1 / 16

New England Tie Benefit Discussion – Operational View

Agenda Items 2.0 Reliability Committee Meeting July 20, 2010. New England Tie Benefit Discussion – Operational View. Peter Brandien, Vice President System Operations NEPOOL Reliability Committee Meeting July 20, 2010. Overview. At the June 18 Reliability Committee Meeting:

vaughan-moody
Télécharger la présentation

New England Tie Benefit Discussion – Operational View

An Image/Link below is provided (as is) to download presentation Download Policy: Content on the Website is provided to you AS IS for your information and personal use and may not be sold / licensed / shared on other websites without getting consent from its author. Content is provided to you AS IS for your information and personal use only. Download presentation by click this link. While downloading, if for some reason you are not able to download a presentation, the publisher may have deleted the file from their server. During download, if you can't get a presentation, the file might be deleted by the publisher.

E N D

Presentation Transcript

  1. Agenda Items 2.0 Reliability Committee Meeting July 20, 2010 New England Tie Benefit Discussion – Operational View Peter Brandien, Vice President System Operations NEPOOL Reliability Committee Meeting July 20, 2010

  2. Overview • At the June 18 Reliability Committee Meeting: • Discussed system restrictions that limited the New England overall import capability • Reviewed NERC Standard requirement to maintain “contingency reserves” • Attempted to communicate how operating reserves could be allocated internally within New England and in other control areas to comply with Standards • Review limitations to the New England Import Capability • Operating Reserve Allocation

  3. New England Interconnection Ties • New York AC Ties • 2x 345 kV • 1x 230 kV • 4x 115 kV • 1x DC Converter • 1x 138 kV PST (NNC) • Hydro Quebec Ties • 2x Asynchronous DC • New Brunswick • 2x 345 kV

  4. New England Transmission Transfer Capability (MW)

  5. New England Transmission System Import Capability

  6. New York – New England Interface –Review Capability to import power to and across the NY-NE Interface is variable and dependents on transmission margins external to New England Operations performed an analysis to determine what level of NY-NE interface flows could be relied upon based on available actual transmission margins when NE was importing power from NY The analysis evaluated June through September for the last three years (2007, 2008 & 2009)

  7. Real Time NY Transfer Capability (MW)

  8. NY Transfer Capability Duration Curve

  9. Real Time NY Transfer Capability (MW) Hour

  10. New Brunswick – New England Interface Maximum import capability of 1000 MW into Maine Full import capability is dependent on numerous Special Protection Schemes Internal New England transmission limitations prevent transfers up to full import capability when utilizing all northern generation Approximately 350 MW constrained in northern Maine at peak load

  11. Reductions to Transmission Transfer Capability (MW) * Based on historical real time transfer capability

  12. Operating Reserve Allocation

  13. NERC Reliability Standard BAL-002-0, Disturbance Control Performance • Requirement 1. Each Balancing Authority shall have access to and/or operate Contingency Reserve to respond to Disturbances. Contingency Reserve may be supplied from generation, controllable load resources, or coordinated adjustments to Interchange Schedules • Requirement 3.1. As a minimum, the Balancing Authority or Reserve Sharing Group shall carry at least enough Contingency Reserve to cover the most severe single contingency • In NPCC, “Contingency Reserves” is referred to as “Ten-minute Reserves” • NPCC also requires “Thirty-minute Reserves” which shall be at least equal to one-half the second contingency source loss • Shall restore thirty-minute reserve within four hours if it becomes deficient

  14. System Response following a Source Loss Following a source loss in New England, most of the generation inertial response is from west of New England This generation response will show up as increased power flows into New England on the New York ties Neighboring areas must operate their system recognizing this response 30% of this power will flow across the NY Central/East Interface because of the inertial response New England must restore the external ties back to the scheduled power flows within 10 minutes

  15. Operating Reserve Allocation • The NERC Standard allows for reserves to be allocated to coordinated adjustments to Interchange Schedules • Under expected capacity shortage conditions, if we assume that New England can arrange with New York to take advantage of the inertial response and some additional level of shared activation of reserves, then New England could meet the NERC operating requirement by maintaining approximately 700 MW of internal reserves • Need to shed 700 MW of load within 10 minutes • This level of internal reserves is also consistent with the NPCC requirement for spinning reserves (50% of the largest source contingency)

  16. Questions?

More Related