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1. Instructions for Reporting Post Seasonal Data Lines Description Where to obtain the data 1 All Time Summer Peak Demand NERC Morning Report 2 Seasonal Peak Demand Forecast NERC Morning Report 3 Day Ahead Peak Demand Forecast NERC Morning Report 4 Demand Response On Peak Must be gathered 5 Actual Peak Demand NERC Morning Report 6 Total Available Capacity MW Calculated 7 Total Available Controllable Capacity Demand Response MW Must be gathered 8 Total Available Generation MW NERC Morning Report 8a Scheduled Outage MW NERC Morning Report 8b Forced Outage MW NERC Morning Report amp c Generator Derates MW NERC Morning Report 9 Required Reserves MW NERC Morning Report 10 Actual Reserves MW NERC Morning Report 11 Operating Reserve Margin NERC Morning Report RELIABILITY ACCOUNTAB NERC Definitions NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Seasonal MW Value Summer Winter Projected Peak MW Peak value based on RC or Region Hour Hour in which peak is expected to occur In amp ally each RC or Region wil defne the daily net hourly peak as an aggregated hourly or highest instantaneous peak Both Seasonal and Peak will the same within RC or Regional Consngency Reserve requirement in MW for the RC area or ifthe reserve requirement is normally achieved through the a Reser2. PL Tap Mosby en gt city 0 0 0 0 0 0 Presentation 7 CERTS Research Supporting Reliability Performance Standards p NERC Interconnections Frequency Control Performance and Timeline for Frequency Response Standard For NERC Operating Reliability Subcommittee By Carlos Martinez CERTS ASR Little Rock Arkansas November 13 2012 Presentation Outline Timeline for the NERC Frequency Response standard Overview of Interconnections 2008 2012 Frequency Control performance assessment and datasets Eastern interconnection 2012 Frequency Regulation metrics identification and quantification Interconnections 2008 2012 Events Frequency Response metrics statistics Estimated Timeline for NERC Frequency Response Standard Estimated Timeline for NERC Frequency Response Standard Nov6 Nov30 Dec Feb May Aug Nov Dec 2012 2012 2012 2013 2013 2013 2013 2013 Non binding SDT Final NERC NERCFiling FERC Industry Start ballot responseto Pallot Board With FERC NOPER Comments FR Passed public for NOPER Standard comments FERC Order Interconnections 2008 2012 Frequency Control Performance Assessment Study NERC Interconnections 2008 2012 Frequency Control Performance Assessment Interconnections Frequency Control Performance Frequency Frequency Regulation Response Secondary Control Primary Control Preliminary Objecti
3. uy Fort Towson Valliant NC er Valliant Weyco Ne junction City fap cen Broken Bow Tap Midway y 4 South Nas Si m L 2 gt Pas Allene Okay L Wilton dues Lake j Fatterson Detroit Seen ds Sugar nm Springs Fae an Twelfth Street Southeast Texar SPP 5221 Red Willow Mingo 345 kV 9 21 2012 16 35 00 PM 19 21 2012 21 00 00 PM 50 9 26 2012 11 00 00 9 26 2012 7 00 00 SPP 0 0 0 0 0 0 FG 5221 Red Willow Mingo 345 kV Red Willow Mingo 345 kV PTDF is used to maintain voltage on the 115kV system in the 5 control area Large North to South flows requires large amounts of reactive power at the Mingo substation where there is little reactive resources causing low voltage on surrounding 115 kV system The normal limit is 717 MW but for this situation we run it at under 600 MW ospr FG 5221 Red Willow Mingo 345 kV Bird City Driftwood Creek co McDonald q Ross Beach QKanarado Grinnell FG 6030 Nebraska City Cooper 345 kV 10 24 2012 11 45 00 PM 10 25 2012 5 00 00 AM sb 10 25 2012 3 25 00 PM 10 26 2012 12 45 00 AM 10 29 2012 1 00 00 AM 10 29 2012 8 00 00 AM SPP Used to control heavy No
4. Once NASPI registry is available this tool is to be retired Initial effort to scope effort was delayed in 2011 MIS PMU Real Time data transfer using NERCNet Currently no available network for RCs to exchanged Synchrophasor data design is available but no implementation the near uture MISO is seeing 3 6 seconds latency using internet Want to leverage existing NERCNet infrastructure for PMU data transfer Minimal cost to add this capability Actual usage costs will be assigned to RCs using capability not intended to be a socialized cost MISO s WAN currently supports ICCP and PMU traffic with no issues approximately 150 PMUs Additional bandwidth required MIS PMU Real Time data transfer using NERCNet continued MISO requested approval for test from TWG TWG approved initial test to validate transfer of PMU data Test will be coordinated with all RC control rooms thru TWG DEWG personnel Initial test will be a single PMU data exchange in each direction MISO requested approval for test from TWG TWG approved initial test to validate transfer of PMU data Test will be coordinated with all RC control rooms thru TWG DEWG personnel MIS T PMU Real Time data transfer using NERCNet continued MISO and NYISO are working on plans to perform this test in two phases short and extended durations Initial confusion on test as DEWG chairman wasn t aware of the two phase requ
