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FERC NOPR

FERC NOPR. Docket No. RM07-3-000. FERC NOPR (August 13, 2007).

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FERC NOPR

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  1. FERC NOPR Docket No. RM07-3-000

  2. FERC NOPR (August 13, 2007) • FERC is proposing to approve three Reliability Standards developed by the North American Electric Reliability Corporation (NERC), which the Commission has certified as the Electric Reliability Organization responsible for developing and enforcing mandatory Reliability Standards. The three new Reliability Standards, designated by NERC as FAC-010-1, FAC-011-1 and FAC-014-1, set requirements for the development of system operating limits of the Bulk-Power System for use in the planning and operation horizons • Response by around Sept. 17, 2007.

  3. System Operating Limits Methodology for the Planning Horizon (FAC-010-1) and Operating Horizon (FAC-011-1) FERC proposes to approve FAC-010 subject to: • Consistency with Order 890: • SOL based on N-1 • Calculation of ATC N-2 • Do Order 890 transparency requirements mitigate any potential for undue discrimination? • Seeks comment on whether: • SOLs (in FAC-010-1) = TTC used for ATC calculation. • If so, should NERC address SOLs, transfer capability and TTC in a coordinated and consistent manner?

  4. System Operating Limits Methodology for the Planning Horizon (FAC-010-1) and Operating Horizon (FAC-011-1) • R 2.2 - requires PA to consider loss of shunt device: • Clarify the TPL Standards be modified to explicitly require the consideration of a shunt device (as in FAC-010-1)?

  5. System Operating Limits Methodology for the Planning Horizon (FAC-010-1)and Operating Horizon (FAC-011-1) • WECC Regional Difference: • E.1.4.The WECC may make changes (performance category adjustments) to the Contingencies required to be studied and/or the required responses to Contingencies for specific facilities based on actual system performance and robust design. Such changes will apply in determining SOLs. • Propose that WECC identify the process that it will use to make changes to the currently listed contingencies required to be studied or required responses to contingencies. • Seeks comment on whether the regional difference should be modified to explicitly include the process that WECC will use to make changes to the currently listed contingencies.

  6. System Operating Limits Methodology for the Planning Horizon (FAC-010-1) • R 2.3 - allows loss of radial and local network load for N-1: • Limited to the loss of load that is a direct result of the contingency, i.e., consequential load following an N-1?

  7. System Operating Limits Methodology for the Operating Horizon (FAC-011-1) • R 2.3.2 - allows loss of load after an N-1 for unanticipated operating conditions • Seeks clarification regarding the meaning of “if the real-time operating conditions are more adverse than anticipated in the corresponding studies, e.g., load greater than studied.” • Concerned whether this provision treats load forecast error as a contingency and as such would allow an interruption due to an inaccurate weather forecast.

  8. Establish and Communicate System Operating Limits (FAC-014-1) - Approve Definitions subject to: • Cascading Outage • Current definition “The uncontrolled successive loss of system elements triggered by an incident at any location. Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies.” • Proposed Definition: “The loss of facilities in the bulk electric systems that are beyond those that would be removed from service by primary or backup protective relaying associated with the initiating event”

  9. Establish and Communicate System Operating Limits (FAC-014-1) - Approve Definitions subject to: • IROLs - The phrase “that adversely impacts the reliability of the bulk electric system” may give the impression that violation of some IROLs that do not adversely impact the reliability of the BES are acceptable. • Accept the definition with the understanding that: • All IROLs impact BES reliability. • The only time it is acceptable to violate an IROL is in the limited time after a contingency has occurred and the operators are taking action to eliminate the violation.

  10. Violation Risk Factors • WECC Regional Difference – No violation Risk Factors • FAC-010-1 - Violation Risk Factor • R2.1 - requires the bulk electric system in a pre-contingency state and with all facilities in service to demonstrate transient, dynamic and voltage stability. • NERC - Lower • FERC - High • R2.2 - instability, cascading or uncontrolled separation shall not occur. • NERC - Medium • FERC - High

  11. Violation Risk Factors • FAC-011-1 • R2.1 - requires the bulk electric system in a pre-contingency state and with all facilities in service to demonstrate transient, dynamic and voltage stability. • NERC - Lower • FERC - High • R2.2.3 - instability, cascading or uncontrolled separation shall not occur. • NERC - Medium • FERC - High

  12. Violation Risk Factors • FAC-014-1 • R.5 and R5.1 – 5.1.4 – RC, PA and TP each provide its SOLs and IROLs to those entities that have a reliability-related need for those limits and provide a written request that includes a schedule for delivery of those limits • NERC - Medium • FERC - High

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