NERC Standard BAL Frequency Response & Frequency Bias Setting

Transcription

1 NERC Standard BAL Frequency Response & Frequency Bias Setting Danielle Croop Sr. Engineer, Performance Compliance Operating Committee October 4 th

2 Agenda Summary PJM BAL Field Trial Performance System Reliability and Recommended Settings Individual Unit Performance Breakdown Path Forward 2

3 PJM BAL Field Trial Performance Performance is measured as the median of all NERC selected events; frequency response measured included generator governor response, & load response PJM Field Trial Performance exceeded expected FRO every year 3

4 Frequency Response Measure vs Frequency Response Obligation

5 Estimated Primary Frequency Response 2016 Based on 2016 (to-date) BAL-003 frequency response events, the majority of generator frequency response is provided by Coal and Natural Gas units Coal units provide 69% of generator frequency response, Natural Gas units provide 19% Evaluation of frequency response measured as the median response for each unit from the selected events Coal 69% Natural Gas 19% Hydro 3% Wind 3% Other 3% Oil 2% Nuclear 1% Solar 0% Landfill 0% Diesel 0% Fuelcell 0% 5

6 System Reliability Initial Observation From NERC Frequency Response Initiative Report, October Modeling of Frequency Response in the Eastern Interconnection Only 30% of units on-line provide primary frequency response 2/3 of the units that did respond exhibit withdrawal of primary frequency response Only 10% of units on-line sustain primary frequency response Frequency Response in the Eastern Interconnection has improved since October 2012 however still observing many units not providing sustained primary frequency response 6

7 Recommended Settings The Goal: Every BES Generator should have a working governor and be set in accordance with Frequency Response Guideline for system reliability and system restoration and provide primary frequency response with available headroom Recommended settings: 36mHz deadband, 5% droop PJM Manual 14D:...the generator governor and Distributed Control System (DCS) settings provide dead bands that do not exceed +/- 36 mhz, and droop settings that do not exceed 5%

8 System Reliability Primary frequency is essential for reliability of the Interconnection and is the first line of defense critical for system restoration needed for accurate modelling and event analysis necessary for compliance to BAL Observations with current primary frequency response within our footprint large variability from event-to-event basis, many generators not providing FR many generators withdraw FR or respond in the opposite direction significant portion of frequency from load and can not predict the load response or control it 8

9 Variability in Frequency Response Observed Demonstrating the variability Event 12/05/ :31 03/02/ :53:32 Response MW/0.1 Hz MW/0.1Hz Excursion Hz Hz Response from Generation Response in wrong direction -409MW/0.1Hz -157MW/0.1Hz -207MW/0.1Hz -128MW/0.1Hz 9

10 Examples of Individual Unit Performance Response in opposite direction No response Initial response with early withdrawal Some response Expected response 10

11 Response in Opposite Direction

12 No Response

13 Initial Response with Early Withdrawal

14 Some Response

15 Expected Response

16 Path Forward PJM will continue to evaluate event and individual unit performance Monitor event performance for BAL compliance Further refine unit parameters (Pmax, Deadband, Droop) Potential initiatives coming from NERC and FERC PJM engaged with the NERC Resource Subcommittee, NERC Operating Committee and Frequency Response initiatives Further FERC direction from Frequency Response NOI 16

17 Appendix 17

18 Timeline for BAL R1 Requirement 1: Each Balancing Authority shall achieve an annual Frequency Response Measure (FRM) that is equal to or more negative than its Frequency Response Obligation (FRO) BAL R1 becomes effective BA FRO for 2017 posted Event Collection begins for 2017 Event Collection ends for 2017 BA FRM Reporting for 2017 April 2016 Nov 2016 Dec 2016 Nov 2017 March

19 NERC Reliability Standard BAL Balancing Authority FRO Allocation: Interconnection Frequency Response Obligation x Balancing Authority Pro-rata Share PJM FRO for 2016 operating year = (-1015 MW/0.1 Hz) x (25.45%) = MW/0.1Hz 2016 Operating Year : December 2015 November 2016 (field trial) **PJM expected FRO for 2017 operating year = (-1015MW/0.1Hz) x (25.45%) = MW/0.1Hz 2017 Operating Year: December 2016 November 2017 (compliance) **tentative 19

20 Primary Frequency Response Primary frequency response is the first stage of frequency control and is the response of generator governors and loads to arrest locally detected changes in frequency. Primary frequency response is automatic, is not driven by any centralized system, and begins within seconds after the frequency changes, rather than minutes. 20