5. P e T FTL amp Long Term Alarms Short Term Alarms Through October 29 2012 Only Eastern Decreased Increased Western No Change Increased ERCOT Decreased Decreased Page 6 N R 1142 E Electric Power Group Eastern Interconnections Frequency Deviation Epsilon 2005 to 2012 estem Frequency Epsilon Per Month Eastern Frequency Epsilon Per Hour Type mHz 12 13 1141017 miz EE 18 to 21 mHz IN 22 10 25 mH Page 7 1 1145 1 3 Electric Power Group Western Interconnections Frequency Deviation Epsilon 2005 to 2012 zHui edAL 194 x 5 2 5 3 2 5 z 2 8 z 0 194 d L 2 13 mHz 14 to 18 mHz 19 tc 24 mHz Page 8 1142 NERC E Electric Power Group CERTS ERCOT Interconnections Frequency Deviation Epsilon 2006 to 2012 28024 2023 21 to 2002 18 10 20 1819 17 10 18 _ 14 15 121013 11112 100011 5 5010 8109 708 6107 5106 4105 dio4 2103 112 Got Hout 072 20 mH E121 1 25 26 10 30 NU 31 43 mz No data in January 2011 Page 9 3 Electric Power Group ee Any questions regardi
6. ps A E a Sar pe 82000 EA 1000 x 2008 2010 2011 2012 datetimelocal Western 2009 2012 Frequency Response Statistics freqresp 3000 4 dus ENT a TCL ERCOT 2009 2012 Frequency Response Statistics fi 5000 4000 3000 82000 us pair a T o 2009 2010 011 2012 hours 04 3e 04 0 00 0 2000 000 freqresp 5000 NERC INTERCONNECTIONS 2011 TYPICAL EVENT FREQUENCY PATTERNS USING THE MEAN OF THE SAME SECOND OF EACH RS FWG SELECTED EVENT Revision 09 26 12 59 90 16 QUESTIONS Interchange Distribution Calculator Working Group IDCWG Update NERC ORS Yasser Bahbaz IDCWG Chair November 12 2012 H NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION IDCWG Update Meetings Conference Calls IDC Change Order Updates Other Items GTL Update NERC Implemented e CO 328 Intra Hour Tag Curtailments An analysis is being performed to determine if this change order is sufficient to handle the 15 Minute Scheduling correctly e CO 346 TLR Auto Acknowledgment IDC is now setup such that each sink impacted Reliability Coordinator can set up to automatically acknowledge the TLR actions based on configurable time intervals a
7. 15 16 17 18 19 20 21 22 23 NA Hours Eastern 2012 Frequency Deviation Metric Pattern and Statistics per Month Type OBSERVATIONS Above 60 22 to 4 Below 60 101018 Most abnormal 16 Most variable 23 ncn fu oo no 111 Eastern 2012 Frequency Deviation SaSPSRSSSRS 1 777177 mb 504 nomo nomo 3 LL 1 4 I pomme I 1 I 4 dm om I I I I I I d I I I I I I EASTERN 2012 FREQUENCY STATISTICS PER HOUR MONTH 1 SECOND DATA Eastern 2012 Frequency OBSERVATIONS Above 60 22 to 4 Below 60 10 to18 j Most abnormal 16 Most variable 7 23 Duration impact Eestem 2012 Frequency W OBSERVATIONS Most abnormal Apr Most variable Jan Feb Mar 11 NERC Interconnections 2009 to 2012 Events Frequency Response Statistics Eastern 2009 2012 Frequency Response Statistics 4000 8200 1000 009 0 1 u hours e 04 4 04 0 00 1000 0 1000 2000 3000 4000 5000 freqresp 4000 5 m 7 4 Vos
8. Operating Practices Subcommittee now retired As a result there are no established criteria for pre identifying IROLs Background SOL Methodology revised early 2012 contains a process the RC uses to determine when an SOL qualifies as an IROL Phase l Phase Il a WECC wide effort to address 19 key issues Establish criteria for pre defined IROLs ORS Discussion Objective To understand how other RCs establish and treat pre defined IROLs ORS Discussion Topics 1 Does the IROL define the point where the system breaks or does it define the point where the system becomes N 1 insecure Is the IROL a number or is it a condition i e a number or set of numbers along with a pre defined set of system conditions Are IROLs generally based on stability issues PV QV analysis transient analysis or something else When establishing IROLs is consideration given to the amount of load lost or at risk ORS Discussion Topics Do IROLs ensure N 1 security or N 1 1 security Is an adjustment period allowed i e if an unexpected contingency occurs that leaves the system in an N 1 insecure state a 30 minute adjustment period is allowed to re position the system back to an N 1 secure state Are pre defined IROLs updated as you get closer to real time Are TPL criteria such as Category C contingencies used for establishing IROLs 1 do IROLs protect against multip
