2016 Fall ITO Stakeholder Meeting. Topics in Operations

Transcription

1 2016 Fall ITO Stakeholder Meeting Topics in Operations 11/17/2016

2 TOP Requirement R1. Each Transmission Operator shall maintain a documented specification for the data necessary for it to perform its Operational Planning Analyses, Real-time monitoring, and Real-time Assessments. The data specification shall include, but not be limited to: Page 2

3 TOP R : A list of data and information needed by the Transmission Operator to support its Operational Planning Analyses, Real-time monitoring, and Real-time Assessments including sub-100 kv data and external network data as deemed necessary by the Transmission Operator. Page 3

4 TOP R1.1 Operational Planning 1.1: A list of data and information needed by the Transmission Operator to support its Operational Planning Analyses, Real-time monitoring, and Real-time Assessments including sub-100 kv data and external network data as deemed necessary by the Transmission Operator. Data ID Data Description Timeframe Periodicity Method of Data Data Format Exchange 1-1 Expected generator Day ahead / as outage / de-rate data for available next day 1-2 Expected generation Day ahead / as output levels for next day available 1-3 Expected transmission outage data for next day (BES) 1-4 Hourly system load forecast for next day (BA specific) 1-5 Hourly scheduled interchange for next day (BA specific) 1-6 Expected transmission rating changes on tielines with LG&E and KU 1-7 System topology changes (BES) Day ahead / as available Day ahead / as available Day ahead / as available Without intentional time delay Without intentional time delay Daily NERC SDX NERC SDX Neighboring TOPs Daily NERC SDX NERC SDX Neighboring TOPs Daily NERC SDX NERC SDX Neighboring TOPs Daily NERC SDX NERC SDX Neighboring TOPs, LSEs Daily NERC SDX NERC SDX Neighboring TOPs, LSEs On occurance / spreadsheet Monthly or on occurance / spreadsheet LG&E and KU Data Provider(s) Applicability Neighboring TOs/TOPs Neighboring TOs/TOPs Balancing Authority Transmission Operator Balancing Authority Transmission Operator Balancing Authority Transmission Operator Balancing Authority Balancing Authority Transmission Operator Transmission Operator Page 4

5 TOP R1.1 Real-time Monitoring & Assessments 1.1: A list of data and information needed by the Transmission Operator to support its Operational Planning Analyses, Real-time monitoring, and Real-time Assessments including sub-100 kv data and external network data as deemed necessary by the Transmission Operator. Data Description Periodicity Data Format Method of Exchange Data Provider(s) LG&E and KU Applicability Generator Output (Gross & Net) ICCP, RTU scan rate MW & MVAR ICCP, RTU LG&E and KU GO/GOP and neighboring GOs/GOPs (LSE KMPA??) BA & TOP Generator Capability (Pmax or derated Pmax) On Occurance MW Voice Communication GOs/GOPs in the LG&E/KU BA Area BA & TOP Transmission Line Flows (BES) 1 ICCP, RTU scan rate MW & MVAR ICCP, RTU Neighboring TOPs BA & TOP Transmission Line Flows (Non-BES) 1 ICCP, RTU scan rate MW & MVAR ICCP, RTU Neighboring TOPs BA & TOP Transformer Flows (BES) 1 ICCP, RTU scan rate MW & MVAR ICCP, RTU Neighboring TOPs BA & TOP Transformer Flows (Non-BES) 1 ICCP, RTU scan rate MW & MVAR ICCP, RTU Neighboring TOPs BA & TOP Bus Voltages (BES) 2 ICCP, RTU scan rate kv ICCP, RTU Neighboring TOPs BA & TOP Bus Voltages (Non-BES) 2 ICCP, RTU scan rate kv ICCP, RTU Neighboring TOPs TOP Line Voltages (BES) as available 2 ICCP, RTU scan rate kv ICCP, RTU Neighboring TOPs TOP Breaker / Switch Status (BES) 2 ICCP, RTU scan rate Status ICCP, RTU LG&E and KU GOP, Neighboring TOP's and TOP GOs/GOPs (gen breaker) Breaker / Switch Status (Non-BES) 2 ICCP, RTU scan rate Status ICCP, RTU LG&E and KU GOP, Neighboring TOP's and GOs/GOPs (gen breaker) TOP LSE load ICCP, RTU scan rate MW & MVAR ICCP, RTU LSE's within the BA area and neighboring LSE's (BREC, EKPC, etc.) TOP Protection System and Special Protection On Occurance / or Voice Neighboring TOs/TOPs, LG&E and KU TO BA & TOP System status changes spreadsheet Communicaitons MISO Dispatch Flow ICCP, RTU scan rate MW ICCP TVA RC TOP AVR Status ICCP, RTU scan rate Status ICCP, RTU GOs/GOPs in the LG&E/KU BA Area TOP Page 5

