ML12011A168
| ML12011A168 | |
| Person / Time | |
|---|---|
| Site: | Columbia  |
| Issue date: | 12/14/2011 |
| From: | Energy Northwest |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| GO2-11-201 | |
| Download: ML12011A168 (160) | |
Text
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS Section Page LDC N-9 9-0 0 0 14-i 14.1 SPECIFIC INFORMATION INCLUDED IN PRELIMINARY SAFETY ANALYSIS REPORTS
.....................................................
14.1-1 14.2 SYSTEM LINEUP, PREOPERATIONAL, AND INITIAL STARTUP TEST PROGRAM.......................................................................14.
2-1 14.2.1
SUMMARY
OF TEST PROGRAM AND OBJECTIVES.........................14.2-1 14.2.1.1 Initial Test Program Objectives..................................................14.2-1 14.2.1.2 Initial Test Program Summaries..................................................14.2-1 14.2.1.3 Description of System Lineup Tests..............................................14.2-2 14.2.1.4 Description of Preoperational Tests.............................................14.2-3 14.2.1.5 Descripti on of Startup Tests.......................................................14.2-3 14.2.2 ORGANIZATION AND STAFFING.................................................14.2-4 14.2.2.1 General...............................................................................14.2-4 14.2.2.2 Definitions............................................................................14.2-5 14.2.2.3 Test and Star tup Program Organization an d the System Lineup and Preoperational Test Program......................................................14.2-6 14.2.2.3.1 General.............................................................................
14.2-6 14.2.2.3.2 Responsib ilities of CGS Test and St artup Division.........................14.2-6 14.2.2.3.3 CGS Test and Startup Department Position Responsibilities.............14.2-6 14.2.2.3.3.1 CGS Te st and Startup Manager.............................................14.2-6 14.2.2.3.3.2 CG S Test Group Manager....................................................14.2-7 14.2.2.3.3.3 CGS Test Group Supervisor..................................................14.2-7 14.2.2.3.3.4 CG S Test Engineers...........................................................14.2-8 14.2.2.4 Plant Operations Organization and the Power Ascension Test Program...............................................................................14.2-8 14.2.2.5 Test Working Group................................................................14.2-9 14.2.2.5.1 System Lineup and Preoperational Test Program..........................14.
2-9 14.2.2.5.2 Membership and Responsibility of the Test Working Group..............14.2-9 14.2.2.6 Plant Organization Func tions and Responsibilities During All Testing and Plant Operations......................................................14.
2-10 14.2.2.7 Energy Northwest Suppor t of the Test and Startup Program................14.2-10 14.2.2.7.1 Plant Organization...............................................................14.2-10 14.2.2.7.1.1 Support During Test and Startup Program Development...............14.2-10 14.2.2.7.1.2 Su pport During Testing.......................................................14.
2-11 14.2.2.7.2 CGS Program.....................................................................14.
2-11 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page LDC N-0 2-0 0 0 14-ii 14.2.2.7.3 Plant Qua lity Assurance.........................................................14.
2-11 14.2.2.8 Architect-Engineer Support of the Test and Startup Program...............14.2-11 14.2.2.9 General El ectric Support of the Te st and Startup Program..................14.2-12 14.2.2.9.1 Staff Responsibilities.............................................................14.2-12 14.2.2.9.1.1 General El ectric Operations Manager.....................................14.2-12 14.2.2.9.1.2 General Elect ric Operations Superintendent..............................14.2-12 14.2.2.9.1.3 General El ectric Shift Superintendents.....................................14.2-12 14.2.2.9.1.4 General Electric Lead Engineer - Start up Test, Design, and Analysis..........................................................................14.
2-13 14.2.2.10 Qualifications of Pers onnel Supporting the Test and Startup Program.............................................................................14.
2-13 14.2.2.10.1 Test and Startup Program Department Personnel Qualifications......14.2-13 14.2.2.10.2 Plant Organization Personnel Qualifications..............................
14.2-14 14.2.3 TEST PR OCEDURES.................................................................14.2-14 14.2.3.1 Development of Test Procedures.................................................14.2-14 14.2.3.1.1 Incorporation of Plant Procedures............................................
14.2-15 14.2.3.1.2 Format of Test Procedures......................................................
14.2-15 14.2.3.1.2.1 Preope rational Test Phase...................................................14.
2-15 14.2.3.1.2.2 Power Ascension Test Phase.................................................14.2-17 14.2.3.2 Review of Test Procedures........................................................14.
2-17 14.2.3.3 Approval of Test Procedures......................................................14.
2-18 14.2.4 CONDUCT OF TEST PROGRAM..................................................14.
2-18 14.2.4.1 Administrative Proce dures for Preoperational Testing.......................14.2-18 14.2.4.1.1 Test Performance Auth orization...............................................14.2-18 14.2.4.1.2 Preope rational Test Prer equisites.............................................14.
2-19 14.2.4.1.3 Conduct of Pr eoperational Testing............................................
14.2-19 14.2.4.1.4 Deficie ncy Reporting.............................................................14.2-20 14.2.4.1.5 Equipment Maintenance and Modifications During Preoperational Testing..............................................................................14.
2-20 14.2.4.1.6 Preoperati onal Test Summary..................................................
14.2-21 14.2.4.1.7 Evalua tion of Preoperational Test Data......................................14.2-21 14.2.4.1.8 Pre operational Test Records...................................................14.
2-21 14.2.4.2 Administrative Proce dures for Power Ascension Testing....................14.2-21 14.2.4.2.1 Plant Operation Duri ng Power Ascension Testing.........................14.2-21 14.2.4.2.2 Power Asce nsion Test Scheduling and Sequencing.........................14.
2-22 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page LDC N-0 2-0 0 0 14-iii 14.2.4.2.3 Power Ascensi on Test Performance...........................................
14.2-22 14.2.4.3 Control of Test Prerequisites......................................................14.
2-23 14.2.4.4 Modification of Test Procedures During Testing..............................14.2-23 14.2.4.4.1 System Lineup and Preoperational Test Phase..............................14.2-23 14.2.4.4.2 Power Ascens ion Test Phase...................................................
14.2-24 14.2.5 REVIEW, EVALUATION, AND APPROVAL OF TEST RESULTS...........14.2-24 14.2.5.1 Control of Test Results Review...................................................14.
2-24 14.2.5.2 Design Organization Par ticipation in Problem Resolution..................14.2-24 14.2.5.3 Results Analysis Prerequis ites to Continuation of Startup Testing.........14.2-25 14.2.6 TEST RECORDS.......................................................................14.
2-25 14.2.6.1 System Lineup an d Preoperational Test Phase................................14.2-25 14.2.6.1.1 General.............................................................................
14.2-25 14.2.6.1.2 Test Reco rd Responsibilities....................................................
14.2-26 14.2.6.1.3 Types of Documents and Records Requiring Test Record File Retention...........................................................................14.
2-26 14.2.6.2 Power Ascension Test Phase......................................................14.
2-26 14.2.7 CONFORMANCE OF TEST PROGRAMS WITH REGULATORY GUIDES.................................................................................
14.2-26 14.2.7.1 Conformance with Regulatory Guide 1.68......................................14.2-26 14.2.7.2 Exceptions to Regulatory Guide 1.68............................................14.
2-27 14.2.7.3 Conformance With or Exce ptions to Regulatory Guides Other Than 1.68............................................................................14.
2-27 14.2.8 UTILIZATION OF REACTOR OPERATING AND TESTING EXPERIENCES IN THE DEVELOPMENT OF THE TEST PROGRAM......14.2-27 14.2.9 TRIAL USE OF PLANT OPERATING AND EMERGENCY PROCEDURES.........................................................................14.
2-28 14.2.10 INITIAL FUEL LOADING AND INITIAL CRITICALITY.....................14.2-28 14.2.10.1 Fuel Loading and Shutdown Power Level Tests..............................14.2-28 14.2.10.1.1 Loss of Power Demonstration - Standby Core Cooling Required......14.2-28 14.2.10.1.2 Cold Func tional Testing.......................................................14.
2-28 14.2.10.1.3 Routine Surveillance Testing..................................................
14.2-29 14.2.10.1.4 Master Startup Checklist.......................................................14.
2-29 14.2.10.1.5 Initial Fuel Loading............................................................14.
2-29 14.2.10.1.6 Zero Powe r Level Tests........................................................14.
2-30 14.2.10.2 Initial Heatup to Rated Temperature and Pressure..........................14.2-30 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page LDC N-0 2-0 0 0 14-iv 14.2.10.3 Power Te sting From 25% to 100% of Rated Output........................14.2-30 14.2.11 TEST PROG RAM SCHEDULE....................................................14.
2-32 14.2.12 INDIVIDUAL TEST DESCRIPTIONS............................................14.
2-32 14.2.12.1 Preoperati onal Test Procedures................................................14.2-32 14.2.12.1.1 Reactor Feedwater System Preoperational Test...........................14.2-33 14.2.12.1.2 Condensate System Preopera tional Test....................................14.2-33 14.2.12.1.3 Fire Protection System Preope rational Test................................14.2-34 14.2.12.1.4 Reactor Wa ter Cleanup System Pre operational Test......................14.2-35 14.2.12.1.5 Stand by Liquid Control System Preoperational Test......................14.2-35 14.2.12.1.6 Nuclear Boiler System Preoperational Test................................14.2-36 14.2.12.1.7 Residual He at Removal System Pre operational Test......................14.2-37 14.2.12.1.8 Reactor Core Isolation Cooling System Preoperational Test............14.2-37 14.2.12.1.9 Reacto r Recirculation System and Control Preoperational Test........14.2-38 14.2.12.1.10 Reactor Manual Contro l System Preopera tional Test...................14.2-39 14.2.12.1.11 Control R od Drive Hydraulic System Preoperational Test.............14.2-39 14.2.12.1.12 Fuel Hand ling and Vessel Servicing Equipmen t Preoperational Test...............................................................................
14.2-40 14.2.12.1.13 Low-Pressu re Core Spray System Pr eoperational Test.................14.2-41 14.2.12.1.14 High-Pressure Core Spr ay System Preoperational Test................14.2-42 14.2.12.1.15 Fuel Pool Cooling and Cleanup System Preoperational Test..........14.2-43 14.2.12.1.16 Leak Detection System Pre operational Test...............................14.2-43 14.2.12.1.17 Liqui d and Solid Radwaste System Preoperational Test................14.2-44 14.2.12.1.18 Reactor Protection System Preoperati onal Test..........................14.2-45 14.2.12.1.19 Neutron Monitoring System Pre operational Test.........................14.2-46 14.2.12.1.20 Traversing In-Core Probe System Preopera tional Test.................14.2-47 14.2.12.1.21 Rod Worth Minimizer System Preoperational Test......................14.2-47 14.2.12.1.22 Process Radiation Monitoring System Preoperational Test............14.2-48 14.2.12.1.23 Area Radiation Monito ring System Preoperational Test................14.2-49 14.2.12.1.24 Process Computer Interface System Preoperational Test...............14.2-50 14.2.12.1.25 Rod Sequence Control System Preoperati onal Test......................14.2-50 14.2.12.1.26 Remote Shutdown Preoperational Test....................................