9. 0 Pilot Trend NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION DIFFERENCE IN LOAD FOLLOWING CAPACITY vs WIND SOLAR in MW 1 200 1 104 1 000 800 600 400 200 E DIFFERENCE IN LOAD FOLLOWING CAPACITY vs WIND SOLAR in MW 5 900 10 850 200610 2010 CHANGE In WIND SOLAR In MW 201010 2020 CHANGE In WIND SOLAR In MW RELIABILITY NERC__ 2006 2010 amp 2010 2020 Tables RELIABILITY CORPORATION 12000 10 000 8 000 6 000 4 000 298 m 133 mm 7777 Increase in Summer Load Following Up MW Increase in Summer Load Following Down MW 6 RELIABILITY ACCOUNTABILITY VG Metric Long Term vs Short Term Long Term Metric does not reflect time trends of wind Regulation 5 min is preferred to Load Following 1 hr RS recommended that CPS1 reflects Regulation well e 51 can change because of several factors Capture change in CPS1 only for a change in wind or solar Threshold for change similar to Frequency Event thresholds These events will be similar to Frequency Response Linear regression will calculate the VG metric as the slope 7 RELIABILITY ACCOUNTABILITY NERC NORTH AMERICAN ELECTRIC Regulation is reflected in CPS1 RELIABILITY CORPORATION MW 7 Regulation Hourly Actual Load Schedule 5 Minute Schedule Regu
10. ERC Eastern Interconnection CPS 1 RELIABILITY CORPORATION Eastern Interconnection NERC CONTROL PERFORMANCE STANDARD SURVEY Daily Summary for October 31 2012 ei e10 0 018 0 0057 CPST 51 Violations Unavailable CPS2 Hour Ending Hourly Daily Avg Periods CPS2 Daily Avg 1 00 115 13 2 66 67 2 00 122 73 118 93 1 83 33 75 00 3 00 143 22 127 03 1 83 33 77 78 4 00 126 09 126 79 3 50 00 70 83 5 00 18 35 97 76 6 0 00 56 67 6 00 50 77 89 93 4 33 33 52 78 7 00 124 57 94 88 3 50 00 52 38 8 00 145 86 101 25 2 66 67 54 17 9 00 151 71 106 86 0 100 00 59 26 10 00 126 69 108 84 3 50 00 58 33 11 00 145 35 112 16 1 83 33 60 61 12 00 164 14 116 49 0 100 00 63 89 13 00 163 50 120 11 0 100 00 66 67 14 00 117 94 119 95 3 50 00 65 48 15 00 142 91 121 48 3 50 00 64 44 16 00 122 72 121 56 2 66 67 64 58 17 00 118 84 121 40 2 66 67 64 71 18 00 151 09 123 05 1 83 33 65 74 19 00 165 37 125 28 0 100 00 67 54 20 00 149 39 126 48 0 100 00 69 17 21 00 145 24 127 38 1 83 33 69 84 2200 129 86 127 49 1 83 33 70 45 23 00 135 07 127 82 1 83 33 71 01 0 00 109 98 127 08 2 66 67 70 83 127 08 42 0 70 83 RELIABILITY ACCOUNTAB Presentation 4 a Applications Status Update NERC Applications Status For Operating Reliability Subcommittee Little Rock AR November 13 14 2012 Gil Tam NC E Electric Power Group 2 CERTS
11. Electric Power Group Pa p NERC Agenda NERC Application Status Summary The IA RA and ARR applications were unavailable from 10 29 11 4 due to damage to Verizon s cable as result of Hurricane Sandy Inadvertent Data Entry Website Implementation NERC Application Access Central Webpage Intelligent Alarms and Epsilon Summary and Trends ERTS 3 Electric Power Group NERC Applications Status Summary Application NERC Applications Status and Authorized Users Many companies have several authorized users Resource Adequacy ACE Frequency Release 7 0 Current Production version 170 authorized users Inadvertent Release 3 5 Current Production version 272 authorized users New website design to resolve existing application interface with Window 7 is near completion EPG and NERC are working to install and test website and target for completion by November details on following slide Area Interchange Error AIE Release 1 0 Current production version 122 authorized users Intelligent Alarms Release 1 0 Current production version 138 authorized users Frequency Monitoring and Analysis FMA Release 2 5 Current production version 118 authorized users iAutomated Reliability Reports ARR Release 1 0 Current production version 63 authorized users Monthly reports through October 2012 and Seasonal re
12. LIABILITY CORPORATION RELIABILITY ACCOUNTABILITY Presentation 6 SPP Reliability PTDF Report November 13 14 2012 Robert Rhodes rrhodes spp org 501 614 3241 a Power Pool 0 0 0 0 0 0 PTDF Information Statistics from September October 2012 Flowgate Valliant Lydia 345 kV 5220 3 TLRs issued Flowgate Red Willow Mingo 345 kV 5221 2 TLRs issued Flowgate Nebraska City Cooper 345 kV 6030 3 TLRs issued Flowgate Temp 40 latan Stranger Creek 345 kV flo latan St Joseph 345 kV Temp 40 3 TLRs issued esp FG 5220 Valliant Lydia 345 kV 10 25 2012 12 30 00 PM 10 25 2012 1 00 00 PM 3b 10 25 2012 2 00 00 PM 10 25 2012 9 00 00 PM SPP 3 0 0 0 0 0 0 FG 5220 Valliant Lydia 345 kV Used to Control North to South flows 138 kV Outages of Craig Ashdown Craig Broken Bow and Craig Broken Bow Tap caused many Sub Transmission 69kV Contingencies to appear on AEP RTCA for loss of Lydia Valliant 345 kV Controlled FG to 500 MW to alleviate TEMP67_18664 Dequeen Patterson flo Valliant Lydia 345kV built to monitor SPP FG 5220 Valliant Lydia 345 kV ene Creek Bow H gt Dierks p LE i i REC South Dierks Kiamichi Pump Wight Golden Hill Dominance Mt N 20 Kiamichi City oui Mehard aet REE Eagleton 5
