ReturnToZero TLR_Level 12/09/ :00 12/10/ : /10/ :00 12/11/ :00 5

38 FG 5419 Lydia-Valliant 345kV Temporary Proxy for Scheduled 345kV breaker outage. Valliant 345/138 kv FTLO Valliant-Hugo 345kV Temporary flowgate TMP138_20675 was built to manage flow during scheduled outage due to modeling issues was unsuccessful 11

39 FG 5419 Lydia-Valliant 345kV Hugo Valliant 345 kv Lydia Valliant 345kV PTDF 345 kv breaker outage (Valliant) 12

40 Presentation 4 Event of December 4th 2014 Lost of lines 7044 and 7047 INTERNE

41 HQT Main Transmission System Large generation complex located in the province northern area. 2. Main load centers located in the province southern area. 2. INTERNE

42 HQT Main Transmission System 1. Lost of 2 lines feeding Chénier substation 2. This event reduced considerably the transmission capacity of the South limit (composed of kv lines) INTERNE

43 Projected load and margin before the event The event occurred at the beginning of the evening peak period The margin for operating reserve and the South limit were sufficient but limited 15h05 INTERNE

44 Lost of lines feeding Chénier The event was triggered by the lost of lines 7044 and 7047 The fault was indicated to be at the same localization for both lines INTERNE

45 South limit flow vs limit The power transfer was decreased to respect emergency limit in 25 minutes INTERNE

46 NET Interchange Export Import INTERNE