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September 2, 2010 DCS Event

September 2, 2010 DCS Event. Reliability Committee November 17, 2010 Peter Brandien. Highlights. New England was experiencing a late season heat wave September 2 nd peak load of 26,098 MW was an all-time September peak

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September 2, 2010 DCS Event

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  1. September 2, 2010 DCS Event Reliability Committee November 17, 2010 Peter Brandien

  2. Highlights New England was experiencing a late season heat wave September 2nd peak load of 26,098 MW was an all-time September peak System Operator reserve monitor indicated surplus in both 10 and 30 minute operating reserves Experienced the source loss that was setting the 10-minute operating reserve requirement Both on-line and off-line resources under performed Failed to recover from the source loss within the NERC Reliability Standard requirement of 15 minutes

  3. NERC Reliability Standard Requirement • Standard BAL-002 - Disturbance Control Performance • R4. A Balancing Authority or Reserve Sharing Group shall meet the Disturbance Recovery Criterion within the Disturbance Recovery Period for 100% of Reportable Disturbances. The Disturbance Recovery Criterion is: • R4.1. A Balancing Authority shall return its ACE to zero if its ACE just prior to the Reportable Disturbance was positive or equal to zero. For negative initial ACE values just prior to the Disturbance, the Balancing Authority shall return ACE to its pre-Disturbance value. • R4.2. The default Disturbance Recovery Period is 15 minutes after the start of a Reportable Disturbance. This period may be adjusted to better suit the needs of an Interconnection based on analysis approved by the NERC Operating Committee. • Reportable Disturbance is defined as any contingency ≥ 80% of the First Contingency Loss

  4. Event Overview – Initial Conditions * Interpolated value for 13:09 from the hourly forecast, assuming hourly load is forecasted at midpoint of each hour. System Conditions at the time of the contingency:

  5. Event Overview At 13:09 New England experienced a source loss of approximately 1400 MW NPCC Shared Activation of Reserve was limited due to heavy imports from New York Operating Reserves dispersed across many units due to the size of the first source contingency and the operating response rates of available resources Recovery of ACE to pre-contingent value took approximately 23 minutes

  6. Timeline

  7. Recovery Actions • Desired Dispatch Points (DDP) were sent to 146 Generators via Electronic Dispatch to increase output for a total of 1925 MW • 56 start ups for a total of 935 MW • 90 online units for a total of 990 MW • At ~13:23, an economic (non-emergency) DDP was sent in response to the Contingency Dispatch not being sufficient to recover the ACE within 15 minutes • ACE was restored to its pre-contingent value at ~13:33

  8. Interconnection Frequency

  9. ACE Recovery

  10. Transmission System Performance • The Eastern Interconnection inertial response increased NY-NE interface flow by approximately 90% of the source loss • NY-NE flows were initially at the N-1 transfer limit • Flows increased from ~1,400 MW to over 2,600 MW • N-0 limit was approximately 2,900 MW • Limit violations are required to be cleared within 30 minutes (NERC Standard: TOP-007) • NY-NE Interface flows reduced to N-1 limit in 21 minutes

  11. Interface Transfer Recovery

  12. Generator Response • Summary of generator response • Of the 56 start ups: • 936 MW dispatched • 673 MW produced • 263 MW deficiency • Of the 90 online units: • 986 MW dispatched • 398 MW produced • 588 MW deficiency

  13. Immediate Actions • ISO New England self-reported violation of BAL-002 Requirement 4.1 the afternoon of September 2 • Ten Minute Reserve requirement raised to 110% of the largest single source contingency • Ten Minute Spinning Reserve requirement raised to 50% of the new requirement (55% of largest contingency) • Maintain a mix of SAR + Ten Minute Reserves of at least 140% of largest single source contingency

  14. Additional Requirements • After the end of each quarter a Balancing Authority’s performance is evaluated by the Regional Entity (NPCC) and NERC • Based on the September 2nd event, effective November 1st ISO New England’s 10-minute reserve requirement was increased to 112.7% of the largest first contingency (NERC Reliability Standard BAL-002) • Performance for the 4th quarter of 2010 will be evaluated in January 2011 for ability to return to 100% effective February 1st

  15. ISO New England’s Internal Analysis • Evaluated Operator Tools and Surveyed Designated Entities to gain a better understanding of NERC violation • Findings: • Need improvements to procedures or standards for: • Generator displays and alarms • Acknowledgement and compliance of DDPs sent to generators by ISO • Testing and verification of the functionality of communication equipment for receiving and responding to DDPs • Generator performance audits • Generator training • Need improvements to ISO systems related to: • Real-Time calculation of Operating Reserves • Real-Time modeling of generators’ response • Ability to monitor DDP receipt & acknowledgement by generators

  16. Conclusion ISO participating with NPCC on Event Analysis, and expects to brief NPCC on its causal analysis in December ISO expects to bring various Operating Procedure and other Rule changes to NEPOOL Committees in 2011

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