ML052140118
| ML052140118 | |
| Person / Time | |
|---|---|
| Site: | Beaver Valley |
| Issue date: | 03/08/2005 |
| From: | Koza F PJM Interconnection |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| Download: ML052140118 (19) | |
Text
Operating the PJM System NRC Regulatory Information Conference Session C1: Grid Reliability Frank J. Koza, General Manager Regional Operations of PJM Interconnection March 8, 2005
Overview of the PJM Integrations
- May 1, 2004 - Commonwealth Edison
- Installation of a 500 MW pathway between ComEd and existing PJM control areas (= 2 control areas)
- October 1, 2004 - AEP and Dayton Power and Light
- Removal of pathway and consolidation of the control areas to one control area
- January 1, 2005 - Duquesne Light
- Inclusion of FE Beaver Valley as a capacity resource in PJM
- Spring 2005 - Dominion PJM Confidential 2
©2003 PJM
Overview of PJMEnergy Market Statistics 2002 Data PJM Confidential 3
©2003 PJM
Overview of PJMNuclear Plants Territory Served
- Byron 1&2
- DC Cook 1&2
- Quad Cities 1&2
- Susequhanna 1&2
- Braidwood 1&2
- LaSalle 1&2
- Beaver Valley 1&2
- Limerick 1&2
- TMI 2
- Oyster Creek
- Peach Botton 2&3
- Salem 1&2/Hope Creek
- Calvert Cliffs 1&2
- Surry 1&2
- North Anna 1&2 PJM Confidential 4
©2003 PJM
Review of Operations--Big Picture (Winter)
Outbound Michigan Outbound New York
~500 MW Inbound Cinergy Inbound VAP Generally, there are large ~500 MW
~500 MW circulatory flows, coming into PJM from the south and west (e.g., Cinergy and TVA) and flowing north to New York and Michigan Inbound TVA
~500 MW PJM Confidential 5
©2003 PJM
Control Performance--ABCs of ACE ACE = (NIA NIS) 10 (FA FS) IME Tie Error Component Frequency Error Component Total difference between actual and Difference between scheduled interchange actual frequency and summed across the scheduled frequency metered boundaries of (normally 60 Hz)
PJM For PJM, 1138 MW/0.1 Hz Bottom Line: PJM must keep its average ACE within +/- 258 MW for at least 90% of every 10 minute period for the month (NERC CPS-2 Control Performance Requirement)
PJM Confidential 6
©2003 PJM
January 24 Case StudyMorning Pickup Freq Error Component of ACE Tie Error Component of ACE ACE Components, Jan 24, 2005 CPS2 Violations RTO Regulation Signal PJM RTO ACE Net Schedule 1100 0 1000 900 Late starting CTs hit 800 the bus, forcing a -500 ACE, Regulation Signal & Error Componets (MW) 700 reversing action 600 500 -1000 400 300 +L10 Net Schedule (MW) 200
-1500 100 0
-100
-2000
-200
-300 -L10
-400 Cold morning pickup10,000
-2500
-500 MW of CTs called on to meet
-600
-700 load, only 5000 MW initially
-800 startothers are delayed -3000
-900
-1000 starting = 8 CPS2 violations
-1100 -3500 AN.REG CE v L10 04:00 04:10 04:20 04:30 04:40 04:50 05:00 05:10 05:20 05:30 05:40 05:50 06:00 06:10 06:20 06:30 06:40 06:50 07:00 07:10 07:20 07:30 07:40 07:50 08:00 Time (EDT)
PJM Confidential
©2003 PJM PJM Load grew7 by over 20,000 MW during this 4 hr period!
January 24 Case StudyMorning Pickup RT O CTs on-line 1/24/2005 11:02:36 AM 9000 5785.