13. Presentation 1 Review Data Request for Post 2011 12 and 2012 Summer Assessments Jessica Bian and Matthew Varghese NERC ORS Meeting November 13 14 2012 NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Transition from RAS to PAS Templates for data collection Instructions Definitions 2 RELIABILITY ACCOUNTABILITY Transition from RAS to PAS v RAS transitioned ownership of post seasonal reports to the Performance Analysis Subcommittee PAS RAS willing to continue post seasonal data collection in the near term but strongly recommends operators provide data directly and review the assessment 3 RELIABILITY ACCOUNTABILITY NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Templates for Data Collection ERO 2011 12PS Schedule Demand and Capacity Season LINE DESCRIPTION Activated Deployed Demand Response On Peak Actual Peak Demand Total Available Capacity Line 7 Line 8 Total Available CCDR Controllable Capacity Demand Response Te Te Te Tere Total Available Generation Scheduled Outage 8b Forced Outage Generator Derates Required Reserves MW 10 Actual Reserves MW 11 Operating Reserve Margin Line 9 Line 8 Line 8 NERC Instructions NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION
14. SOL exceeded 100 of the emergency limit Formula SOL Emergency_Rating_Exceedance Number of First Contingency SOL Limit Violations which exceed 100 of emergency limit not acted upon within 35 minutes Quarterly Reports on an aggregate basis by Interconnection Eastern Western ERCOT and Qu bec http www nerc com docs pc rmwg pas metrics Proposed ALR 3 7 docx 4 RELIABILITY ACCOUNTABILITY Presentation 3 Metric Proposals to Measure Reliability I Variable Generation Integration Jessica Bian and Matthew Varghese NERC ORS Meeting November 13 14 2012 gt The Need for a VG Metric Long Term Load following VG Metric Load Following VG Metric Definition amp Calculation Short Term vs Long Term metrics Short Term Regulation VG Metric Regulation VG Metric Definition amp Calculation Background Information CPS1 Definition CPS1 Data for El 2 RELIABILITY ACCOUNTABILITY The need for a VG Metric v VG Metrics measure the supply demand imbalance due to VG VG Metrics quantify change in operating reserves due to VG VG Metrics development recommended by IVGTF Task 1 4 http www nerc com docs pc ivgtf IVGTF Task 1 4 Final pdf 3 RELIABILITY ACCOUNTABILITY VG Metric Long Term Definition v Metric Difference in Load following for 10 years Difference in Wind and Solar for 10 years 4 RELIABILITY ACCOUNTABILITY NERC 2006 2010 amp 2010 202
15. agnetosphere which are causing immense flows of electric current in the upper atmosphere over much of the planet Those huge currents disturb Earth s normally quiescent magnetic field which in turn induces surges of current in electrical telecommunications and other networks across entire continents Streetlights flicker out electricity is lost A massive planetary blackout has occurred leaving vast swaths of North and South America Europe Australia and Asia without power NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION v According to the scenario Based on a projected 5 000 nT min storm large numbers of EHV transformers will fail Since transformers are custom built and not NS RUES sourced domestically recovery could take years si as af probable pawer sestom cellae Source Peter Warner Storm Analysis Consultants Msp John MacNeill NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Magnetosphere K gt gt Energetic Charged Particles SS Heliosphere Ionosphere NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Solar Flare CME Interaction with Earth s Magnetic Field Maxwell Eq amp Earth Cond Model Grid Model m GIC NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION STEREO Behind STEREO spacecraft orbit generally
16. along the Earth s orbit path SOHO and ACE are about 7 million mites 1 6 km towards the sun from Earth at the Lagrangian Point L1 SOHO and ACE STEREO ler Relative positions of SOHO 8 both STEREO STEREO spacecraft attained 90 separation on January 24 2009 Diagram not to scale NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION 2012 03 08 21 00 00 Plasma Density 25 EARTH 2 5 8 Radial Velocity km s 1600 EARTH mye STEREO A STEREO B Source WSA Enil Solar Wind Tool NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION GIC flows in lines Transformer half cycle saturation Harmonics Transformer heating P amp C incorrect operation Capacitor bank or SVC Tripping loss or reactive support Generator overheating and tripping Can lead to voltage collapse and blackout v Reactive power loss Voltage control limits contingency management Voltage and angle stability NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION NERC NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION v e Most likely result from a severe GMD is the need to maintain voltage stability to avoid voltage coll
