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2004 NERC, NPCC & New England Compliance Programs. John Norden Manager, Operations Training, Documentation & Compliance August 31, 2003 RC Meeting. NERC 2004 Program Changes post-blackout. Near-Term Actions to Assure Reliable Operations. - PowerPoint PPT Presentation
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2004NERC, NPCC & New
EnglandCompliance Programs
John Norden
Manager, Operations Training, Documentation & Compliance
August 31, 2003 RC Meeting
NERC 2004 Program Changespost-blackout
3
Request from NERC on 10/15/2003 to Reliability Coordinators and Control Areas to review reliability practices to ensure compliance with NERC and regional reliability council standards and established good utility practices Surveyed Participant practices for two issues
Ensure all interconnected generators that have automatic voltage regulation (AVR) and are operating under AVR; and
Ensure high voltage transmission line rights of way are free of vegetation and other obstructions that could contact an energized conductor within the normal and emergency ratings of each line
Near-Term Actions to Assure Reliable Operations
4
Recommendation 2 of NERC Final Blackout Report: “Strengthen the NERC Compliance Enforcement Program”
NERC Formed the CTTF in order to make more clear the existing requirements and develop any additional measures as were identified as contributing factors to the Blackout 12 additional measures and more clear requirements
replace what was in the existing 2004 Compliance Enforcement Program
Compliance Template Task Force (CTTF)
5
On April 2, 2004 the NERC BOT approved a set of 38 revised compliance templates that strengthen and clarify existing standards 18 Planning Measures 20 Operating Measures
Reporting required as of June 1, 2004 Many requirements are “upon occurrence”
as opposed to scheduled reporting
38 “New” Compliance Templates
6
Protection System Maintenance and Testing NPCC Document A-4, Bulk Power System Protection
Minimum Maintenance already in the Enforceable Program
Inter-Area Coordination (outages & Interchange) NPCC does a very good job
Operator Training Vegetation Management
New England Transmission Maintenance and Construction Task Group will be revising OP #3 Appendix C and D and asking the RC for approval as a separate Operating Procedure
Loss of Primary Control Facility
Major Additions
NERC Version 0 Update
8
“Plan for Accelerating the Adoption of NERC Reliability Standards” – June 15, 2004
How does this effect the Version 1 process
Translation from existing requirements
Existing Planning Standards, including post-blackout Compliance Template revisions
Existing Operating Policies, including post-blackout Policy 5,6, and 9 revisions
“Version 0” NERC Standards
9
Why “Version 0”? The August 14 blackout has challenged NERC and the
industry to demonstrate that its reliability standards are unambiguous and measurable – now.
Recommendation 25 of the U.S./Canada Power System Outage Task Force final report: “NERC should reevaluate its existing reliability standards development process and accelerate the adoption of enforceable standards.”
An April 14, 2004 order of FERC states a policy objective addressing “the need to expeditiously modify [NERC] reliability standards in order to make these standards clear and enforceable.”
10
Why “Version 0”? (cont’d.)
The continued use of multiple formats, processes and forums for developing and maintaining reliability rules is an inefficient dilution of industry and staff resources.
The transition to new standards and retiring of existing operating policies and planning standards will be too complex for industry implementation if taken one standard at a time over several years.
11
“Version 0” Status Posted for Industry Comment on July 11th
Over 400 pages of documentation to review Only 30 days to review, compile & submit comments
Comment period closed on August 9th
Approximately 100 entities submitted written comments
ISO-NE, NPCC and ISO/RTO Council reviewed all material and issued comments including issues with Phase III and IV Planning standards regarding generation testing.
ISO-NE also has issues with implementation plans
12
“Version 0” Next Steps Drafting Team met again August 18-20
Comments considered Standards revised, as appropriate
Second draft to be posted by August 30th
45 days review period During September and October, several regional
workshops will be held to hear comments and answer questions about the Version 0 reliability standards and the registration of reliability functions
Committee action during November 9-11 meetings Present to NERC BOT in February 2005 and
implementation upon approval
2004 Program Status Report
14
Reporting Participants report on all Participant
Compliance requirements to the ISO The ISO reports both Participant and Area
Compliance for NPCC and NERC Measures through NPCC
Regions (NPCC) report on Regional Compliance (a compilation of all Areas’ and all Area’s Participant compliance) to NERC for the NERC Measures
15
2004 NERC Requirements 41 Requirements in the Final 2004 Program
22 “Planning” (4 of which are operational) 19 Operations 12 Covered by NPCC Compliance
requirements; no double-reporting 6 Regional (NPCC) reporting requirements 15 Area/Reliability Coordinator reporting
requirements 8 Participant reporting requirements
All surveyed and reported on for the 2004 Program
16
2004 NPCC NRAP(non-enforceable)
Five Requirements One Planning – Participant reporting on
Generator Underfrequency Tripping Four Operations
One Participant Reporting - Testing Requirements for critical components associated with key facilities (Document A-03, Section 4.10) To be Reported in Early 2005
Three Area reporting requirements
17
2004 NPCC RCEP(enforceable)
Eight Requirements Three Planning – Two are Participant
reporting requirements Minimum BPS Maintenance Area Automatic UFLS requirements
Five Operations One Participant Reporting – Annual
blackstart testing requirement (Document A-03)
Reported from previous year
18
2004 NPCC & NERC Reporting Status
Partial non-compliance reported NPCC-wide on the NRAP non-enforceable measure for Testing Requirements for critical components associated with key facilities May be due to required clarification to uniformly
address some of the specific testing requirements contained in Section 4.10.1 of Document A-03
Critical requirements following August 14th Blackout Several testing requirements will be enforceable in
next year’s program Need to stress importance to Industry Participants that
compliance with NPCC Criteria, whether enforceable or not, is required by the Restated NEPOOL Agreement!
19
2004 New England Two Requirements identified to-date
NEPOOL Operating Procedure No. 17, ‘Load Power Factor Correction’
NEPOOL Operating Procedure No. 13, ‘Standards For Voltage Reduction and Load Shedding Capability’ – 5% Voltage Reduction
20
2005 NPCC RCEP(Document A-08)
Report on the “Restoration of the NPCC Areas Following the Power System Collapse of August 14, 2003” recommends additional requirements of this Program NPCC Document A-03, ‘Emergency
Operation Criteria,’ Section 4.10 Make several tests enforceable with
penalties Blackstart Generating Station Testing (“BS-1”); and Control Center and Telecommunication Center
Facility Testing (“CC-1” through “CC-7”)
Questions
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