14.2-51 14.2.12.1.27 Offgas System Preoperational Test.........................................
14.2-52 14.2.12.1.28 Environs Radiation Monitoring Preopera tional Test....................14.2-53 14.2.12.1.29 Main Steam Syst em Preoperational Test..................................
14.2-53 C OLUMBIA G ENERATING S TATION Amendment 61 F INAL S AFETY A NALYSIS R EPORT December 2011 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page LDCN-11-000 14-v 14.2.12.1.30 Radwaste Building Heating, Ventilating, and Air Conditioning System Preoperational Test
................................................... 14.2-54 14.2.12.1.31 Closed Cooling Water System Preoperational Test ...................... 14.2-55 14.2.12.1.32 Primary Containm ent Atmospheric Control System Preoperational Test (SYSTE M DEACTIVATED) ......................... 14.2-55 14.2.12.1.33 Primary Containment Cooling System Preoperational Test ............ 14.2-56 14.2.12.1.34 Primary Containment Instru ment Air Preoperational Test ............. 14.2-57 14.2.12.1.35 Primary Containmen t Atmospheric Monitoring System Preoperational Test ............................................................ 14.2-57 14.2.12.1.36 Standby Gas Treatment System Preoperational Test .................... 14.2-58 14.2.12.1.37 Loss of Power and Safety Testing Preoperational Test ................. 14.2-59 14.2.12.1.38 Instrument Powe r Preoperational Test .................................... 14.2-61 14.2.12.1.39 Emergency Lighting System Preoperational Test ........................ 14.2-61
14.2.12.1.40 Standby Alter nating Current Power System Preoperational Test ..... 14.2-62 14.2.12.1.41 250-V Direct Current Power System Preoperational Test .............. 14.2-63 14.2.12.1.42 125-V Direct Current Power System Preoperational Test .............. 14.2-64 14.2.12.1.43 24-V Direct Current Power System Preoperational Test ............... 14.2-64 14.2.12.1.44 Plant Service Water Sy stem Preoperational Test ........................ 14.2-65 14.2.12.1.45 Standby Service Water System Preoperational Test ..................... 14.2-66 14.2.12.1.46 Plant Communications System Preoperational Test ..................... 14.2-67 14.2.12.1.47 Reactor Building Emer gency Cooling System Preoperational Test ............................................................................... 14.2-67 14.2.12.1.48 Control, Cable, and Critical Switchgear Rooms Heating, Ventilating and Air Conditioning System Preoperational Test ......... 14.2-68 14.2.12.1.49 Standby Service Water Pump Hous e Heating and Ventilating System Preoperational Test
................................................... 14.2-68 14.2.12.1.50 Reactor Building Cr ane Preoperational Test ............................. 14.2-69 14.2.12.1.51 Primary Contai nment Integrated Leak Rate Preoperational Test ..... 14.2-70 14.2.12.1.52 Secondary Containment Integrated Leak Rate Preoperational Test ............................................................................... 14.2-71 14.2.12.1.53 Diesel Generator Bu ilding Heating and Ventilating System Preoperational Test ............................................................ 14.2-71 14.2.12.1.54 Seismic Monitoring System Preope rational Test ......................... 14.2-72 14.2.12.2 General Discussion of Startup Tests ........................................... 14.
2-72 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page LDC N-0 2-0 0 0 14-vi 14.2.12.3 Start up Test Procedures..........................................................14.
2-73 14.2.12.3.1 Test Number 1 - Chemical and Radioc hemical............................14.2-73 14.2.12.3.1.1 Purpose........................................................................14.
2-73 14.2.12.3.1.2 Prerequisites..................................................................14.2-73 14.2.12.3.1.3 Description....................................................................14.
2-73 14.2.12.3.1.4 Criteria.........................................................................14.
2-74 14.2.12.3.2 Test Number 2 -
Radiation Measurements..................................
14.2-74 14.2.12.3.2.1 Purpose........................................................................14.
2-74 14.2.12.3.2.2 Prerequisites..................................................................14.2-74 14.2.12.3.2.3 Description....................................................................14.
2-74 14.2.12.3.2.4 Criteria.........................................................................14.
2-75 14.2.12.3.3 Test Number 3 - Fuel Loading................................................
14.2-75 14.2.12.3.3.1 Purpose........................................................................14.
2-75 14.2.12.3.3.2 Prerequisites..................................................................14.2-75 14.2.12.3.3.3 Description....................................................................14.
2-76 14.2.12.3.3.4 Criteria.........................................................................14.
2-76 14.2.12.3.4 Test Number 4 -
Full Core Shutdown Margin..............................14.2-76 14.2.12.3.4.1 Purpose........................................................................14.
2-76 14.2.12.3.4.2 Prerequisites..................................................................14.2-76 14.2.12.3.4.3 Description....................................................................14.
2-77 14.2.12.3.4.4 Criteria.........................................................................14.
2-77 14.2.12.3.5 Test Number 5 -
Control Rod Drive System................................14.2-77 14.2.12.3.5.1 Purpose........................................................................14.
2-77 14.2.12.3.5.2 Prerequisites..................................................................14.2-77 14.2.12.3.5.3 Description....................................................................14.
2-78 14.2.12.3.5.4 Criteria.........................................................................14.
2-79 14.2.12.3.6 Test Numb er 6 - Source Range Monitor Performance and Control Rod Sequence..........................................................
14.2-80 14.2.12.3.6.1 Purpose........................................................................14.
2-80 14.2.12.3.6.2 Prerequisites..................................................................14.2-80 14.2.12.3.6.3 Description....................................................................14.
2-80 14.2.12.3.6.4 Criteria.........................................................................14.
2-80 14.2.12.3.7 Test Number 7...................................................................14.
2-81 14.2.12.3.8 Test Number 8...................................................................14.
2-81 14.2.12.3.9 Test Number 9...................................................................14.
2-81 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page LDC N-0 2-0 0 0 14-vii 14.2.12.3.10 Test Number 10 - In termediate Range Monitor System Performance....................................................................
14.2-81 14.2.12.3.10.1 Purpose.......................................................................14.
2-81 14.2.12.3.10.2 Prerequisites.................................................................14.2-81 14.2.12.3.10.3 Description...................................................................14.
2-81 14.2.12.3.10.4 Criteria.......................................................................14.
2-81 14.2.12.3.11 Test Number 11 - Local Power Range Monitor Calibration...........14.2-82 14.2.12.3.11.1 Purpose.......................................................................14.
2-82 14.2.12.3.11.2 Prerequisites.................................................................14.2-82 14.2.12.3.11.3 Description...................................................................14.
2-82 14.2.12.3.11.4 Criteria.......................................................................14.
2-82 14.2.12.3.12 Test Number 12 - Average Power Range Monitor Calibration........14.2-82 14.2.12.3.12.1 Purpose.......................................................................14.
2-82 14.2.12.3.12.2 Prerequisites.................................................................14.2-82 14.2.12.3.12.3 Description...................................................................14.
2-82 14.2.12.3.12.4 Criteria.......................................................................14.
2-83 14.2.12.3.13 Test Number 13 - Process Computer.......................................
14.2-83 14.2.12.3.13.1 Purpose.......................................................................14.
2-83 14.2.12.3.13.2 Prerequisites.................................................................14.2-83 14.2.12.3.13.3 Description...................................................................14.
2-83 14.2.12.3.13.4 Criteria.......................................................................14.
2-84 14.2.12.3.14 Test Number 14 - Reacto r Core Isolation Cooling System.............14.2-85 14.2.12.3.14.1 Purpose.......................................................................14.
2-85 14.2.12.3.14.2 Prerequisites.................................................................14.2-85 14.2.12.3.14.3 Description...................................................................14.
2-85 14.2.12.3.14.4 Criteria.......................................................................14.
2-86 14.2.12.3.15 Test Number 15................................................................14.
2-86 14.2.12.3.16 Test Nu mbers 16A and 16B..................................................14.
2-86 14.2.12.3.16.1 Test Number 16A - Selected Process Temperatures...................14.2-86 14.2.12.3.16.1.1 Purpose....................................................................14.
2-86 14.2.12.3.16.1.2 Prerequisites..............................................................14.2-87 14.2.12.3.16.1.3 Description................................................................14.2-87 14.2.12.3.16.1.4 Criteria.....................................................................14.
2-87 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
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Section Page LDC N-0 2-0 0 0 14-viii 14.2.12.3.16.2 Test Number 16B -
Water Level Referenc e Leg Temperature Measurement.................................................................14.2-88 14.2.12.3.16.2.1 Purpose....................................................................14.
2-88 14.2.12.3.16.2.2 Prerequisites..............................................................14.2-88 14.2.12.3.16.2.3 Description................................................................14.2-88 14.2.12.3.16.2.4 Criteria.....................................................................14.
2-89 14.2.12.3.17 Test Number 17 - System Expansion.......................................
14.2-89 14.2.12.3.17.1 Purpose.......................................................................14.
2-89 14.2.12.3.17.2 Prerequisites.................................................................14.2-89 14.2.12.3.17.3 Description...................................................................14.
2-89 14.2.12.3.17.4 Criteria.......................................................................14.
2-92 14.2.12.3.18 Test Number 18 -
Core Power Dist ribution...............................14.2-92 14.2.12.3.18.1 Purpose.......................................................................14.
2-92 14.2.12.3.18.2 Prerequisites.................................................................14.2-92 14.2.12.3.18.3 Description...................................................................14.
2-92 14.2.12.3.18.4 Criteria.......................................................................14.
2-93 14.2.12.3.19 Test Number 19 - Core Performance.......................................
14.2-93 14.2.12.3.19.1 Purpose.......................................................................14.
2-93 14.2.12.3.19.2 Prerequisites.................................................................14.2-93 14.2.12.3.19.3 Description...................................................................14.
2-94 14.2.12.3.19.4 Criteria.......................................................................14.
2-94 14.2.12.3.20 Test Number 20 - Steam Production.......................................
14.2-94 14.2.12.3.20.1 Purpose.......................................................................14.
2-94 14.2.12.3.20.2 Prerequisites.................................................................14.2-95 14.2.12.3.20.3 Description...................................................................14.
2-95 14.2.12.3.20.4 Criteria.......................................................................14.
2-95 14.2.12.3.21 Test Number 21 - Core Power-Vo id Mode................................14.2-96 14.2.12.3.21.1 Purpose.......................................................................14.
2-96 14.2.12.3.21.2 Prerequisites.................................................................14.2-96 14.2.12.3.21.3 Description...................................................................14.