8000 7000 When we 6000 needed them 5000 When we got them 4000 3000 2000 1000 4:00 5:00 6:00 7:00 8:00 9:00 10:00 PJM Confidential 8
©2003 PJM
January 24 Case StudyEvening Pickup Freq Error Component of ACE Tie Error Component of ACE ACE Components, Jan 24, 2005 CPS2 Violations RTO Regulation Signal PJM RTO ACE Net Schedule 1100 1000 1000 900 Serendipitous alignment of tie 800 error and frequency error, ACE, Regulation Signal & Error Componets (MW) 700 effectively canceling each other 500 600 500 400 300
+L10 Net Schedule (MW) 200 0 100 0
-100
-200 -500
-300
-L10
-400
-500
-600
-1000
-700
-800 Only 2 CPS-2 Violations
-900
-1000
-1100 -1500 MAN.REG ACE v L10 16:00 16:10 16:20 16:30 16:40 16:50 17:00 17:10 17:20 17:30 17:40 17:50 18:00 18:10 18:20 18:30 18:40 18:50 19:00 19:10 19:20 19:30 19:40 19:50 20:00 Time (EDT)
PJM Confidential 9
©2003 PJM
PJM Nuclear Owners/Operators Users Group
- Created by the owners as a feature of PJM governance (PJM staff facilitates and provides administrative support)
- Broad participation from the nuclear owners: AEP, AmerGen, Constellation, Dominion, Exelon, First Energy, PPL, and PSEG PJM Confidential 10
©2003 PJM
Grid Interface Issues
- Cultural Differences
- Communications (Dont speak the same language)
- Have differing regulatory accountabilities (FERC vs. NRC vs. State PUCs)
- Market role (Code of Conduct issues)
PJM Confidential 11
©2003 PJM
PJM Response to Cultural Differences Issue Nuclear Communications Protocol (PJM Manual M-1, Attachment B) http://www.pjm.com/contributions/pjm-manuals/pdf/m01v08.pdf Features:
- Nuclear Safety/ Grid Reliability Philosophies
- Roles and Responsibilities
- Key Terms Defined
- Event Communications
- Regulatory Background Information PJM Confidential 12
©2003 PJM
Protocol KEY TRANSMISSION TERMS First Contingency Violation The transmission system is operated so that the single loss of any facility (line, generator, etc.) will not result in violation of any operating limit. The single loss is called the first contingency.
The transmission operators have software that simulates the first contingency individually for a number of facilities on the system.
Implication: The operators are required to correct any first contingency violation that will violate the emergency ratings on any facility within a period of time (normally within 30 minutes). If the operators ask the nuclear plant to take action as the result of the first contingency violation, the action should be implemented unless the action will jeopardize nuclear safety, personnel safety, or equipment protection.
PJM Confidential 13
©2003 PJM
Grid Interface Issues
- Post-contingency Voltage Stability
- NPPs generally have more restrictive voltage limits than the grid
- In an accident scenario, will the safety systems work if needed?
PJM Confidential 14
©2003 PJM
PJM Response to Voltage Concerns Notification and Mitigation Protocols for Nuclear Plant Voltage Limits (PJM Manual M-3, Section 3, page 36) http://www.pjm.com/contributions/pjm-manuals/pdf/m03v14.pdf Regarding Code of Conduct issues:
If PJM operators observe voltage violations or anticipate voltage violations (pre or post-contingency) at any nuclear stations; PJM operators are permitted to provide the nuclear plant with the actual voltage at that location, the post-contingency voltage at that location (if appropriate) and limiting contingency causing the violation.
PJM Confidential 15
©2003 PJM
Example of Voltage Standards and Operational Philosophy PJM Confidential 16
©2003 PJM
Grid Interface Issues
- Outage Coordination
- NPP perspective: Getting the transmission owner to perform maintenance when the NPP is in an outage to mitigate NPP risk
- Transmission perspective: We dont schedule maintenance the way they do.
PJM Confidential 17
©2003 PJM
PJM Response to Outage Coordination Issue Outage Coordination Procedures (PJM Manual M-3, Section 4) Same link as above
- Strict advanced notification requirements
- Multiple step analysis process to ensure reliability is maintained
- Wide dissemination of outage information PJM Confidential 18
©2003 PJM
Special Consideration for Nuclear Plants The Nuclear Generating Stations coordinate the scheduling of a Unit Breaker outage and internal plant equipment outages and testing to minimize station risk.
Adherence to outage schedule and duration is critical to the plant during these evolutions. Emergent plant or transmission system conditions may require schedule adjustments, which should be minimized. Any change to the outage schedule that impacts the Unit Breakers shall be communicated to the nuclear generator operator.
The following Nuclear Generating Stations have transmission system connections that can impact Nuclear Station Safety Systems:
Peach Bottom: Limerick:
Unit 2: CB 215 Unit 1: CB 535 CB 225 CB 635 Unit 3: CB 15 Unit 2: CB 235 CB 65 CB 335 Salem: Oyster Creek:
Unit 1: 5 - 6 B.S. 10X GD1 2 - 6 B.S. 11X GC1 Unit 2: 9 - 10 B.S. 30X 1 - 9 B.S. 32X Hope Creek: Calvert Cliffs:
BS 6 - 5 50X Unit 1: 552 - 22 BS 2 - 6 52X 552 - 23 Unit 2: 552 - 61 552 - 63 PJM Confidential 19
©2003 PJM