Industry Advisory Generator Governor Frequency Response Troy Blalock South Carolina Electric and GasBob Cummings NERC Reliability Initiatives and System AnalysisRich Bauer NERC Reliability Risk Manage ID: 886599
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1 Frequency Response Initiative Industry A
Frequency Response Initiative Industry Advisory – Generator Governor Frequency Response Troy Blalock – South Carolina Electric and Gas Bob Cummings – NERC Reliability Initiatives and System Analysis Rich Bauer – NERC Reliability Risk
2 Management April 7, 2015 RELIABILITY
Management April 7, 2015 RELIABILITY | ACCOUNTABILITY 2 Agenda • Why Primary Frequency Response is important • Define Primary Frequency Response • Discuss the NERC Advisory Generator Governor Frequency • Recommendations for Dead Band an
3 d Droop • Coordination Requirement wit
d Droop • Coordination Requirement with Plant DCS • Step vs. Linear Response • Frequent Occurring Issues • Questions RELIABILITY | ACCOUNTABILITY 3 • Essential for Reliability of the Interconnections Cornerstone for system stability
4 Line of defense to prevent Under Fre
Line of defense to prevent Under Frequency Load Shedding(UFLS) Prevent equipment damage • Essential for System Restoration Droop response is critical in restoration efforts • Compliance with NERC Standards BAL - 003 - 1, BAL - 001
5 prevent future regulations related
prevent future regulations related to generator frequency response performance • To accurately predict system events ( Transmission Models) Why Primary Frequency Response Is Important RELIABILITY | ACCOUNTABILITY 4 Frequency 4 RELIABILITY
6 | ACCOUNTABILITY 5 • Primary Frequenc
| ACCOUNTABILITY 5 • Primary Frequency Response are actions to arrest and stabilize frequency in response to frequency deviations. Primary Response comes from generator governor response, load response (motors) and other devices that pr
7 ovide immediate response based on local
ovide immediate response based on local (device - level) control. • Generator Governor Response within 0 - 10 seconds.. Primary Frequency Response 5 Frequency Point A is the frequency prior to the event Frequency Point C is the nadir or lowe
8 st point Frequency Point B is the settl
st point Frequency Point B is the settling frequency RELIABILITY | ACCOUNTABILITY 6 Classic Frequency Excursion Recovery RELIABILITY | ACCOUNTABILITY 7 Primary Frequency Response Generator turbine governors either mechanically or electronically
9 control the primary control valves to
control the primary control valves to the turbine. Steam, Water or Fuel is what is regulated. Graphic from GE info bulletin PSIB20150212 Generator Response RELIABILITY | ACCOUNTABILITY 8 Current Interconnection Profiles RELIABILITY | ACCOUNTA
10 BILITY 9 Current Interconnection Profile
BILITY 9 Current Interconnection Profiles RELIABILITY | ACCOUNTABILITY 10 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 MW / 0.1 Hz Year Eastern Interconnection Mean Primary Frequency Response * * 1999 Data Interpolated Source 1994 - 2009:
11 J. Ingleson & E. Allen, "Tracking the
J. Ingleson & E. Allen, "Tracking the Eastern Interconnection Frequency Governing Characteristic" presented at 2010 IEEE PES. Source 2010 - 2011: Daily Automated Reliability Reports * * 1999 Data Interpolated Source 1994 - 2009: J. Ingleson &
12 E. Allen, "Tracking the Eastern Interc
E. Allen, "Tracking the Eastern Interconnection Frequency Governing Characteristic" presented at 2010 IEEE PES. Source 2010 - 2011: Daily Automated Reliability Reports Decline in Eastern Interconnection Frequency Response RELIABILITY | ACCO
13 UNTABILITY 11 Current Eastern Interconne
UNTABILITY 11 Current Eastern Interconnection Frequency Response RELIABILITY | ACCOUNTABILITY 12 Generator Governor Frequency Response Advisory • Advisory issued February 5th • Prompted by NERC Resource Subcommittee Interconnections fr
14 equency response has declined Easte
equency response has declined Eastern Interconnection Lazy L profile 2010 and 2013 Generator Survey Data Generator Governor Frequency Response Advisory RELIABILITY | ACCOUNTABILITY 13 Graphic from GE info bulletin PSIB20150212 What Has
15 Been Learned • Primary Frequency Res
Been Learned • Primary Frequency Response logic typically resides in the turbine controls . • Dead Bands Vary Many exceed 36 mHz or 2.16 RPM • Droops Settings Vary Majority Droops reported 5% RELIABILITY | ACCOUNTABILITY
16 14 Graphic from GE info bulletin PSIB201