2-96 14.2.12.3.21.4 Criteria.......................................................................14.
2-96 14.2.12.3.22 Test Number 22 - Pressure Regulator.....................................
14.2-96 14.2.12.3.22.1 Purpose.......................................................................14.
2-96 14.2.12.3.22.2 Prerequisites.................................................................14.2-96 14.2.12.3.22.3 Description...................................................................14.
2-97 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
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Section Page 14-ix 14.2.12.3.22.4 Criteria.......................................................................14.
2-97 14.2.12.3.23 Test Number 23 - Feedwater System.......................................
14.2-98 14.2.12.3.23.1 23A - Water Level Setpoint and Man ual Flow Changes..............14.2-98 14.2.12.3.23.1.1 Purpose....................................................................14.
2-98 14.2.12.3.23.1.2 Prerequisites..............................................................14.2-98 14.2.12.3.23.1.3 Description................................................................14.2-98 14.2.12.3.23.1.4 Criteria.....................................................................14.
2-98 14.2.12.3.23.2 23B - Loss of Feedwater Heating........................................14.2-100 14.2.12.3.23.2.1 Purpose....................................................................14.2-100 14.2.12.3.23.2.2 Prerequisites..............................................................14.2-100 14.2.12.3.23.2.3 Description................................................................14.2-100 14.2.12.3.23.2.4 Criteria.....................................................................14.2-100 14.2.12.3.23.3 22C - Feedwater Pump Trip..............................................14.2-101 14.2.12.3.23.3.1 Purpose....................................................................14.2-101 14.2.12.3.23.3.2 Prerequisites..............................................................14.2-101 14.2.12.3.23.3.3 Description................................................................14.2-101 14.2.12.3.23.3.4 Criteria.....................................................................14.2-101 14.2.12.3.23.4 23D - Maxi mum Feedwater Runout Capability.......................14.2-101 14.2.12.3.23.4.1 Purpose....................................................................14.2-101 14.2.12.3.23.4.2 Prerequisites..............................................................14.2-101 14.2.12.3.23.4.3 Description................................................................14.2-101 14.2.12.3.23.4.4 Criteria.....................................................................14.2-102 14.2.12.3.24 Test Number 24 -
Turbine Valve Surveillance............................
14.2-103 14.2.12.3.24.1 Purpose.......................................................................14.2-103 14.2.12.3.24.2 Prerequisites.................................................................14.2-103 14.2.12.3.24.3 Description...................................................................14.2-103 14.2.12.3.24.4 Criteria.......................................................................14.2-103 14.2.12.3.25 Test Number 25 - Ma in Steam Isolation Valves..........................
14.2-104 14.2.12.3.25.1 25A - Main Steam Isolation Valve Function Tests.....................14.2-104 14.2.12.3.25.1.1 Purpose....................................................................14.2-104 14.2.12.3.25.1.2 Prerequisites..............................................................14.2-104 14.2.12.3.25.1.3 Description................................................................14.2-104 14.2.12.3.25.1.4 Criteria.....................................................................14.2-104 14.2.12.3.25.2 25B - Full Reactor Isolation..............................................14.2-105 14.2.12.3.25.2.1 Purpose....................................................................14.2-105 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page 14-x 14.2.12.3.25.2.2 Prerequisites..............................................................14.2-105 14.2.12.3.25.2.3 Description................................................................14.2-105 14.2.12.3.25.2.4 Criteria.....................................................................14.2-105 14.2.12.3.26 Test Number 26 - Relief Valves.............................................14.
2-106 14.2.12.3.26.1 Purpose.......................................................................14.2-106 14.2.12.3.26.2 Prerequisites.................................................................14.2-106 14.2.12.3.26.3 Description...................................................................14.2-106 14.2.12.3.26.4 Criteria.......................................................................14.2-106 14.2.12.3.27 Test Number 27 - Turbine Trip and Generator Load Rejection.......14.2-107 14.2.12.3.27.1 Purpose.......................................................................14.2-107 14.2.12.3.27.2 Prerequisites.................................................................14.2-107 14.2.12.3.27.3 Description...................................................................14.2-107 14.2.12.3.27.4 Criteria.......................................................................14.2-108 14.2.12.3.28 Test Number 28 - Shutdown From Outside the Main Control Room............................................................................
14.2-109 14.2.12.3.28.1 Purpose.......................................................................14.2-109 14.2.12.3.28.2 Prerequisites.................................................................14.2-110 14.2.12.3.28.3 Description...................................................................14.2-110 14.2.12.3.28.4 Criteria.......................................................................14.2-110 14.2.12.3.29 Test Number 29 - Recirculation Flow Control...........................
14.2-110 14.2.12.3.29.1 29A - Valve Position Control.............................................14.2-110 14.2.12.3.29.1.1 Purpose....................................................................14.2-110 14.2.12.3.29.1.2 Prerequisites..............................................................14.2-110 14.2.12.3.29.1.3 Description................................................................14.2-110 14.2.12.3.29.1.4 Criteria.....................................................................14.2-111 14.2.12.3.29.2 29B - Recirc ulation Flow Loop Control.................................14.2-112 14.2.12.3.29.2.1 Purpose....................................................................14.2-112 14.2.12.3.29.2.2 Prerequisites..............................................................14.2-112 14.2.12.3.29.2.3 Description................................................................14.2-112 14.2.12.3.29.2.4 Criteria.....................................................................14.2-113 14.2.12.3.30 Test Number 30 - Recirculation System...................................14.2-115 14.2.12.3.30.1 30A - One Pump Trip......................................................14.2-115 14.2.12.3.30.1.1 Purpose....................................................................14.2-115 14.2.12.3.30.1.2 Prerequisites..............................................................14.2-115 14.2.12.3.30.1.3 Description................................................................14.2-115 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page 14-xi 14.2.12.3.30.1.4 Criteria.....................................................................14.2-115 14.2.12.3.30.2 30B - Recirculation Trip of Two Pumps................................14.2-116 14.2.12.3.30.2.1 Purpose....................................................................14.2-116 14.2.12.3.30.2.2 Prerequisites..............................................................14.2-116 14.2.12.3.30.2.3 Description................................................................14.2-116 14.2.12.3.30.2.4 Criteria.....................................................................14.2-116 14.2.12.3.30.3 30C - System Performance................................................14.2-117 14.2.12.3.30.3.1 Purpose....................................................................14.2-117 14.2.12.3.30.3.2 Prerequisites..............................................................14.2-117 14.2.12.3.30.3.3 Description................................................................14.2-117 14.2.12.3.30.3.4 Criteria.....................................................................14.2-117 14.2.12.3.30.4 30D - Recirculation Pump Runback.....................................14.2-118 14.2.12.3.30.4.1 Purpose....................................................................14.2-118 14.2.12.3.30.4.2 Prerequisites..............................................................14.2-118 14.2.12.3.30.4.3 Description................................................................14.2-118 14.2.12.3.30.4.4 Criteria.....................................................................14.2-118 14.2.12.3.30.5 30E - Reci rculation System Cavitation..................................14.2-118 14.2.12.3.30.5.1 Purpose....................................................................14.2-118 14.2.12.3.30.5.2 Prerequisites..............................................................14.2-118 14.2.12.3.30.5.3 Description................................................................14.2-118 14.2.12.3.30.5.4 Criteria.....................................................................14.2-119 14.2.12.3.31 Test Number 31 - Loss of Turbine-Generator and Offsite Power.....14.2-119 14.2.12.3.31.1 Purpose.......................................................................14.2-119 14.2.12.3.31.2 Prerequisites.................................................................14.2-119 14.2.12.3.31.3 Description...................................................................14.2-119 14.2.12.3.31.4 Criteria.......................................................................14.2-119 14.2.12.3.32 Not Applicable.................................................................14.2-120 14.2.12.3.33 Test Number 33 - Piping Vibration.........................................14.
2-120 14.2.12.3.33.1 Purpose.......................................................................14.2-120 14.2.12.3.33.2 Prerequisites.................................................................14.2-120 14.2.12.3.33.3 Description...................................................................14.2-120 14.2.12.3.33.4 Criteria.......................................................................14.2-120 14.2.12.3.34 Test Number 34 - Reactor Pressure Vessel Internals Vibration.......14.2-121 14.2.12.3.34.1 Purpose.......................................................................14.2-121 14.2.12.3.34.2 Prerequisites.................................................................14.2-121 C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 Chapter 14 INITIAL TEST PROGRAM
TABLE OF CONTENTS (Continued)
Section Page 14-xii 14.2.12.3.34.3 Description...................................................................14.2-121 14.2.12.3.34.4 Criteria.......................................................................14.2-122 14.2.12.3.35 Test Number 35 - Recirculation System Flow Calibration..............14.2-122 14.2.12.3.35.1 Purpose.......................................................................14.2-122 14.2.12.3.35.2 Prerequisites.................................................................14.2-122 14.2.12.3.35.3 Description...................................................................14.2-122 14.2.12.3.35.4 Criteria.......................................................................14.2-123 14.2.12.3.36 Test Number 70 - Re actor Water Cleanup System.......................14.2-123 14.2.12.3.36.1 Purpose.......................................................................14.2-123 14.2.12.3.36.2 Prerequisites.................................................................14.2-123 14.2.12.3.36.3 Description...................................................................14.2-123 14.2.12.3.36.4 Criteria.......................................................................14.2-123 14.2.12.3.37 Test Number 71 - Re sidual Heat Removal System.......................14.2-124 14.2.12.3.37.1 Purpose.......................................................................14.2-124 14.2.12.3.37.2 Prerequisites.................................................................14.2-124 14.2.12.3.37.3 Description...................................................................14.2-124 14.2.12.3.37.4 Criteria.......................................................................14.2-124 14.2.12.3.38 Test Number 72 - Drywel l Atmosphere Cooling System................14.2-125 14.2.12.3.38.1 Purpose.......................................................................14.2-125 14.2.12.3.38.2 Prerequisites.................................................................14.2-125 14.2.12.3.38.3 Description...................................................................14.2-125 14.2.12.3.38.4 Criteria.......................................................................14.2-125 14.2.12.3.39 Test Number 73 - Cooling Water Systems.................................14.2-125 14.2.12.3.39.1 Purpose.......................................................................14.2-125 14.2.12.3.39.2 Prerequisites.................................................................14.2-125 14.2.12.3.39.3 Description...................................................................14.2-125 14.2.12.3.39.4 Criteria.......................................................................14.2-126 14.2.12.3.40 Test Number 74 - Offgas System............................................14.2-126 14.2.12.3.40.1 Purpose.......................................................................14.2-126 14.2.12.3.40.2 Prerequisites.................................................................14.2-126 14.2.12.3.40.3 Description...................................................................14.2-126 14.2.12.3.40.4 Criteria.......................................................................14.2-127 C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 Chapter 14 INITIAL TEST PROGRAM
LIST OF TABLES Number Title Page 14-xiii 14.2-1 Preoperational Tests............................................................