17. apse and blackout Major Conclusion Major System operators and planners need Conclusion tools to maintain reactive power supply Some transformers may be damaged or lose remaining life depending on design and current health Major Conclusion v Task Teams working on the following Team 1 Vulnerability Assessment Team 2 Equipment Modeling Team 3 GIC Modeling Team 4 System Operating Practices v Task Team 4 working on the following NERC Alert Review e Operating Procedures Template e Notification Process Operator Training Template v NERC required to e Stage 1 Create a NERC standard s within 90 days to require transmission entities to have operating procedures to deal with GMD e Stage 2 Create a NERC standard s within 6 months to address the need for assessments of the transmission system to identify facilities that are vulnerable to GMD and develop mitigation strategies PJM has operating procedure since shortly after the HQ Blackout in 1989 FERC Stage 1 Req t PJM Transmission Owners have installed Ground Induced Current GIC detectors at a number of facilities and more are on the way e PJM in cooperation with the PJM Planning Committee is working on a proposal to conduct a vulnerability assessment of the PJM system Target completion Second Quarter of 2013 FERC Stage 2 Req t NORTH AMERICA ECTRIC RE
18. ary fails RCs lose data from these sites Prohibits network testing as can t switch sites from one option to the other DEWG committee is asking ORS for direction on requiring this capability MIS Current Efforts DDF Data Definition Files are not being updated on a regular basis Effort has been delayed due to other efforts Efforts underway to correct this issue Starting to review who has submitted updated files in the last quarter starting with 39 qtr 2011 Requirement to submit at least once per every six 6 months MIS DEWG DDF update 2012 2012 2011 3rd 4th qtr 1st 2nd qtr 3rd 4th qtr ALCOA Duke x x x ENTERGY ERCOT N A N A N A N A N A N A FPL HOT IESO ISO NE x x MISO NBSO NERC N A N A N A N A N A N A NYISO x x x PJM SCEG SEPA SOCO x x x SPP x x x TVA x WECC N A N A N A N A N A N A MIS PMU Data Definition Files Version 1 of the PMU data definition file has been approved Contains meta data definition for PMU measurements Couldn t reach consensus on a common naming convention for signal names Effort was tabled until new PMU standards are in production Signal name length goes from 16 to 256 characters Validation tool is available to verify PMU DDF file before submittal to NERC ISN repository NERCISN repository is available for RC modeling groups to access submit DDF files
19. bjects in the WebRegistry prior to the go live and publication of the Registry to IDC e The webRegistry publication for 11 13 2012 was successfully implemented right before 01 00 CST 11 13 2012 in the IDC e Since the implementation of the webRegistry in production until early this morning the IDC has successfully imported into the IDC more than 450 e Tags NERC Web Registry Publication e After the implementation of the webRegistry in IDC TLR activity has been conducted without any major issues reported e OATI reported certain E Tags with missing object IDs Further Inquiry of the impact of this issue is outstanding NERC IDCWG Update GTL Update NERC IDCWG Update IDCWG is working with the BPS to draft a IDC GTL User s Manual The intent is to highlight how the current IDC will change to successfully implement BPS requirements as dictated in the whitepaper This document would serve as complimentary material for the NAESB Executive Committee responsible for the approval of the methodology NERC IDCWG Update Vic Howell Manager Operations Engineering WECC RC Pre Identified IROL Establishment amp Treatment 11 13 2012 ORS Meeting Little Rock AR Background September 8 Blackout Report the WECC RC should recognize that IROLs exist Stems from the June 27 2007 IROL Philosophy letter from
20. equacy RA Application Inadvertent Inadvertent data submission NERC Application Broker Inadvertent Application Installation Instruction Release 3 5 and monitoring Download 4 Download User Guide Area Interchange data submission NERC Application Broker No Installation Requiered Download User Guide Release 1 0 Errors AIE and monitoring AIE Website Download Survey User Guide Intelligent Alarms Short term long term Click here for instructions No Installation Required Alarm Descriptions Not Applicable prolonged and data Email Based Alarms Summary Help quality alarms Automatic Reliability Reports Report Click here for instructions No Installation Required Download ARR Help Release 1 0 ARR Monthly Report Email Based Reports and Report ARR Reports Archive Page 5 NERC CERTS E Electric Power Group I Alarms Summary and Trends 2008 to 2012 FTL High 5 Min EASTERN 60 05Hz WESTERN 60 07 Hz ERCOT 60 09 Hz NERC Intelligent Alarm Type 10 2011 2012 0 1 0 ss ss Ci Short Term Low Short Term High NERC Long Term 1 Minute Delta 1 Minute Delta Intelligent 60 Min EASTERN lt 35 mHz EASTERN gt 35 mHz Alarm Type Average gt 30 mHz WESTERN lt 35 mHz WESTERN gt 35 mHz ERCOT lt 70 mHz Year Interc 2011 2012 2008 2010 2011 2012 2008 2011 2012 Eastern 294 xr 389 248 A 5 s s s To
