1 / 10

New 2013 NERC Compliance Analysis Activities for TP and/or PC TSS – January 25, 2013

New 2013 NERC Compliance Analysis Activities for TP and/or PC TSS – January 25, 2013. Discussion Lead Tom Duane. Single Point of Failure Survey. Mandatory for all Transmission Planners This data request will impose a substantial burden on the submitting entities .

elijah
Download Presentation

New 2013 NERC Compliance Analysis Activities for TP and/or PC TSS – January 25, 2013

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. New 2013 NERC Compliance Analysis Activities for TP and/or PCTSS – January 25, 2013 Discussion Lead Tom Duane

  2. Single Point of Failure Survey • Mandatory for all Transmission Planners • This data request will impose a substantial burden on the submitting entities. • Simulate a three‐phase fault on each bus in its transmission planning area identified in step 1. • The conditions that require further evaluation include: • the loss of synchronism of 2,000 MW or more • loss of synchronism between two portions of the system • negatively-damped oscillations.

  3. Single Point of Failure Survey • Buses to be tested: • Buses operated at 200 kV or higher with 4 or more circuits. • Buses operated at 100 kV to 200 kV with 6 or more circuits • Buses operated at 100 kV or greater with 4 or more circuits and at which a bus fault and tripping of all connected elements at the remote terminals will result in 300 MW or more of consequential load loss as a result of remote clearing. • Buses with aggregate generation of 1,000 MW or higher.

  4. Single Point of Failure Survey • Schedule: • Interim Report Due to NERC Feb 28, 2013 • >300 kV due August 31, 2013 • 200 to 300 kV due February 28, 2014 • 100 to 200 kV due August 21, 2014

  5. PRC-023-2 R6 R6. Each Planning Coordinator shall conduct an assessment at least once each calendar year, with no more than 15 months between assessments, by applying the criteria in Attachment B to determine the circuits in its Planning Coordinator area for which Transmission Owners, Generator Owners, and Distribution Providers must comply with Requirements R1 through R5. The Planning Coordinator shall: 6.1 Maintain a list of circuits subject to PRC-023-2 per application of Attachment B, including identification of the first calendar year in which any criterion in Attachment B applies. 6.2 Provide the list of circuits to all Regional Entities, Reliability Coordinators, Transmission Owners, Generator Owners, and Distribution Providers within its Planning Coordinator area within 30 calendar days of the establishment of the initial list and within 30 calendar days of any changes to that list.

  6. PRC-023-2 R6 • Applicable to All Transmission Owners and Planning Coordinators • Requires that the Planning Coordinators apply the criteria annually to 100-200 kV facilities and to sub-100 kV facilities identified as critical facilities in the Regional Entity Compliance Registry • Applicable Facilities Affected • Transmission lines operated at 200 kV and above • Transmission lines operated at 100 kV to 200 kV as determined by the Planning Coordinator using Attachment B criteria. • Transmission lines operated below 100 kV identified as critical facilities by the Regional Entity and as determined by the Planning Coordinator

  7. PRC-023-2 R6 • Test: • Major transfer path within the Western Interconnection (Path Rating Catalog) • The circuit is identified through the following sequence of power flow analyses5. • Simulate double contingency combinations selected by engineering judgment, without manual system adjustments in between the two contingencies. • For circuits operated between 100 kV and 200 kV evaluate the post-contingency loading against a threshold based on the Facility Rating assigned • The threshold for selection of the circuit will vary based on the loading duration assumed in the development of the Facility Rating.

  8. PRC-023-2 R6 • Schedule: • First assessment required by Jan 2014. • Assessment covers one to five year planning horizon.

  9. FAC-013-2 • This is a new standard linked to the MOD standards except that it applies to the Planning Horizon instead of the Operations Horizon. • Replaces FAC-012-1 and FAC-013-1. • The standard is effective on April 1, 2013.  Each PC must have issued its Transfer Capability Methodology to adjacent and overlapping PC’s by this date. • Standard requires a simulation of transfer capability for at least one-year in the near-term planning horizon.

  10. FAC-013-2 • Questions: • What are you planning to study relative to this standard? • What will be assumed as the transfer capability methodology? • Assessments must be provided to adjacent and overlapping PC’s within 45 days of completion.

More Related