14.2-129 14.2-2 Major Plant Transients.........................................................
14.2-132 14.2-3 Stability Tests....................................................................14.
2-133 14.2-4 Power Ascension Test Program...............................................14.2-134
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 Chapter 14 INITIAL TEST PROGRAM
LIST OF FIGURES Number Title LDC N-9 9-0 0 0 14-xiv 14.2-1 Test Condition Region Definition 14.2-2 Test and Startup Relation to Other Energy Northwest Departments 14.2-3 CGS Startup Organization
14.2-4 Preoperational Test Schedule
14.2-5 RCIC Acceptance Criteria Curves for Capacity and Actuation Time
14.2-6 Maximum Acceptable Drive Flow Response
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.1-1 Chapter 14 INITIAL TEST PROGRAM 14.1 SPECIFIC INFORMATION IN CLUDED IN PRELIMINARY SAFETY ANALYSIS REPORTS The initial test program overall test objectives and general pr erequisites were previously provided in the Preliminary Safe ty Analysis Report (PSAR). The technical aspects of the initial test program are described in Section 14.2 in sufficient detail to show that the test program adequately verifies th e functional requireme nts of plant structures, systems, and components such that th e safety of the plant will not be dependent on untes ted structures, systems, or components.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-1 14.2 SYSTEM LINEUP, PREOPERATI ONAL, AND INITIAL STARTUP TEST PROGRAM The italicized information is historical and was provided to support the application for an operating license.
The initial test program consisted of a series of tests categoriz ed as system lineup testing, preoperational, and initial start up tests. The system lineup testing determines correct installation and functional operab ility of equipment. Preopera tional tests are those tests normally conducted prior to fuel loading to demonstrate the capability of plant systems to meet performance requirements.
Initial startup tests began with fuel loading and demonstrated the capability of the integrated plant to meet performance requirements.
14.2.1
SUMMARY
OF TEST PROGRAM AND OBJECTIVES
14.2.1.1 Initial Test Program Objectives The objectives of the initial test program are to
- a. Ensure that the constructi on is complete and acceptable,
- b. Demonstrate the capability of struct ures, components, and systems to meet performance requirements,
- c. Effect fuel loading in a safe manner,
- d. Demonstrate, where pr actical, that the plant is capable of withstanding anticipated transients and postulated accidents,
- e. Evaluate and demonstrate, to the extent possible, pl ant operating pr ocedures to provide assurance that the operating group is knowledgeabl e about the plant and procedures and fully prepared to operate the facility in a safe manner, and
- f. Bring the plant to rated capac ity and sustained power operation.
14.2.1.2 Initial Test Program Summaries The three categories of tests in the in itial test program are summarized below:
- a. System lineup tests such as pump and valve tests, m echanical actuation to verify proper installation, and electrical continuity verifications, are those tests which demonstrate that components are correctly installed and operational.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-2 b. Preoperational tests conduc ted prior to fuel loading to demonstrate that the plant systems have been properly desi gned and that they meet performance requirements.
- c. Startup tests consist of fuel loading, precritical tests, low power tests, and power ascension tests that ensure fuel loading in a safe manner, confirm the design bases, demonstrate where practical that the plant is capable of withstanding the anticipated transients and postulated acci dents, and ensure t hat the plant is safely brought to rated capacity and sustained power operation.
14.2.1.3 Description of System Lineup Tests Typical system lineup tests generally include but are not limited to the following:
- a. Chemical cleaning and flushing of system s, tanks, and vessels,
- b. Electrical equipment to test and/or energize, e.g., groundi ng, relays, circuit breaker operation and controls, continuity, megger, phasing, high potential
measurements, and buses,
- c. Initial adjustment, bumping, and running of rotating equipment,
- d. Checking control and interlock functions of instruments, relays, and control devices,
- e. Calibrating instruments and checking or setting initial trip setpoints,
- f. Pneumatic testing of instruments and service air system and cleanout of lines,
- g. Checking and adjusting reli ef and safety valves,
- h. Complete tests of safety-related motor-operated valves including adjusting torque switches and limit switches, ch ecking all interlocks and controls, measuring motor current and operati ng speed, and checking leaktightness of stem packing and valve seat during hydrotests; and comple te tests of the nuclear steam supply system (NSSS) control sy stems including checking all interlocks and controls, adjusting limit switches, measuring operati ng speed, checking leaktightness of pneuma tic operators, and checking for proper operation of controllers, pilot so lenoids, etc., and
- i. Other tests and verifications such as structural, leaktight ness, and vibration.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-3 14.2.1.4 Description of Preoperational Tests A listing of the preoperational tests is provided in Table 14.2-1. The general objectives of the preoperational test phas e are as follows:
- a. Ensure that test acceptance criteria are met,
- b. Provide documentation of the performance and safety of equipment and systems, c. Provide baseline test and operating data on equipment and systems for future reference, d. Run-in of a system for a sufficient period so that any design, manufacturing, or installation defects can be detected and corrected,
- e. Ensure that plant system s operate together on an inte grated basis to the extent possible,
- f. Give maximum opportunity to the perm anent plant operating staff to obtain practical experience in the operation and maintenance of equipment and systems,
- g. Establish safe and efficient normal, abnormal, and emergency operating procedures, to the extent possible,
- h. Establish and evaluate survei llance testing procedures, and
- i. Demonstrate that systems and safety e quipment are operational and that it is possible to proceed to fuel loading and to the Startup Phase.
14.2.1.5 Description of Startup Tests The Power Ascension Test Phase (PATP) begins after the Preoperational Test Phase has been completed. The Power Ascensi on Test Phase begins with fuel loading and extends to commercial operation. This phase is s ubdivided into the following four parts:
- a. Open vessel testing (fuel loading and shutdown power level tests), b. Initial heatup,
- c. Power testing, and
- d. Warranty demonstration.
The tests conducted during the Power Ascension Test Phase consis t of major plant transients (Table 14.2-2
), stability tests (Table 14.2-3
), and a remainder of tests which are directed C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-4 towards demonstrating correct pe rformance of the nuclear boile r and numerous auxiliary plant systems while at power. Certai n tests may be identified with mo re than one class of test. Table 14.2-4 shows the complete Power Ascension Test Program.
Figure 14.2-1 provides test conditions region definition.
The general objectives of the Power Ascension Test Phase are as follows:
- a. Achieve an orderly and safe initial core loading, b. Accomplish all testing and measuremen ts necessary to determine that the approach to initial criticality and subsequent power ascens ion is safe and orderly, c. Conduct low power physics tests sufficient to ensure that test acceptance criteria have been met,
- d. Conduct initial heatup and hot functional testing so t hat hot integrated operation of all systems is shown to meet test acceptance criteria,
- e. Conduct an orderly and sa fe power ascension program, with requisite physics and systems testing, to ensure that the plant operating at power meets test acceptance criteria, and
- f. Conduct a successful warr anty demonstration program.
14.2.2 ORGANIZATION AND STAFFING
14.2.2.1 General The Energy Northwest Test and St artup Program is administered by two entities with distinct levels of responsibility and two distinct organizations.
For the system lineup test phase and the pre operational test phase, the Test Working Group (TWG) provides review, approval , and planning of general Test and Startup Program activities and the results of those activities. The Test and Startup organization and qualified members of other organizations represented on the TW G provide the necessary development, implementation, and analysis of Test and Startup Pr ogram activities at the working level.
For the Power Ascension Test Phase, the Plant Operations Committee (POC) provides review and planning of the test program and evaluates the test re sults. The Plant Manager approves the procedures and final test re ports. The implementation of the PATP is achieved with the normal plant operations crew operating the plant and test engineers under the direction of the Reactor Engineering Supervisor coordinating the test activities.
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-5 14.2.2.2 Definitions The definitions of phrases used in this secti on and throughout this chapt er are as follows:
- a. Test Working Group (TWG) - a project onsite administrative body whose membership consists of pe rsonnel representing organizati ons directly responsible for preparation and performance of test ing and startup during the system lineup and preoperational test phases. This group provides review and approval of test preparation and perf ormance activities.
- b. Power Generation - an Energy Northwes t organization within the Operations Directorate with responsibility for devel opment and implementation of the Test and Startup Program.
- c. Columbia Generating Station (CGS) Test and Startup - a Power Generation division with responsibility for development and implementation of the CGS Test and Startup Program.
- d. CGS Plant Organization - a Power Gene ration division with responsibility to startup, operate, and maintain CGS in co mpliance with Federal, State, local, and owner requirements.
- e. CGS Plant Operations Committee (POC) - refer to definition in Section 13.4.1. The POC reviews the activities of the Power Ascensi on Test Phase.
- f. Test and Startup Manager - the Po wer Generation Division Manager with responsibility for implementation of the CGS Test and Startup Program.
- g. Test and Startup Program - the program that encompasses the transition from construction to commercial operation and consists of system lineup testing, preoperational testing, and power as cension testing.
- h. Test and Startup Progr am Manual - the manual that defines generic administrative policy and procedures for th e initial testing and startup of Energy Northwest nuclear facilities.
- i. Test and Startup Instructi ons - the specific in structions required to implement the Test and Startup Program for an individual project.
- j. Plant Procedure Manual (PPM) - the Plant Manager approved procedures for operating the plant. The PPMs include the test procedures for the PATP.
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-6 14.2.2.3 Test and Startup Program Or ganization and the System Lineup and Preoperational Test Program 14.2.2.3.1 General
Power Generation is an organization within the En ergy Northwest Operations Directorate.
Relative to the Program, Power Generation is responsible for development and administration of plans, policies, and administ rative procedures; procurement of test equipment and other test-related resources, and assignment of the CGS Test and Startup Manager. The Power Generation organization and its relationship to ot her Energy Northwest organizations is shown in Figure 14.2-2. 14.2.2.3.2 Responsibilities of CG S Test and Startup Division
CGS Test and Startup is a Division of the Powe r Generation organization. The CGS Test and Startup Manager manages an organi zation comprised of Energy Northwest test engineers and test technicians augmen ted by test personnel from the ar chitect-engineer, the NSSS supplier, and others as contractually established. The CGS Test and St artup Manager is responsible for the development and implementation of the CGS Test and Startup program and those responsibilities are de scribed in Section 14.2.2.3.3. The CGS Test and Startup staff organization is shown in Figure 14.2-3. 14.2.2.3.3 CGS Test and Startup Department Position Responsibilities
14.2.2.3.3.1 CGS Test and Startup Manager. a. Chairman, TWG;
- b. Develop plans, schedules, methods, procedures, and dat a systems for the testing and evaluation of all plant equipment and systems to permit acceptance and licensing;
- c. Administer and coordinate the testing activities with other organizations involved in the Test and Startup Program;
- d. Manage and direct assigned test personnel in activities relating to the attainment of Test and Startup Program objectives;
- e. Manage and direct assigned test personnel to establish qualitative and quantitative acceptance criter ia and develop test procedur es to direct and guide performance of testing, and
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-7 f. Provide recommendations and effect actions to elimi nate equipment or system deficiencies as determined by Test and Startup Pr ogram criteria which could adversely affect performance of safety-related functions.