21. est Resolved during conference call November 13 2012 Phase is currently planned for Thursday November 154 2012 for an eight 8 hour duration Conference bridge to be available during initial test set up Requesting that each RC participate in call from respective control room Test will consist of one PMU in each direction Terminated if any issue is observed or requested by any RC Phase ll is tentatively planned to start Tuesday November 27 2012 for a 30 day duration Test will follow the same procedure as noted above MIS PMU Real Time data transfer using NERCNet Next Steps After sucessful tests DEWG TWG will be asked to approve allowing PMU data on NERCNet ORS to approve does this need to go any other NERC committees MISO has a requirement to use Synchrophasor data in the Control Room need a private network to exchange data Current NERCNet upgrade to MPLS is behind schedule Allows ICCP traffic to have a higher priority More capability to monitor network traffic Approximately 75 of option 2 sites backup are transitioned behind schedule Not sure what timeline is for option 1 sites primary Synchrophasor data is the new tool for control rooms Need network for transmission of this data not Internet If it s not NERCNet then will need to install a new network expensive Need to push industry to have capability for Synchrophasor data MIS
22. fter a new TLR instance NERC Development Testing CO 322 PFV Generation Priority Submissions Will be moved to development once a final methodology is reached at BPS Will be revised as needed CO 330 Authorization of OATI Use of IDC Data for DOE Studies Same Data is being requested for 2011 Not approved by IDCWG Requesting ORS feedback CO 336 Changes to IDC Factor Calculation Timing This will be moved for development if deemed need after an evaluation on the behavior of status changes is completed by IESO and MISO CO 350 Increase the Initial Limit for NNL Relief Provided During TLR Issuance CO 351 Update the Flowgate Display to Show PJM Historic Control Areas NERC Development Testing e CO 352 Various Enhancements to the NNL Re Dispatch Worksheet e CO 354 Sending IDC TLR ID to SPP Via WebData Interface 355 Make Informational Flowgates Selectable in Study TLR Mode NERC Meetings Conf Calls e August 157 16 MISO St Paul October 16t 8 5 17 8 5 BPS Joint Meeting on 17 1 5 November 16 Conference Call January 29th 30th 8 5 OATI Offices in Redwood City NERC DRAFT Evaluation e CO 326 PFV Metrics Maybe revised after a final methodology is reached at BPS e CO 353 PSEC SOCO Dynamic Tags e CO 356 TVA RC Requires all IPPs to be a Pseudo Balancing Au
23. lation Red Shaded Area http www caiso com Documents Integration RenewableResourcesReport pdf PDF Page 87 of 231 RELIABILITY VG Metric Short Term Definition v Metric Difference in successive CPS1 one minute averages Difference in successive Wind amp Solar 1 minute averages Trigger for VG Event produces list Regression will find the slope Difference in successive Wind amp Solar 1 minute averages gt X MW The X MW will be determined similar to Frequency Event Triggers 9 RELIABILITY ACCOUNTABILITY RELIABILITY ACCOUNTABILITY NERC _ CPS1 Definition NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Definition of CPS1 Control Performance Standard 1 ww The CPS1 equation can be simplified as follows CPS1 in percent 100 2 Constant Frequency Error ACE The Scheduled Frequency is 60 Hz except for ATEC Time Error Correction The largest CPS1 achievable is 200 percent This occurs whenever ACE or Frequency Error is zero The size of the Constant is equal to 10 B is the Balancing Authority Bias Special Case When a single Balancing Authority is an Interconnection ACE will always be in phase with Frequency Error The Bias terms will cancel out CPS1 is a function of Frequency Error and Adapted from RS document http www nerc com docs oc rs NERC 20Balancing 20and 20Frequency 20Control 20040520111 pdf RELIABILITY ACCOUNTABILITY N