14 Graphic from GE info bulletin PSIB20150212 • Coordination with plant DCS is a requirement when operating in MW Set Point Coordinated Control. What Has Been Learned RELIABILITY | ACCOUNTABILITY 15 Frequency 60.000 Hz 400 MW 150 MW 150 MW 100
17 MW Graphic from GE info bulletin PSIB201
MW Graphic from GE info bulletin PSIB20150212 Example RELIABILITY | ACCOUNTABILITY 16 Frequency 59.940 Hz Graphic from GE info bulletin PSIB20150212 400 MW 153 MW for little more than 1 second 100 MW +/ - Dead Band MW 153 MW for little more than 1
18 second Missing Example RELIABILITY | AC
second Missing Example RELIABILITY | ACCOUNTABILITY 17 Frequency 59.940 Hz 400 MW 153 MW 100 MW +/ - Dead Band MW 153 MW 406 MW 6 MW Graphic from GE info bulletin PSIB20150212 Example RELIABILITY | ACCOUNTABILITY 18 Frequency 60.000 Hz 400 MW 150
19 MW 150 MW 100 MW 400 MW 0 MW Graphic fr
MW 150 MW 100 MW 400 MW 0 MW Graphic from GE info bulletin PSIB20150212 Example RELIABILITY | ACCOUNTABILITY 19 No Frequency Algorithm in DCS Frequency Algorithm in Plant DCS 3 - 175 MW GE7FA Gas Mark VIe Turbine 3/3/2015 Tale of Two Tales
20 RELIABILITY | ACCOUNTABILITY 20 OR The C
RELIABILITY | ACCOUNTABILITY 20 OR The Code RELIABILITY | ACCOUNTABILITY 21 Graphic from GE info bulletin PSIB20150212 Frequency 59.940 Hz 400 MW 6 MW 406 MW +/ - Dead Band MW 406 MW Conventional Steam Plant RELIABILITY | ACCOUNTABILITY 22 Droop R
21 esponse Step vs. Linear o r Proporti
esponse Step vs. Linear o r Proportional Source: Frequency Response Initiative Report: The Reliability Role of Frequency Response, NERC, Robert Cummings, October 30, 2012 RELIABILITY | ACCOUNTABILITY 23 Droop - Linear Response Source: Frequ
22 ency Response Initiative Report: The Re
ency Response Initiative Report: The Reliability Role of Frequency Response, NERC, Robert Cummings, October 30, 2012 RELIABILITY | ACCOUNTABILITY 24 Event Occurrence • The majority of the Eastern events where frequency declines in excess of
23 36 mHz is when the interconnections ar
36 mHz is when the interconnections are lightly loaded and the majority of generation is dispatch is less than Pmax . Source: MYBA_2015_FRS_FORM_19a_Eastern Interconnection_Final RELIABILITY | ACCOUNTABILITY 25 Other issues • Some units co
24 me out of AGC or MW Set Point Control w
me out of AGC or MW Set Point Control when frequency response is being provided. • Conventional Steam Turbines operating in sliding pressure or turbine following mode • Resolution/quality of speed signal Common Generator Frequency Respon
25 se Issues Combustion Turbine Conventiona
se Issues Combustion Turbine Conventional Steam Unit RELIABILITY | ACCOUNTABILITY 26 “If I provide primary frequency response I will be penalized.” • Interconnection frequency events resulting in deviations below the recommended governor d
26 eadband settings are infrequent (about
eadband settings are infrequent (about 1 / week) • Primary frequency response is a relatively small amount of energy for a short period Typically provided for about 120 seconds Roughly 0.5% of capacity • Tariff provisions vary but t
27 ypically measure dispatch imbalance or d
ypically measure dispatch imbalance or deviation charges based on substantially longer time intervals (on the order of 30 to 60 minutes with a tolerance band of 5 - 10%) • Tariff provisions typically allow for exemptions or recourse if a g
28 enerating resource is subject to imbala
enerating resource is subject to imbalance or deviation charges due to providing frequency response • Contact your Transmission Provider for specific tariff information A Misconception RELIABILITY | ACCOUNTABILITY 27 Fall Outages 2015/ Spring
29 2016 Note: Need to make sure dead bands
2016 Note: Need to make sure dead bands and droop are coordinated to be the same in the Plant DCS as Turbine. • Check and add if necessary Frequency Response Algorithm on Frame Gas Turbines • Check / Adjust Dead Bands and Droops • Che
30 ck Conventional Steam Unit Requested Ne
ck Conventional Steam Unit Requested Next Steps RELIABILITY | ACCOUNTABILITY 28 • NERC Resource Subcommittee • North American Generator Forum www.generatorforum.org • Original Equipment Manufacturers • Industry Trade Associations • Ar
31 chitect /Engineering Firms • Balancing
chitect /Engineering Firms • Balancing Authority Resources RELIABILITY | ACCOUNTABILITY 29 Participating Vendors * - have developed or are developing a related technical guide RELIABILITY | ACCOUNTABILITY 30 RELIABILITY | ACCOUNTABILITY 31 Appe