14.2.2.3.3.2 CGS Test Group Manager. a. Represent Test and Startup on the TWG;
- b. Coordinate the activities of Test Group Supervisors and test engineers during the Test and Startup Program;
- c. Develop, monitor, and coordinate the preparation and impl ementation of plans, schedules, methods, and pro cedures for testing and evaluation of plant systems and components for verification of performance and acceptance;
- d. Maintain surveillance o ver testing perfor med by Energy Northwest and others, including system and equipment tests, and calibration of instrumentation;
- e. Identify problem areas and recomme nd actions where deficiencies could adversely affect the performance, sa fety-related func tions, or operating efficiency;
- f. Assist in preparation of program status and othe r Test and Startup Program related reports, and
- g. Assume the responsibilities of the Test and Startup Manager as described in the Test and Startup Program Manual (T SPM) during his absence and all other responsibilities speci fically delegated.
14.2.2.3.3.3 CGS Te st Group Supervisor. Test Group Supervisors are assigned lead technical responsibility for testing.
General Test Group Supervisor s' duties are as follows:
- a. Supervise the activities of assigned test engineers;
- b. Review and, where appropriate, appro ve test procedures, field changes to procedures and test results, and make recommendations to the Test Group Managers or Startup Mana ger, as appropriate;
- c. Set schedules and priorities for assigned Test Engineers and assist them with problem resolution;
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-8 d. With other Test Group Supervisors and the Test Group Manager or Startup Manager, as appropriate, plan and coordinate start up activities and provide assistance;
- e. Advise the Test Group Manager or Test and Startup, as appropriate, on all matters concerning testing within th eir group and if required, attend TWG meetings for this purpose;
- f. Act for the Test Group Manager or Test and Startup Manager, as appropriate, when so delegated;
- g. Prepare for and perform testing as required to support the Test and Startup Program;
- h. Coordinate the identification and docum entation of design problems and their resolution, and
- i. Advise the Test Group Manager or Test and Startup Manager, as appropriate, regarding current and future manpower requirements impacting the testing effort.
14.2.2.3.3.4 CGS Test Engineers. Test engineers provide for the routine development and implementation of testing. General test engineer dutie s are as follows:
- a. Prepare assigned test procedures,
- b. Review tests and inspecti ons prepared by others fo r application to assigned testing responsibilities,
- c. Provide direction during performance of system and component testing, and
- d. Identify problem areas and recomme nd actions where deficiencies could adversely affect performance of safety-rel ated functions or operating efficiency.
14.2.2.4 Plant Operations Organization and the Power Ascension Test Program The PATP will be carried out by the plant operations organiza tion using test procedures developed and approved according to the requirements of the PPM. The PATP procedures were prepared by members of the plant technical department under the supervision of the
Reactor Engineering Supervisor. Technica l expertise from other Energy Northwest organizations and from the General Electric Company (GE), the NSSS vendor, was used whenever necessary. Review of these procedures and scheduling of the test activities will be carried out by the POC and approved by the Plant Manager. The Reactor Engineering C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-9 Supervisor will direct the PATP te st engineers in the completion of testing according to the POC schedule.
14.2.2.5 Test Working Group 14.2.2.5.1 System Lineup and Preoperational Test Program
The purpose of the TWG, a composite of re presentatives from or ganizations directly responsible for preparati on, performance, and review of Test and Startup Program activities, is to provide a means for a coordinated review of all testing concerns and ensuring all obligations to the Test and Startup Program are met by the or ganizations represented.
The TWG provides review and appr oval of all activities proposed and the results thereof as appropriate. All decisions and approvals or recommendations of the group are included in the minutes of the meetings. Matte rs requiring approval by the TW G includes, but are not limited to
- a. System lineup procedures,
- b. Preoperational test procedures, c. Changes to test procedures, and
- d. Results of testing.
14.2.2.5.2 Membership and Responsibility of the Test Working Group
The TWG membership consist of organizations that have a direct support function for conduct or development of testing.
The CGS Test and Startup Manager is Chairman of the TWG and is responsible for convening and conducting TWG meetings on the administr ative and technical content of program activities.
The Test Group Manager is res ponsible for providing a techni cal review of the proposed activities, technical documents, and their re sults. The Test Group Manager serves as Chairman during the absence of the Test and Startup Manager.
The CGS Plant Manager is responsible for providing an operational review of test documents and for submitting safety-related documents to the POC for review and for communicating the committee's decisions to the TWG. The Plant Manager provides detailed plant operating procedures and surveillance pro cedures to be used for plant operation and testing during the Test and Startup Program system lin eup and preoperati onal test phase.
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-10 The plant quality assurance repr esentative to the TWG shall be responsible for review of proposed activities, test proce dures, and test results as required by the Operational Quality Assurance Program Description (OQAPD).
The project engineering repres entative is responsible for obt aining a technical review of proposed activities and test documents by as signed project enginee rs and for providing a working relationship with Ener gy Northwest and architect-engi neering organizations to aid resolution of testing concerns.
Conditional Members are representative of any organization having responsibility and/or expertise in the area of the TWG meeting agenda. In this situation the repr esentative will be requested to attend the meeting by the TWG chairman.
14.2.2.6 Plant Organization Functions and Responsibilities During All Testing and Plant Operations The plant organization has overa ll responsibility for the safe and efficient operation of plant systems and equipment, from provisional acceptance through commercial operation including responsibility for maintenance and operational control. Plant organization responsibilities in supporting the Test and Startup Prog ram are discussed in Section 14.2.2.7.1.
The responsibility of the plant organization representative to the TWG is defined in Section 14.2.2.5.2.
14.2.2.7 Energy Northwest Support of the Test and Startup Program 14.2.2.7.1 Plant Organization
In addition to the responsibilit ies described in Section 14.2.2.6 , the plant operating, technical, and maintenance sections provide manpower for development, implementation, and review of testing.
14.2.2.7.1.1 Su pport During Test and Startup Program Development. Assistance during the development of the Test and St artup Program is provided formally through the plant organization's TWG representative and through the POC. Input to test procedures and other testing documentation by the plant staff ensures that
- a. The operational requirements of the test procedures are bas ed on the knowledge and experience of the operating staff, b. The technical considerations receive th e review of the Plant Technical Staff, and
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 LDC N-0 2-0 0 0 14.2-11 c. Important nuclear and opera tional safety considerations receive attention by the plant organization.
14.2.2.7.1.2 Suppor t During Testing. Detailed review and analys is of system lineup and preoperational test results will be performed by the plant technical section and/or plant operations section where their particular expertise is deemed nece ssary by the plant representative to the TWG to support approvals of completed system lineup and preoperational tests. Detailed review and analysis of PAT P test results will be carried out by the test engineers of the plant operations technical department and w ill receive final review through the POC and final approval by the Plant Manager.
14.2.2.7.2 CGS Program
The CGS Program Director is re sponsible for the performance of the organizations involved in the design, procurement, and c onstruction of generating projects. The Program Director supports the Test and Startup Program by providing and implemen ting project control systems, project engineering services, and engineering support services.
The CGS Program Director suppor ts the Test and Startup Program by maintaining a high level of current status information available to the startup program or ganizations to ensure that all startup program schedu ling and preparation is based on an accurate assessment of the condition of systems and equipment being readied for testing. The Program Director provides liaison with Construction Management for the pr ovision of construction craft support for the implementation of various system lineup and preoperational tests.
14.2.2.7.3 Plant Quality Assurance
The functions of the plant Quality Assurance organization during the Te st and Startup Program will be to survey ongoing efforts to determine that the controls required by vari ous regulations, guides, and standards are effectively implemented.
The activities of the TWG will be monitored to ensure that the proper degrees of control for safety-related activities are being maintained and that required activities are completed when they are prerequisite to another testing activity.
14.2.2.8 Architect-Engineer Support of the Test and Startup Program Burns and Roe, Inc., is responsib le for providing engineering services required to ensure timely completion of construction testing and equipment turnover for provisional acceptance and system turnover. Burns and Roe also provides system-oriented engin eers to assist the CGS Test and Startup Divisions, as requested by Energy Northwest technical direction and/or advice and consultation during system and component testing through preope rational testing.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-12 14.2.2.9 General Electric Support of the Test and Startup Program General Electric is the supplier of the boiling water reactor (BWR) NS SS for the CGS plant.
General Electric is responsible for generic and specific CGS desi gns and for the supply of the NSSS. During the construction phase of the plant cycle, the GE Reside nt Site Manager is responsible for all NSSS equipm ent disposition. When the star tup testing phase of the project begins after fuel load, the responsibility of GE-NSSS activities are assigned to the Preoperational and Startup group. The GE Preoperational and Startup sta ff responsibilities are outlined below.
14.2.2.9.1 Staff Responsibilities
14.2.2.9.1.1 General Elect ric Operations Manager. The GE Operations Manager is the senior NSSS vendor representative onsite at or near official fuel loading, and is the official site spokesman for GE for preoperational and start up testing concerns and requirements. The Operations Manager coordinates with the Startup Superintendent for the performance of his duties, which are as follows:
- a. Reviewing all NSSS test procedures, including changes to test procedures, and test results as a conditional member of TWG and POC,
- b. Providing technical direc tion to the station staff,
- c. Managing the activities of the GE site personnel in providing technical direction to CGS personnel in the testing and operation of GE-supplied systems,
- d. Providing liaison between the site and the GE San Jose home office to provide rapid and effective solution to prob lems that cannot be solved onsite,
- e. Participating as a conditional memb er of the TWG when required, and
- f. Reviewing test procedures for the POC.
14.2.2.9.1.2 General Electri c Operations Superintendent. The GE Operati ons Superintendent is responsible to the GE Op erations Manager for supervis ing the activities of GE Shift Superintendents. He works directly with th e CGS Operations Manager in providing GE technical direction to the operating organization.
14.2.2.9.1.3 General Elect ric Shift Superintendents. The GE shift superintendents provide technical direction to CGS shift personnel in th e testing and operation of GE-supplied systems.
They provide 24-hr per day shift coverage as required beginni ng with fuel loading. They report to the GE Opera tions Superintendent.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-13 14.2.2.9.1.4 General Electric Lead Engineer - Startup Test, Design, and Analysis. The GE lead engineer - Startup Test, Design, and Analysis, is responsible to the GE Operations Manager for supervising the GE shift engineer s and for verifying core physics parameters and characteristics and documenting that performance of the NSSS and components conform to test acceptance criteria.