6 TOP R : Provision for notification of current Protection System and Special Protection System status or degradation that impacts system reliability Data ID Data Description Timeframe Periodicity Data Format Method of Data Exchange 1-8 System modeling Without On occurrence / parameter (resistance, intentional spreadsheet reactance, charging time delay susceptance) changes (BES) 1-9 Protection System and Special Protection System status changes Without intentional time delay On occurrence / spreadsheet or Voice Communications Data Provider(s) Neighboring TOs/TOPs Neighboring TOs/TOPs, GOs/GOPs, LG&E/KU TO LG&E and KU Applicability Transmission Operator Transmission Operator Page 6

7 TOP R : A periodicity for providing data. Data ID Data Description Periodicity 1-1 Expected generator outage / de-rate data for next day Daily 1-2 Expected generation output levels for next Daily day 1-3 Expected transmission outage data for Daily next day (BES) 1-4 Hourly system load forecast for next day (BA specific) Daily 1-5 Hourly scheduled interchange for next day Daily (BA specific) 1-6 Expected transmission rating changes on On occurrence tie-lines with LG&E and KU 1-7 System topology changes (BES) Monthly or on occurrence 1-8 System modeling parameter (resistance, On occurrence reactance, charging susceptance) changes (BES) 1-9 Protection System and Special Protection System status changes On occurrence All of the Real-Time monitoring should be delivered on occurrence if not on a periodicity of ICCP/RTU scan rate Page 7

8 TOP R2.1 R2. Each Balancing Authority shall maintain a documented specification for the data necessary for it to perform its analysis functions and Realtime monitoring. The data specification shall include, but not be limited to: Data ID Data Description 3-1 Hourly system load forecast for next day (BA specific) 3-2 Hourly scheduled interchange for next day (BA specific) Timeframe PeriodData Preferred icity Format Day Ahead Daily NERC SDX Day Ahead Daily NERC SDX Method of Exchange NERC SDX NERC SDX Data Provider(s) Neighboring TOPs, LSEs Neighboring TOPs, LSEs LG&E and KU Applicability Balancing Authority Balancing Authority Page 8

9 Entities this is Applicable to BA s MISO (LBA s) PJM (Zones) TVA TOP s BREC SIGE DEI OVEC EEI LSE s HE KMPA Benham LGE/KU EEI OVEC PJM (EKPC, AEP, DEOK) OMU TVA HE LGE/KU Paris OMU BREC Page 9

10 Entities this is Applicable to continued GO/GOP s OMU LGE/KU EKPC DP s PPS/PEPB LGE/KU OMU EKPC HE TVA BREC Paris Page 10

11 When this goes into effect? LG&E/KU to be compliant must have a data spec sheet in place by January 1, This includes sending it out to all prospective entities. All applicable entities must comply with data spec sheets by April 1, Page 11

12 Formality Discussion It has been observed that all entities are currently in compliance with the one exception being the departing municipals where it is not yet applicable. Page 12

13 Questions Page 13

14 2016/17 Winter Assessment Troy Fortwengler October 4, 2016

15 Introduction A seasonal assessment study is performed prior to the summer and winter (peak) seasons to identify potential issues that could occur in operations during the seasonal peaks. Mitigations are developed for potential issues and operating guides are developed as necessary and reviewed by the TVA RC. Page 15

16 Study Methodology Study performed on 4 models 2016 /17 Winter 50/50 model (6412 MW LG&E/KU) 2016 /17 Winter 90/10 model (6947 MW LG&E/KU) 2016/17 Winter 90/10 model with 2500 MW South to North Transfer 2016/17 Winter 90/10 model with 3000 MW North to South Transfer Expected operating conditions over peak taken into consideration Ghent Owen County Tap 138 kv outage (8 hour return window) Real-time (normal) and post-contingent (emergency) limits monitored All N-1 breaker to breaker contingencies were simulated Voltage and MVA violations screened MVA loading in excess of 98% of emergency rating reported for BES facilities MVA loading in excess of 100% of emergency rating reported for non-bes facilities 53 different generation dispatch scenarios simulated on top of each breaker to breaker contingency Dispatch scenarios consider most significant generator outage at each plant with several different replacement options Page 16

