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NERC/FERC Update

NERC/FERC Update. CCPG Meeting – April 22, 2010. NERC Standards Under Development. TPL-001-1 Transmission System Planning Performance Requirements Received 35.4% approval from industry in initial ballot (WECC balloted affirmative; most WECC members balloted negative)

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NERC/FERC Update

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  1. NERC/FERC Update CCPG Meeting – April 22, 2010

  2. NERC Standards Under Development • TPL-001-1 Transmission System Planning Performance Requirements • Received 35.4% approval from industry in initial ballot (WECC balloted affirmative; most WECC members balloted negative) • Standard being revised to address industry comments • Changes influenced by March 18 FERC Order (Table I, Footnote b) and NOPR (TPL-002 R1.3.10 Interpretation) • Posting of next draft for comments not likely before early-August

  3. NERC Standards Under Development • FAC-013-2 Planning Transfer Capability • In response to FERC Order 729 (rejected NERC proposal to retire FAC-012/-013 based on approval of MOD-001/-028/-029/-030) • Will replace existing FAC-012-1 (Transfer Capability Methodology) and FAC-013-1 (Establish and Communicate Transfer Capabilities) • To establish inter-/intra-regional transfer capability in planning horizon using methodology consistent with that used for operating horizon • In WECC – Which of the 3 methodologies is being used to calculate OTC’s for Major Paths / TOTs? How would the methodology for FAC-013-2 be different than what’s used for FAC-010-2 (to compute SOL’s for planning horizon)?

  4. March 18 FERC Orders and NOPR • Compliance Order RM06-16-009 • Commission directs NERC to submit a modification to Table I, footnote b of TPL-002-0 that is responsive to the Commission’s directive in Order No. 693, by June 30, 2010. • Existing footnote b: Planned or controlled interruption of electric supply to radial customers or some local Network customers, connected to or supplied by the Faulted element or by the affected area, may occur in certain areas without impacting the overall reliability of the interconnected transmission systems. To prepare for the next contingency, system adjustments are permitted, including curtailments of contracted Firm (non-recallable reserved) electric power Transfers.

  5. March 18 FERC Orders and NOPR Revised footnote b posted for comment by NERC on April 15 • No interruption of firm Load is allowed except: (1) Interruption of Load that is directly served by the elements that are removed from service as a result of the Contingency, or (2) Planned or controlled interruption of Load supplied by Transmission Facilities made temporarily radial as a result of the Contingency and where that Load must be interrupted to meet performance requirements only on those now radial Transmission Facilities. • No curtailment of Firm Transmission Service is allowed except when coupled with the appropriate re-dispatch of resources obligated to re-dispatch where it can be demonstrated that Facilities remain within applicable Facility Ratings and those adjustments do not result in the shedding of any firm Load. • Effective Date: First day of the first calendar quarter, 60 months after applicable regulatory approval.

  6. March 18 FERC Orders and NOPR NOPR RM10-6-000 on R1.3.10 Interpretation • R1.3.10. Include the effects of existing and planned protection systems, including any backup or redundant systems. NERC Interpretation for PacificCorp • Question 1: Does TPL-002-0 R1.3.10 require that all elements that are expected to be removed from service through normal operation of the protection systems be removed in simulations? • Response 1: TPL-002-0 requires that System studies or simulations be made to assess the impact of single Contingency operation with Normal Clearing. TPL-002-0, R1.3.10 does require that all elements expected to be removed from service through normal operations of the Protection Systems be removed in simulations. • Question 2: Is a Category B disturbance limited to faults with [N]ormal [C]learing where the protection system operates as designed in the time expected with proper functioning of the protection system(s) or do Category B disturbances extend to protection system misoperations and failures? • Response 2: This standard does not require an assessment of the Transmission System performance due to a Protection System failure or Protection System misoperation. FERC Rejection Basis NERC’s proposed interpretation: • miscategorizes non-operation of non-redundant primary protection systems as protection system failure which is addressed in TPL-003-0 and TPL-004-0. • misses studying the effects of backup and redundant protection systems pursuant to Requirement R1.3.10 of TPL-002-0.

  7. March 18 FERC Orders and NOPR NOPR RM10-6-000 on R1.3.10 Interpretation Uses the following definitions: • Primary protection scheme is the first line of defense designed to remove the minimum number of elements in the shortest time. • Backup protection system isolates the fault or disturbance by removing additional elements some period of time after the non-redundant primary protection system would do so, operating because that primary protection system did not function properly. • Remote backup protection refers to protection systems that operate breakers distant from the site of the contingency and therefore result in the isolation of a larger portion of the bulk electric system. • Normal clearing is when the protection system operates as designed and the Fault is cleared in the time normally expected with proper functioning of the installed protection systems. (Table I, footnote e) • Delayed clearing of a Fault is due to failure of any protection system component such as a relay, circuit breaker, or current transformer, and not because of an intentional design delay.(Table I, footnote e)

  8. March 18 FERC Orders and NOPR NOPR RM10-6-000 on R1.3.10 Interpretation • R1.3.10. Include the effects of existing and planned protection systems, including any backup or redundant systems. • Proposed Interpretation: “...requires that planners study, in their system assessments, the non-operation of primary protection systems in order to ascertain whether and how reliance on the as-designed backup or redundant protection systems affects reliability.” • Based on the following arguments: • non-operation of a non-redundant primary protection system is not a contingency • normal clearing of a contingency depends on the protection system that operates to clear the contingency (i.e. primary or backup) • longer clearing times corresponding to the as-designed operating times of the backup protection system do not constitute or create a situation of delayed clearing

  9. March 18 FERC Orders and NOPR NERC TIS Recommended Rebuttal to NOPR RM10-6-000 • Non-operation of non-redundant primary protection system translates to two and only two conditions: • protection system failure to operate • protection system out of service – a planned outage • Condition 1 is clearly covered by TPL-003 and TPL-004 • Condition 2 is covered under R1.3.12 R1.3.12. Include the planned (including maintenance) outage of any bulk electric equipment (including protection systems or their components) at those demand levels for which planned (including maintenance) outages are performed. • Hence in TPL-002 studies/simulations, R1.3.10 can only be analyzed in context of R.1.3.12

  10. Questions?

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