The lead engineer works with the CGS technical department to c oordinate and effect implementation of the PATP instrumentation including special test equipment required to confirm these acceptance criteria.
14.2.2.10 Qualifications of Personnel Supporting the Test and Star tup Program The qualifications described in th is section are for those pers ons having authority to direct testing, review and approve test documentation and results, or otherwis e have direct influence on the conduct of testing and quality of acquired data. Although other personnel, specifically GE, Burns and Roe, and Energy No rthwest technical specialists, are also involved in these processes, they are under the direction of individuals whose qualifications are described herein and who review and approve all Test and Startup Program activities.
14.2.2.10.1 Test and Star tup Program Department Personnel Qualifications
- a. At the time of appointment to the active position, the CGS Test and Startup Manager shall have 10 years of responsib le thermal power plant experience such as, but not limited to, managerial, technical, or administrative positions, of which a minimum of 3 years shall be nuclear power plant experience.
A maximum of 4 years of th e remaining 7 years of experience may be fulfilled by academic training on a one-t o-one basis. This academi c training shall be in engineering or the individual shall have acquired the experience and training
normally required for exami nation by the NRC for a senior operator license whether or not the examination is taken.
- b. Minimum qualifications for Test Group Manager are a B.S. degree in engineering or related field and 6 years of applicable experience, at least 3 of which are in testing or operation of nuclear power generati on, propulsion, or similar scale test or pro duction facilities. Related exp erience may be substituted for academic requirements when the c andidate's professiona l background and level of achievement clearly demonstrate capabilities to fill the position.
Previous preoperational test ing experience is requir ed. A good understanding of quality assurance and regulatory require ments and an ability to effectively communicate with others are necessities.
A demonstrated technical leadership in his discipline and necessary work exper ience at the Test Group Supervisor or equivalent level is eviden ce of required proficiency.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-14 c. Minimum qualifications for Test Group Supervisor are a B.S. degree in engineering or related field and 5 years of applicable experience, at least 2 of which are in testing or operation of nuclear power generati on, propulsion, or similar scale test or pro duction facilities. Related exp erience may be substituted for academic requirements when the c andidate's professiona l background and level of achievement clearly demonstrate capabilities to fill the position.
Previous preoperational test ing experience is requir ed. A good understanding of quality assurance and regulatory require ments and an ability to effectively communicate with others are necessities.
A demonstrated technical leadership in his discipline and necessary work experience at the Se nior Test Engineer or equivalent level is eviden ce of required proficiency.
- d. Minimum qualifications for a Test Engi neer directing preope rational tests are a B.S. degree in engineering or related field or a gr aduate of a technical or vocational school in an e ngineering or related field and 2 years of related experience. Related exper ience above the required mi nimum may be substituted for academic requirements when the candi date's record for performance clearly indicates the ability to fill the positio n without question.
A good understanding of engineering principles and the ability to understand new concepts and to effectively communicate w ith others is a necessity.
Minimum requirements for a Test Engineer directing startup tests are a B.S.
degree in engineering or related field and 2 years of related experience or a graduate of a technical or vocational school in an engi neering or related field, and 3 years of related experience.
Related experience above the required minimum may be substituted for academi c requirements when the candidate's record for performance clearly indicate s the ability to fill the position without question. A good un derstanding of engineering principles and the ability to understand new concepts and to effectively communica te with others is a necessity.
14.2.2.10.2 Plant Organization Personnel Qualifications
Qualifications of some plant personnel are discussed in Section 13.1.3.
14.2.3 TEST PROCEDURES
14.2.3.1 Development of Test Procedures Test Procedures are de veloped by the CGS Test and Startup or Plant Operations Department to provide a detailed method to demonstrate the capability of the system to perform its design function under anticipated ope rating and accident condition.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-15 General Electric Company as supplier of the NSSS provides test progr am specifications and instructions from which Energy Northwest prepares the preoperational and initial startup test procedures for systems supplied by GE.
Architect-Engineer and Vendors Technical assistance is provided by Burns and Roe and vendor t echnical representatives as deemed necessary.
14.2.3.1.1 Incorporation of Plant Procedures
The following program will be implemented at CGS to utilize and qualify plant operating procedures dur ing testing.
- a. Plant procedures required to support testing will have been prepared and approved before preoperati onal testing begins on th e system using the best information available from the principal designer and responsible equipment suppliers.
- b. Preoperational test pr ocedures will use plant operating and emergency procedures as near ly as possible.
- c. Using the results of preoperational te sting, including the us e-testing of plant procedures where practica l, the plant procedures required to s upport startup testing will be updated and r evised before startup testi ng of applicable systems.
Exceptions to this program will be those approved plant procedures required to be verified during the startup phase.
- d. Startup test procedures will be developed using the results of preoperational testing and updated plant procedures.
14.2.3.1.2 Format of Test Procedures
14.2.3.1.2.1 Preope rational Test Phase. The minimum content requirements for CGS Preoperational test proc edures are specified in the Energy Northwest TSPM. The format for CGS test procedures is specifie d in the CGS TSPM. The resu lting format and content is the following:
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-16 a. Preoperational Test Procedure Format
- 1. Purpose A concise description of the objectives of the test, including such test
requirements as component functions to be checked and testing under normal or simulated conditions to ver ify readiness for system startup and operation, and system tests to confirm that the performance of the system is in compliance with all applicable design requirements.
- 2. Prerequisites Provisions necessary for performance of the test. Conditions that should exist prior to start of the test. Instructions given to identify required operational status of the plant and interfacing systems, environmental conditions, and individual component status requirements, including verification of the following:
(a) Components and systems being te sted have been turned over and open deficiencies will not affect the performance of the test, (b) System lineup testing on compone nts, included in the test, is complete, (c) Necessary support sy stems are available, and
(d) For control system testing, the other principal control systems are in appropriate operating modes fo r the given test conditions.
- 3. Limits and Precautions Special precautions required for safety of personnel and equipment or needed to ensure a meaningful te st and satisfactory performance of testing. 4. Special Equipment A list of special material and equipment for the performance of the test.
- 5. Procedure A step by step procedure for pe rforming the test. Plant operating procedures will be utilized whenever practicable for the operation of C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-17 systems and equipment during testing and for returning the system to normal after completion of testing. Ab normal procedures will be utilized as required to supplement normal pl ant operating procedures. Data collection will be part of the procedure steps.
- 6. Restoration Includes those steps necessary to return the system to a normal operating or tagged status. This may include re moval of special test instruments, temporary equipment, electrical jumpers, valve lineups, etc.
- 7. Acceptance Criteria The criteria against which the success or failure of the test will be judged must be identified. In some instan ces, these will be qualitative criteria, e.g., given event does or does not o ccur. In other cases, quantitative values can be designated as acceptance criteria.
(a) All quantitative acceptance crit eria shall include suitable tolerances, and
(b) A readily apparent correlation should exist to cross-reference among procedure steps, data, and acceptance criteria.
- 8. References A listing of all material required fo r the preparation and performance of the test. This should include pi ping and instrumentation drawings, electrical elementary drawings, ve ndor instruction manuals, applicable FSAR sections, contract specifications, and applicable codes, standards or guides, and applicabl e plant procedures.
14.2.3.1.2.2 Power Ascension Test Phase. All PATP procedures will be formatted according to the PPM.
14.2.3.2 Review of Test Procedures Each member of the TWG ensures test procedures will provide for review with respect to that member's organizational area of responsibility. Power ascensi on test procedures will be reviewed by the POC.
Comments submitted by TWG membe rs will be evaluated by the TWG and the test procedure revised accordingly. After discussion of the resulting version, the decision to reject, accept, or C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-18 accept with modification, will be obtained by consensus of the membership of the TWG. In the event the TWG cannot reach a consensus, the Chairman shall prov ide resolution or a method for resolving the issue to the appropriate division manageme nt for review and concurrence.
The results of the POC review of PATP will be approved by the Plant Manager.
The qualifications of the individuals or organizati on representatives review ing test procedures are described in Section 14.2.2.10. The administrative procedures governing the test procedure review proce ss are contained in the CGS TSPM. These procedures cover the mechanism for review and comment resolution, documentation of this review, and method of in dication for the review status of a test procedure.
14.2.3.3 Approval of Test Procedures Test procedures will be approved by the TWG Chairman by means of consensus of the TWG membership after review of the test procedure as desc ribed in Section 14.2.3.2. Power ascension test procedures will be reviewed by the POC in a similar manner.
Individual test procedures w ill be approved by the chairman of the TWG or POC/Plant Manager, as appropriate. The consensus of the two committees were contained in the meeting minutes.
The administrative procedures governing the exer cise of approval of test procedures are contained in the CGS TSPM or the PPM.
14.2.4 CONDUCT OF TEST PROGRAM
14.2.4.1 Administrative Procedur es for Preoperational Testing 14.2.4.1.1 Test Perfor mance Authorization
A significant period of time may have elapsed between the time a preoperational test procedure
was approved and the time a test is performed. The te st procedure is ther efore reviewed just prior to initiating the test. Any changes in the system since original approval of the test procedure will be thoroughly researched and the test procedure revised and approved in accordance with Sections 14.2.3.2 and 14.2.3.3. The CGS Test and Startup Manager will then approve the test procedure fo r performance of the test.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-19 14.2.4.1.2 Preoperational Test Prerequisites Approval by the Test and Startup Manager to perform a pre operational test also requires consideration of the prerequi site testing required to qualify components and systems for operation. In general, co mpletion of the system lin eup testing (see Section 14.2.1.3) will qualify the system for preoperational testing.
System lineup testing, as a prerequisite to preoperational testing, includes the following:
- a. Instrumentation and protective relay checks, including calibration, setpoint adjustments, logic verifi cation, and line checks;
- b. Component operability checks, includ ing valve stroking, motor rotation, ventilation system balancing, rotating equipment run-in and pipe support inspection and adjustment;
- c. Flushing, including proof flushes, fl ow instrumentation response, and pump performance and capacity checks;
- d. Electric component and sy stem checks, including brea ker trip setpoints; and
- e. Hydrostatic or pneumatic pressure tests and system s where dynamic testing, such as pump runs, are re quired to allow performance of pressure tests. Pressure integrity tests are otherwise performed during cons truction testing.
Verification that required system lineup tests have been or can be successful ly completed prior to preoperational testing is performed by the respective test group manager prior to recommending turnover of a system or component from a contractor to Energy Northwest.
Verification that the system is actually ready for pr eoperational testing w ill be performed as described in Section 14.2.4.3.
14.2.4.1.3 Conduct of Preoperational Testing
- a. Implementation responsibilities for scheduling all tests are assigned to the CGS Test and Startup Manager. The TWG will be kept informed of the scheduled activities.
- b. The satisfaction of prere quisites to commencement of th e test, as indicated in the test procedure, will be veri fied by the test engineer prior to performance of the test.