17 2016/17 Winter Assessment Results (BASE) No Base Case BES or non-bes voltage issues identified on LG&E/KU facilities Three LKE base case constraints were identified. Facility Contingency Dispatch max PU Carrollton - Metal + Thermit 69 kv Clay Village Tap - Clay Village 69 kv Garrard CT - Lancaster KU 69 kv None None None Rate (MVA) Flows (MVA) Mitigation/Notes 2016W W Outages 2016W W Outages 2016W Outages + ORCA SN 2016W Outages + ORCA NS Base Dispatch br3_lv_tc_m iso Base Dispatch Limits were only exceed in the 90/10 and transfer cases Mitigation identified for each constraint There is no issue with Ghent - Owen County Tap 138 kv in service. Return the line to service if the week-ahead study process indicates potential issues. There is no issue with Ghent - Owen County Tap 138 kv in service. Return the line to service if the week-ahead study process indicates potential issues. Close N.O. switch and open switch at Stanford. Page 17

18 N-1 Results (BES) 15 BES thermal constraints identified 8 Constraints Due to Ghent Owen County Tap 138 kv Outage (Return Line to Service) Adams Innovation 138 kv (flo) Adams Tyrone 138 kv Adams Tyrone 138 kv (flo) Haefling Innovation 138 kv Carrollton Lockport 138 kv (flo) Ghent West Frankfort 138 kv East Frankfort Tyrone 138 kv (flo) Ghent W Lexington Brown North 345 kv East Frankfort West Frankfort 138 kv (flo) Ghent W Lexington Brown N 345 kv Haefling Innovation 138 kv (flo) Adams Tyrone 138 kv Viley Road West Lexington 138 kv (flo) Haefling West Lexington 138 kv West Lexington 345/138 kv (flo) Brown North 345/138 kv Remaining 7 constraints resulted from worst case dispatch scenarios with mitigation achievable through re-dispatch Clifty Creek Trimble County 345 kv (flo) Jefferson Rockport 765 kv Blackbranch Hardinsburg 138 kv (flo) Hardin County 345/138 kv Hardin County 345/138 kv (flo) Brown North Hardin County 345 kv Hardinsburg North Hardin 138 kv (flo) Hardin County 345/138 kv Lake Reba Tap Union City Tap 138 kv (flo) Fawkes KU Fawkes EKPC 138 kv Blue Lick 345/161 kv (flo) Hardin County 345/138 kv Lafollet TN Norris HP 161 kv (TVA) (flo) Phipps Bend Pocket North 500 kv Page 18

19 N-1 Results (BES) 38 BES Voltage Criteria Violations Identified 22 resulting from Ghent Owen County Tap 138 kv outage (Return Line to Service) Of the remaining 16 none were seen at the 50/50 load profile levels If winter peak approaches levels seen in the 90/10 load profile post-contingent load shed may be necessary for the following contingencies: Meredith Leitchfield Ohio County 138 kv Hardin County 345/138 kv Fawkes KU Fawkes EKPC 138 kv Goddard 138/69 kv Page 19

20 N-1 Results (non-bes) 31 non-bes thermal constraints identified 6 resulted from Ghent Owen County Tap 138 kv outage Only 2 were identified using the 50/50 load profile Rodburn 138/69 kv (flo) Rodburn Farmers Spencer Road 138 kv Clay Village Tap Shelbyville East 69 kv (flo) E Frankfort West Frankfort 138 kv + West Frankfort 138/69 kv All constraints but one were able to be mitigated using a mixture of pre-contingent switching and generation re-dispatch No viable mitigation found for Artemus 161/69 kv (flo) KU Park Pineville 69 kv Post-contingent loading 101% Post-contingent load shed may be necessary 234 non-bes voltage criteria constraints identified 119 resulted from Ghent Owen County Tap 138 kv outage None were identified using the 50/50 load profile Most violations were marginal (>.88 p.u.) except for those related to the loss of Hardin County 345/138 kv which saw bus voltages fall as low as.84 p.u. Only identified mitigation is post-contingent load shed Full results available in the distributed report Page 20

21 Winter Assessment Report Distribution The Summer Assessment Report is distributed to the following [per TOP- 002]: Transmission Operations TVA RC Neighboring TOPs Neighboring BAs (subject to confidentiality requirements) Page 21

22 Questions? Page 22