24. le Facility Contingencies Questions Presentation 10 a A 4 DEWG Status Update wn nd VAN MASS ORS Meeting November 13 2012 DEWG ISN Node Meeting Participation 10 18 2012 7 12 2012 4 19 2012 1 12 2012 10 20 2011 7 14 2011 4 14 2011 1 13 2011 ALCOA Duke X X X X X X X ENTERGY X X X X ERCOT X X FPL X X X HQT X X X X IESO X X X X X X ISO NE X X X X X X X X MISO X X X X X X X X NBSO NERC X X X X X X X X NYISO X X X X X X X X PJM X X X X X X X X SCEG SEPA SOCO X x x x x x SPP x x X X X X X TVA X X X X X X X WECC X X X X MIS Committee Documents Completed review of all DEWG documents Non relevant documents retired Perform yearly review of all active documents MIS NERCNet concerns SaskPower applied for NERCNet extension 15 quarter of 2011 Required due to MISO retiring St Paul servers Effort not completed as of today MISO extended MISO s WAN to SaskPower to facilitate data transfer DEWG is requesting meeting with NERC to discuss this issue along with NERCNet support at upcoming January 2013 meeting Provide an update to ORS once this meeting occurs MIS Discuss NERCNet Option 2 requirement Currently no requirements for RC to have the NERCNet Option 2 backup If Option 1 Prim
25. ng the NERC CERTS applications please contact Gil Tam Tam electricpowergroup com 626 685 2015 Page 10 1142 CERTS E Electric Power Group N E R C Presentation 5 NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION RELIABILITY ACCOUNTABILITY NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION SES Solar Cycle Sunspot Observed data through umber Progression Feb 2012 175 150 125 100 75 50 Sunspot Number TTTT 25 TTTT 9 lt S o QL ok 99 d 59 AV AD 45 4h 59 AD AT AD yor Smoothed Monthly Values Updated 2012 Mar 12 Monthly Values yor Predicted Values Smoothed NOAA SWPC Boulder CO USA NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION epectr rm MAGAZINE MUL e SIDEBAR AEROSPACE BIOMEDICAL COMPUTING CONSUMER ELECTRONICS ENERGY Hundreds of Fukushimas ENERGY THE SMARTER GRID How a massive solar orm could trigger nuclear dap plant meltdowns A Perfect Storm of Planetary Proportions worldwide The approach of the solar maximum is an urgent reminder that power grids everywhere are more vulnerable than ever to geomagnetic effects uu By JOHN KAPPENMAN FEBRUARY 2012 Linked to the celestial spectacle are enormous fluctuations of the magnetic field in Earth s m
26. ontact EPG at 626 685 2015 or via email support electricpowergroup com You can also use this link to contact EPG https www electricpowergroup net contactUs aspx and use the Contact Us form CERTS E Electric Power Group NERC Application Access Central Webpage https www electricpowergroup net NERC To login to our website follow the Click here to login link Use your EPG Username and password to login Electric Power Group Note if you need to retrieve your password or username please click on the Forgot your password or username link in the Login page and follow instructions PRODI SERVI NERC Resources Subcommittee Monitoring Applications Registration Software Access And Installation User Documentation Click here to login to your EPG account to be able to download applications and supporting documents Application Functionality Registration Access install User Guide Version Resource Adequacy RA 30 and 60 Minutes NERC Application Broker Resource Adequacy RA Online Help Release 7 0 Freg ACE Monitor Download Installation Instruction CPS BAAL Monitor Situaltional Awareness Frequency Monitoring Frequency Event NERC Application Broker FMA Application Download User Guide Release 25 and Analysis FMA Frequency Response Download CPS BAAL Tracking Evaluation of CPS BAAL Metrics NERC Application Broker Resource Adequacy RA Online Help Release 7 0 integrated with Resource Download Installation Instruction Ad
27. ports through Summer 2012 have been posted in ARR website ARR website access details on following slide Page 2 1112 NERC ERTS E Electric Power Group New Inadvertent Data Entry Website Implementation EPG has completed software design and sent software to NERC for implementation NERCIT staff is installing software Testing is in progress Target is to complete and deploy in late November 2012 EPG will send notices and user instructions to all authorized users NERC Will Provide Hosting Services Web Address User Security Data Backup User Training EPG will schedule and provide a one hour training session via WebEx Page 3 1142 CERTS E Electric Power Group Page 4 ne NERC ARR Website Access As a subscriber and recipient of the Daily Automatic Reliability Reports you can also access the ARR Monthly Quarterly and Yearly reports as well as the archived Daily reports at the following website https www electricpowergroup net ARR To access the above website use your EPG Username and password to login Note If you do not already have a password or forgot your username or password and need to activate one for the first time please go to the EPG Login Page at https www electricpowergroup net userAccount acctLogin aspx and click on the Forgot your password or username link on This Page and follow instructions If you have any questions please c