- c. The assigned test engineer is responsible for directi ng the performance of each test. Testing is performe d in direct coordination be tween the test engineer and shift supervision.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-20 d. All testing will be conducted in accor dance with approved test procedures. If, during the performance of a test the procedure is unaccep table, the test engineer can propose changes by use of a "Test Change Notice" (see Section 14.2.4.4). This provided both documentation of th e change and confirmation by the TWG.
- e. All test data will be entered on or attached to the record copy of the test procedure.
14.2.4.1.4 Deficiency Reporting
Deficiencies or discrepancies identified during testing will be reported individually as described in Section 14.2.5.2.
Corrective action or satisfactory disposition sha ll be taken on all defic iencies and discrepancies in equipment and procedures prior to final approval of the pre operational test results. All deficiencies or discrepancies identified during the test, or which have not been resolved on completion of the test, will be recorded in the record copy of the preoperational test.
14.2.4.1.5 Equipment Maintenance and Modifications During Preoperational Testing
Modifications or repair to safety-related systems will be implemented as a result of a formal system of problem and deviation reporting. Disposition of problems requiring mechanical or electrical changes or repairs by contractors will be implemented by work requests.
- a. Startup Problem Reports (SPR), Star tup Deficiency Reports (SDR), and Startup Work Requests (SWR) are administered th rough closed-loop pro cedural controls to ensure resolutions. A completed SPR, SDR, and SWR is approved for closure by the respective Test Group Manager.
- b. Startup Problem Reports are used to report design deficiencies and are coordinated by the Energy Northwes t project engineering organization for resolution by the responsible design or ganization or qualified alternate. The SPRs are reviewed by engineering and a Project Engineering Directive (PED) is issued to define plant modifications or changes that are required. An SWR is then issued to perform the plant modific ation by contractor personnel or an SDR is issued to defer the work or ha ve it performed by startup personnel.
- c. Startup Deficiency Reports (SDR) are used to report and track non-design-related defic iencies. If requi red, an SWR will be issued to perform the repair work to resolve the non-desi gn-related deficienc y by contractor personnel. Work accomplis hed by startup personnel c an be accomplished by the SDR without issuing an SWR.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-21 d. Retest requirements will be identified on the SWR or SDR a nd attached to, or referenced by the work request number in test files.
- e. Startup Problem Reports, SDR, SWR, design change documentation, retest results, and procurement r ecords for safety-related systems will be filed in assembled packages or with appropriate cross-refere ncing for retrievability.
14.2.4.1.6 Preoperati onal Test Summary
During the preoperational test, th e test engineer will prepare a test report which includes a summary of the conduct of the test, evaluation of the test re sults with reference to the acceptance criteria, and a description of problems encountered and corrective actions taken or proposed. This report will be attached to the record copy of the test.
14.2.4.1.7 Evaluation of Pr eoperational Test Data
On completion of the test, a copy of the offic ial test procedure, dat a, the test summary, and other applicable attachments will be transmitted to each member of the TWG responsible for
review.
14.2.4.1.8 Preoperati onal Test Records
The Test and Startup Manager will maintain all official test reco rds (the copy of the test procedure containing the original test data and signatures and a ll attachments) until completion of the test program. See Section 14.2.6 for details of the te st records handling and retention program.
14.2.4.2 Administrative Procedures for Power Ascension Testing 14.2.4.2.1 Plant Operation Du ring Power Asce nsion Testing
During initial startup tests and operations, the plant procedures are followed except as specifically modified by approved test procedures. In addition, special safety precautions and limitations are included in the te st procedures. Approved test procedures will be used to control test conditions outside of the Technical Specifications limits where allowed for test purposes.
Certain individual tests or power escalations may require authorization by both the POC and the Plant Manager immediately prior to implementation and will be so identified in the applicable test procedure.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-22 The final authority to start or continue a test is the responsib ility of the Shift Manager after all previous approvals have been exerci sed. Testing is performed in direct coordination between the test engineer and Shift Manager.
14.2.4.2.2 Power Ascension Te st Scheduling and Sequencing
Scheduling and sequencing of testing during startup is perf ormed under the direction of the Plant Manager by POC.
The startup or power ascension test sequence is describe d in terms of individual test evolutions and specific power plateaus due to interfaces with other simult aneous tests, requirements for continuous data review, and plant administrative requirements for authorization to proceed or continue. The test sequence identifies hold poi nts for data review and authorization to proceed and establishes the general plant c onditions for each group of tests.
14.2.4.2.3 Power Ascens ion Test Performance
Before starting each test, the assigned shift test engineer will review the test procedure to ensure that prerequisite ac tivities of conditions have been satisfied as described in Section 14.2.4.3.
The test will be stopped or curtailed if it cannot be performed safely or in accordance with the approved test procedure. Required test procedure deviations or changes may be effected in accordance with PPM 1.2.3, "Use of Plant Procedures," as de scribed in Section 14.2.4.4.2.
Should apparent deviations of test results from performance requirements or acceptance criteria be revealed, or shoul d other apparent anomalies develop, the plant will be placed in a safe condition and relevant test data will be reviewed by the te st engineer and Shift Manager. If the apparent discrepancy or anomaly is substantiated, the situation will be reviewed by the POC to ascertain if a plant safety question is involved. Control of any identified nonconformance or noncompliance will be in accordance with the plant administrative procedures.
Evaluation of the effect of the discrepancy or anomaly on plant safety will be performed at the appropriate level of review, and appropriate corrective actions will be taken before resumption of the test or test conditions at which the problem was revealed.
At the completion of an entire test procedure, the test engineer will assemble all of the data and supporting information, nonconformance documentation, and test re sults evaluations for review by the POC. Any data reduction or analysis required will be done as soon after the data is available as is practical so that the results of the analysis may be include d in the complete test package.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-23 Test records will be maintain ed as described in Section 14.2.6. 14.2.4.3 Control of Test Prerequisites Conditions and activities prerequisite to a given test will be id entified in the applicable test procedure. Prior to commencemen t of the particular test, the test engineer will verify that the identified prerequisites have been satisfied. The verifications will be recorded and retained as part of the test record.
The test engineer will verify that
- a. The test procedure has been approved by the appr opriate committee and Plant Manager, Test and Startup Manager, or Startup Superi ntendent as required. The test procedure is compatible with the latest versions of material referenced in the test procedure;
- b. The record copy of the test procedure is identical to that contained in the master file or PPM, including the latest TWG/POC approved revisions or test
procedure field changes (see Section 14.2.4.4);
- c. Prerequisite tests have been completed. If TWG and/or Plant Manager approval of a completed test is also a prerequisite, that approv al will have been obtained;
- d. The test procedure has been made available for shift operator review and familiarization. Operator support has been scheduled, as necessary;
- e. Test equipment is available or in place as required. Calibration or other readiness requirements have been completed. System inst rumentation to be used in the test has been calibrated within the required time period established for surveillance testing and/or preventative maintenance; and
- f. Test and operating personnel involved in the performance of the test have been briefed immediately prior to starting the test.
14.2.4.4 Modification of Test Procedures During Testing 14.2.4.4.1 System Lineup and Preoperational Test Phase
The TSPM provides a means of controlling modifications to TWG-approved test procedures during testing. This administ rative procedure, cont ained in the CGS TSPM, applies to changes made to an approved test proce dure during preoperational and startup testi ng. The procedure does not apply to revisions made during the preparation of test procedures.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-24 The procedure provides control of revisions which change the intent or the acceptance criteria of the test procedure.
The required changes, when id entified by the responsible test engineer, are described on a special form (Test Change Notice/Procedure Devia tion Form) which identifies the affect ed test procedure or plant procedure, justifies the change, and contai ns spaces for the appropriate approvals. The Test Change Notice forms beca me a permanent part of the test record.
A Test Change Notice for a pre operational test is reviewed by the TWG and approved by the Test and Startup Manger, TWG Chairman.
14.2.4.4.2 Power Ascension Test Phase
All test procedure details or changes must be made in accordance with PPM 1.2.3, "Use of Plant Procedures." This pro cess requires documentation on the required forms, signatures of authorized individuals, and subs equent full POC review. The PPM 1.2.3 forms became a permanent part of the test record.
14.2.5 REVIEW, EVALUATION, AND APPROVAL OF TEST RESULTS
14.2.5.1 Control of Test Results Review The individuals responsible for reviewing the results of particu lar tests will be designated by the POC or the Test and Startup Manager. Th ese reviews will be obtained through TWG or POC members in accord ance with their repres ented areas of respons ibility. TWG members will provide names of individuals in their repres ented organizations who meet the requirements of Regulatory Guide 1.58, Revision 0, for evaluation of inspec tion and test results.
Based on the recommendations of the qualified reviewers, the completed preoperational test will be approved by the TWG. Plant Op erating Committee review and Plant Manager approval of power ascension te st results is required.
14.2.5.2 Design Organization Partic ipation in Problem Resolution Failures of tests to meet acceptance criteria and other probl ems discovered in the course of testing will be documented as de ficiencies in accordance with the requirements of the TSPM for System Lineup and Preoperational Tests and in accordance with PPM 1.3.12, "Plant Nonconformances," for the power as cension tests. Reports of such deficiencies will indicate the parties or organizations deemed responsible for providing an accept able resolution of the deficiency. The responsible organization will be request ed to provide a resolution of the defined problem.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-25 Documentation of the final resolution will include the recommendati on of the responsible organization and a description of the measures implemented in accordance with that recommendation. Design problems will requi re resolution by th e appropriate Energy Northwest Technical Division Department, Project Engineering, Plant Technical Staff, or original design organization, depending on the technica l nature of the problem.
14.2.5.3 Results Analysis Prerequisites to Continua tion of Startup Testing The POC will establish prerequisites for various tests, test conditi ons, and test phases in consideration of system or component qualification for subsequent testing. The control or prerequisites to an individual test will be as described in Section 14.2.4.3.
The POC will also require an evaluation of the data acquired duri ng a particular test phase or plateau. The items considered in this eva luation will include, but are not limited to the following:
- a. The need for additional testing or re testing to improve assurance that a particular system or component will perform as require d in subseque nt testing, especially under more demanding cond itions such as higher power levels,
- b. The need for analysis of certain dat a to qualify measured variables or parameters for use in s ubsequent measurements,
- c. The completeness of testing up to the point in question as evidenced by the documentation of the completed tests, and
- d. The need for specific reviews and approval s of particular sets of data to satisfy the above.
14.2.6 TEST RECORDS
14.2.6.1 System Lineup and Preoperational Test Phase 14.2.6.1.1 General
The TSPM contains a generic procedure regarding filing and recordkeeping to be applied to testing documentation. This pr ocedure is intended to ensure compliance of Energy Northwest project startup programs with the applicable provisions of ANS N45.2.
