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1
2014 System Operator Conference
NERC Standards Review for:
Simulator Drill Orientation
2014 System Operator ConferencesCharlotte NC & Franklin TN
SERC/SOS Facilitator Team
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Applicable to:
Events Modeled on the Finist Energy System using the Operator Training Simulator
“OTS FINIST”
Review of NERC Reliability Standards
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Issues You Will See During the Drill:
• MW limit violations; congestion on flowgates
• Out-of-range voltage (high or low)
• Activation of protection systems
• DCS events
• Large deviation from schedule in
• Interconnection frequency
• ACE in the BAs
• Actual Net Interchange
• Need for manual load shed
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At the conclusion of this training, the participant should be able to:
Identify and discuss NERC standards that relate to:
Establishing operating entity reliability responsibilities and authorities
Operating within established SOLs and IROLs; returning from “unknown” emergency state within 30 minutes
Having sufficient reactive resources to maintain voltage schedules; keeping generator units in AVR mode
Learning Objectives
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Identify and discuss NERC standards that relate to:
Knowledge, understanding and coordination of protection systems, including: UVLS, UFLS, SPS
Ability of BAs to balance resources & demand following loss of generation.
Importance of proper communication protocols during system events.
Exercising TOP operator authority to shed firm load when required.
Learning Objectives, cont’d
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NERC Standards review:• TOP-001: Reliability Responsibilities and Authorities
• TOP-004: Transmission Operations
• VAR-001: Voltage and Reactive Control
• VAR-002: Gen. Ops. for Maintaining Network Voltage Schedules
• PRC-001: System Protection Coordination
• PRC-006: UFLS & SERC Regional UFLS Standard
• PRC-010: UVLS
• BAL-002: Disturbance Control Performance
• COM-002: Communications & Coordination
• EOP-003: Load Shedding Plans
Outline of Topics
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TOP-001-1aReliability Responsibilities and
Authorities
Enforcement Date 11/21/2011
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TOP-004-2
R1: Operate within SOL/IROL
R4: Return from unknown operating state within 30 min.
R5: “Cut Loose” if cannot remain interconnected
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VAR-001-4Voltage and Reactive Control
Enforcement Date 10/1/2014
VAR-001-3 will be retired 9/30/2014
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R2: Schedule sufficient reactive resources to regulate voltage levels
VAR-001-4
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R5 sub-requirements: TOP shall provide the GOP with reactive power schedule, AVR control mode, deviation notification, criteria used in schedules.
VAR-001-4
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VAR-002-3Generator Operation for Maintaining
Network Voltage Schedules
Enforcement Date 10/1/2014
VAR-002-2b will be retired: 9/30/2014
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VAR-002-3
R1: GOP must have AVRs in automatic mode**exceptions start-up/shut-down mode. or directed by TOP
R2: GOP must maintain voltage. By alternate method if AVR out, modify voltage as instructed, and have a methodology to monitor voltage
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VAR-002-3
R5 and R6: GO must provide GSU tap settings and assure tap positions are changed per TOP specs
R3 and R4: GOP must notify the TOP of status or other changes in reactive capability within 30 min
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PRC-001-1.1System Protection Coordination
Enforcement Date 4/1/2013
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R4 and R5: coordinate protection systems and any system changes affecting others
R6: Operator Awareness of status of each Special Protection System (SPS )*
Example: In Finist, if any 2 of 3 key lines are out of service and the remaining line trips, SPS kicks in to create an island of balanced load & generation.
*SPS Detects a certain set of conditions and takes action above & beyond the isolation of faulted equipment. also :Remedial Action Scheme (RAS)
PRC-001-1.1
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PRC-006-1
PRC-006-SERC-01Automatic Underfrequency Load
Shedding (UFLS)
Enforcement Date 4/1/2014
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Arrest &
Assist
PRC-006-1
UFLS entities that own, operate or control UFLS equipment
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PRC-006-SERC-01
R2: UFLS scheme: shed at least 30% peak demand, min 3 freq. setpoints, highest 59.3-59.5, lowest 58.4
R4: 10-1-2015 (future enforcement)
R4: If UFLS entity’s total load >100 MW, must implement UFLS developed by PC and must meet requirements, such as; % load shed total and steps, freq. setpoints, etc)
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PRC-010-0Technical Assessment of the Design and Effectiveness of Undervoltage
Load Shedding (UVLS) Program
Enforcement Date 6/18/2007
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PRC-010-0
R1: At least every 5 years TO/TOP must evaluate its UVLS program for coordination, demonstration, and review voltage set points & timing.
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BAL-002-1Disturbance Control Performance
(DCS)
Enforcement Date 4/1/2012
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*Reportable Disturbance Any event that causes an ACE change greater than or equal to 80% of a Balancing Authority’s or reserve sharing group’s most severe contingency.
R4: Following a Reportable Disturbance*BA must return ACE to the lesser ofzero (0) or pre-contingency value in 15 minutes.
R3: Must carry enough Contingency Reserve to cover most severe single contingency
BAL-002-1
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COM-002-2Communications & Coordination
Enforcement Date 6/18/2007
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COM-002-2
R2: Directives must be issued using 3-part communication. 1- Sender speaks directive. 2-Recipient repeat-back. 3-Sender acknowledges
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EOP-003-2
R1: Shed Load if all fails
R8: Have plans for operator-controlled manual load shed
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Summary The simulations during this conference will reinforce the
importance of adhering to NERC Reliability Standards, including:
• TOP-001: Authority to take all appropriate actions
• TOP-004: Operate within established limits
• VAR-001: Have sufficient reactive resources to maintain voltage
• VAR-002: Maintain generator voltage schedules and keep AVRs on automatic.
• PRC-001: Be aware of purpose & limitations of automatic protection
schemes
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Summary, cont’d
• PRC-006: Auto UFLS provides last-resort preservation of system when frequency is declining
• PRC-010: Auto UVLS sheds enough load in a timely manner to prevent voltage instability/collapse
• BAL-002: Have enough Contingency Reserves to recover from a DCS within the time limit
• COM-002: Issue effective emergency directives using 3-part communication
• EOP-003: After exhausting other corrective actions, manually shed load
rather than risk an uncontrolled separation.