28. rth to South flows during an outage of Cooper unit and Cooper Mark Moore 345 kV Used as proxy for FG 18661 Temp 66 Nebraska City Cooper 345 kV flo Fallow Avenue Grimes 345 kV Monitored Element of FG 18661 18661 had not been made Market Coordinated by MISO SPP 1o 0 0 0 0 0 0 FG 6030 Nebraska City Cooper 345 kV SPP FG 17699 Temp 40 latan Stranger Creek 345 kV flo latan St Joseph 345 kV 19 13 2012 14 25 00 9 13 2012 18 30 00 3b 9 20 2012 12 00 00 9 20 2012 14 00 00 PM 19 22 2012 16 00 00 PM 9 22 2012 19 00 00 PM SPP 0 0 0 0 0 0 FG 17699 Temp 40 latan Stranger Creek 345 kV flo latan St Joseph 345 kV Used as proxy to control RTCA contingency Jarbalo 166 St 115 kV flo latan St Joseph 345 kV Contingency showed up due to outage of Stranger Craig 345 kV FG was built the following day Temp 65 latan outlet issue SPP Temp 40 and Temp 65 Bendena Severance N Dearborn e Platte City NW Leavenworth Spruce Johnston Pepe Spruce Jonnston Ist zi SENS w Hallmark Roanridge Lai Line Basehor Maywood West FPE Westb dge Hawthorn
29. thority in the IDC BOF CO 16 PSSE Version Change NERC IDCWG Update Other Items NERC Entergy Transition to MISO e Entergy Transition to MISO Entergy is scheduled to transition and become under MISO RC purview on December 1 t IDCWG MISO and ICTE members will coordinate modeling changes effort for December Model NERC Location of IDC Model Swing Bus e Preliminary Analysis showed that the location of Swing Bus doesn t impact TDF or GLDF calculation e The analysis were fairly thorough however further analysis were requested by members of the IDCWG on other environments of the IDC e IDCWG Documentation SDWT is working to clarify all training documents to clarify how best to use GSF and LSFs provided by the IDC NERC IDC Reference Document IDCWG approved the following recommendation IDCWG proposes that The Flowgate Administration Reference Document Parallel Flow Calculation Procedures Reference Document and Reliability Coordinator Reference Document sections of the NERC Operating Manual sections of the NERC Operating Manual be removed and replaced with a hyperlink to the appropriate document that is posted on the NERC website The appropriate documents would be the IDC User s Manual and SDX User s Manual NERC Web Registry Publication e IDCWG worked with OATI to validate and debug missing o
30. ve Sharing Group Contingency Reserve requirement for he Reserve Sharing Group Projected MW Total anscipated operating reserves available at sme of peak in the RC area or the reporing footprint Normally this would be a daily seasonal assessment number RELIABI ACCOUNTAB Presentation 2 Revised Situation Awareness Metrics Jessica Bian and Matthew Varghese NERC ORS Meeting November 13 14 2012 b d ALR3 6 Unforecasted System Operating Limit Violations ALR3 7 Emergency Rating SOL Exceedances 2 RELIABILITY ACCOUNTABILITY ALR3 6 Unforecasted 5015 During real time daily operation how many first contingency limit exceedances SOLs are identified by TOP or RC during real time operations without day ahead or months ahead identification of the same SOL in the day ahead operations plan Formula Count of SOLs identified during real time operations without day ahead identification of the same SOL in the day ahead operations plan Quarterly Reports on an aggregate basis by Interconnection Eastern Western ERCOT and Qu bec http www nerc com docs pc rmwg pas metrics Proposed ALR 3 6 docx 3 RELIABILITY ACCOUNTABILITY During real time daily operation how many first contingency SOL limit exceedances which exceed 100 of emergency limit are not acted upon no mitigation plan orders issued by the TOP or RC within 35 minutes from the first time the
31. ves Identify performance metrics Quantify performance metrics Impact on reserves Impact on Inadvertent Impact on Time Error Impact of variable generation Impact of Market Products Primary control withdraw Risk assessment Control Standards Adequacy Known Interconnections Historical Datasets 3 4 Interconnection Eastern ERCOT Interconnections Frequency NERC 3 Interconnections Response Events and Parameters RS Applications Frequency Response 1 Min 1 Sec Data q Y P J Ingleson E Allen 1992 2009 S Niemeyer CERTS LBNL 2008 2012 ERCOT T Bilke 1994 2011 Eastern 2002 2008 FERC 2010 2008 2012 Min 1 Se RS FWG Freq Resp Standard Support 4 Interconnections 2008 2012 Frequency Response Events and Parameters Eastern 2012 Frequency Regulation Metrics Identification and Quantification Eastern 2012 Frequency Deviation Metric Pattern and Statistics per Hour Type p p n CT CD pitt L 1 Eastern 2012 Frequency Deviation concn DONON rir irr the OBSERVATIONS Data quality H Hours 14 15 16 2 lt e Hour 7 morning pk SZ prat 2222 4 Duration impact 1 1 1 3 27 4 i i r 1 i 01234567 8 9 1011 12 13 14
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