9-1974, "Requirements for Collection, Storage, and Maintenance of Nucl ear Power Plant Quality Assurance Records,"
as required by Regulatory Guide 1.88, Revision 1, December 1975.
The following sections describe the provisions of the aforementioned procedure, which will be contained in specific detail in the CGS Test and Startup Instructions.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-26 14.2.6.1.2 Test Record Responsibilities
The Test and Startup Manager is responsible for identifying th e responsibilities, controls, and requirements for establishing and implemen ting a Test and Star tup Program filing and recordkeeping system, in accordance with 10 CFR 50 Appendix B, ANSI N45.2.9, and the Energy Northwest Quality Assurance Program Manual. The Test and Startup Manager will ensure that adequate procedures are prepared and maintained within the Test and Startup Instructions. The Test and St artup Manager will ensure that trained and qu alified personnel maintain the Test and Startup Program files.
14.2.6.1.3 Types of Documents and Records Requiring Test Record File Retention
Documentation and records that will be maintain ed within Test and Startup Program files are:
- a. Test and Startup program records as specified by ANSI N45.2.9, and
- b. All records and documents as specified by the Test and Startup Program and instruction manuals.
Other records, documents, corr espondence, etc., may be mainta ined at the discretion and approval of the Startup Progr am Manager, provided thei r access requirements do not compromise the security of the mandatory files.
14.2.6.2 Power Ascension Test Phase All test records and data shall be kept and filed in accordance with the PPM 1.6 series of procedures which detail the requirements for all plant recordkeeping.
14.2.7 CONFORMANCE OF TEST PROGRAMS WITH REGULATORY GUIDES
14.2.7.1 Conformance with Regulatory Guide 1.68 The CGS Test and Startup Program conforms to the requirement s of Regulatory Guide 1.68, Revision 0, "Preoperational and Initial Star tup Test Programs for Water-Cooled Power Reactors," except where specifically noted otherwise. The Regulatory Guide has been reviewed by Energy Northwest for applicability of individual items in the guide to CGS and its systems. The applicability to this plant has determined the nature and scope of testing to be
performed. Actual ex ceptions to the testing required by this guide have been specifically addressed and are disc ussed in Section 14.2.7.2. Areas where the guide does not apply are not considered to be exceptions.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-27 14.2.7.2 Exceptions to Regulatory Guide 1.68 The exceptions to Regulatory Guide 1.68 ar e listed below with an explanation of the justification for the exception.
- a. Exception to Format of Test Procedures
The format of the test procedures is diffe rent from that fou nd in Appendix C of Regulatory Guide 1.68, but the format d ifference is not considered an exception to the regulatory guide since the guide specifies required el ements of a test procedure while merely implyi ng but not requiring a format.
- b. See Section 1.8.2 for a delineation of specific exceptions to the requirements of Regulatory Guide 1.68.
14.2.7.3 Conformance With or Exceptions to Regulatory Guid es Other Than 1.68
- a. Regulatory Guide 1.70, "Standard Format and Conten t of Safety Analysis Reports for Nuclear Power Plants" will be complied with for the section that pertains to the Test and Startup Program, b. Regulatory Guide 1.33, "Quality Assurance Program Requirements" will be complied with in "Quality Assurance During the Operations Phase,"
Section 17.2, of the FSAR for the Test and Startup Program,
- c. All other regulatory guides pertaining to individual testing will be complied with unless noted otherwise in Section 14.2.12 , and
- d. Regulatory Guide 1.58 "Q ualifications of Nuclear Power Plant Inspection, Examination, and Testing Personnel." Energy Nort hwest Test and Startup personnel involved in testing meet the requirements of Regulatory Guide 1.58.
14.2.8 UTILIZATION OF REACTOR OPERATING AND TESTING EXPERIENCES IN THE DEVELOPMENT OF THE TEST PROGRAM As a matter of Energy Northwes t policy, a continuous program of review of reactor operating experience is coordinated by th e Operations Division of Energy Northwest. The sources of information reviewed in co mpliance with this policy ar e NRC Information Notices and Bulletins, operating experience re ports, preoperational test summari es and startup reports from other plants, administrative and te st procedures from other plants' start up programs, personal contacts with other nuc lear plant licensees or applicants, and additional information supplied by Energy Northwest Technical and Operations Division members.
All available sources are C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-28 utilized; relevance to particular Energy Northwest nuclear projects is determined in the review process.
The information is reviewed by CGS Start up Program personnel for applicability to the CGS Test and Startup Program, for incorporation into test procedures, or fo r consideration in the administrative control of testing.
14.2.9 TRIAL USE OF PLANT OPERATING AND EMERGENCY PROCEDURES To the extent practical throughout the preoperational and initial PATP, test procedures utilize operating, emergency, and abnormal procedures where applicable in the performance of tests.
The use of these procedures is intended to do the following:
- a. Prove the specific procedure or illustrate changes which may be required, b. Provide training of pl ant personnel in the use of these procedures, and c. Increase the level of knowledge of pl ant personnel on the systems being tested.
Test procedures may use operati ng, emergency, and abnormal proce dures in several ways: the test procedure may reference the procedure directly; the test procedure may extract a series of steps from the procedure; the test procedure may use a combination of the first two methods; or the test procedure may require system and plant conditi ons that will be obtained by the use of plant operating or emergency procedures.
14.2.10 INITIAL FUEL LOADING AND INITIAL CRITICALITY
14.2.10.1 Fuel Loading and Sh utdown Power Level Tests Fuel loading and initial criticalit y is conducted in accordance with written procedures after all prerequisite tests are satisfacto rily completed and an operating license has been issued. Prior to approving fuel loading, the plan t must be verified as ready to load fuel. This verification is accomplished by the following step s, which are performed at the completion of a majority of the preoperational testing.
14.2.10.1.1 Loss of Power Demonstration-Standby Core Cooling Required This test demonstrates the capability of each em ergency diesel generator to start automatically and assumes all of its emergency core cooli ng loads in a loss of normal auxiliary power.
14.2.10.1.2 Cold Functional Testing
The cold functional testing defin ed here is an integrated syst em operation of various plant systems that can be opera ted as systems prior to fuel loadi ng. The intent is to observe any unexpected operational problems from either an equipment or a procedural source and to C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-29 provide an opportunity for operator familiariz a tions with the system-operating procedures under operating conditions.
Some of the cold functional testing will be acc o mplished during the preoperational test program. For example, integrated and simult a neous operation of the following systems may take place during the flush of t h e total system: condensate s y stem, condensate demineralizer system, low-pressure coolant inject i on (LPCI) sys t em, core spray sys t em, react o r water cleanup (RWCU) system, service w a ter system, closed cooling w a ter (RCC) system, and others.
As required, additional integrated systems p e r f ormance will be demonst r ated prior to fuel loading.
14.2.10.1.3 Routine Su r veillance Testing
Because of the interval between completion of a preoperational test on a system and the requirement for that system to be operated may be of conside r able length, a nu m ber of routine surveillance tests must be per f ormed prior to fuel loading and must be r e peated on a routine basis. The Technical Specifications described the t e st frequency. In gen e ral, this S u rveillance Test Program (specified in the Technical Specifications) is instit u ted prior to fuel loading by the plant opera t i ng staff.
14.2.10.1.4 Master Startup Checklist
A detailed list of items that must be com p lete, including the preop e rational tests, work requests, design chang e s, and proper dispositioning of all exceptions noted during preoperational testing listed in Table 14.2-1 is r echecked to ve r ify c o mpletion just prior to the final appro v als for fuel loading a nd at each significant new step s u ch as heat up, opening main steam isolation valves (M SIVs), and power operation.
14.2.10.1.5 Initial Fuel Loading
Fuel loading requires the movement of the full core complement of assemblies from the fuel pool to the core, with e a ch a ssembly identified b y number before being placed in the correct coordinate position. The proc e dure controlling this movement is arranged so that shutdo w n margin and subcritical checks are m ade at predetermined i n tervals throughout the loading, thus ensuring safe loading incre m ents. Specially sensitive invess e l neutron monito r s that are maintained at the loading face as loading pro g resses serve to pro v ide indication for the shutdown m a rgin measurements, and al so to al l o w the recording of the core flux level as each assembly is added. A c o mplete check is made of the fully loaded core to ascertain that all assemblies are properly installed, correctly oriented, and are occupying their designated positions.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-30 14.2.10.1.6 Zero Power Level Tests
At this point in the program, a number of te sts are conducted which ar e best described as initial zero power level tests. Chemical and radiochemical tests are made to check the quality of the reactor water before fu el is loaded, and to establis h base and background levels required to facilitate later analysis and in strument calibrations. Plant and site radiation surveys are made at specific locations for later comparison with the values obtained at the subsequent operating power levels. Shutdown margin checks are repeated for the fully loaded core, and criticality is achieved with each of the two prescribed rod sequences in turn, the data being recorded for each rod withdrawn. Each rod drive is subj ected to scram and performance testing. The initial setting of the intermediate range monitors (IRMs) is at maximum gain.
14.2.10.2 Initial Heatup to Rated Temperature and Pressure Heatup follows the satisfactory completion of the fuel loading and ze ro power level tests (Sections 14.2.10.1.5 and 14.2.10.1.6) and further checks are made of coolant chemistry together with radiation surveys at the selected plant locations.
All control rod drives (CRDs) are scram-timed at rated temperature and pressure, with selected drives timed at two intermediate reactor pr essures and for different accumulator pressures.
The process computer checkout continues as more proc ess variables become available for input. The reactor core isolation cooling (RCIC) system will complete controlled starts at low reactor pressure and at rated conditions, with testing in the quick-start mode at 150 psig and 10 00 psig. Correlations are obtained between reactor vessel temperatures at several loca tions and the values of other process variables as heatup continues. The movements of NSSS piping in the drywell mainly as a function of expansion are recorded for comparison with design data.
14.2.10.3 Power Testing From 25% to 100% of Rated Output The power test phase comprises th e following tests, many of whic h are repeated several times at the different test l evels; consequently, see Table 14.2-4 for the series. While a certain basic order of testing is maintained relative to power ascension, there is, nevertheless, considerable flexibility in the test sequence at a particular power level which ma y be used whenever it becomes operationally expedient. In no instance, however, is nuclear safety compromised.
- a. Coolant chemistry tests and radiation su rveys are made at each principal test level to preserve a safe and efficient power increase,
- b. Selected CRDs are scram-timed at various power levels to provide a correlation with the initial data,
- c. The effect of control rod movement on other parameters (e.g., electrical output, steam flow, and neutron flux level) is examined for different power conditions, C OLUMBIA G ENERATING S TATION Amendment 59 F INAL S AFETY A NALYSIS R EPORT December 2007 LDCN-06-000 14.2-31 d. Following the first reasonable, accura te heat balance (25% power) the average power range monitors (APRMs) are calibra ted and IRMs are reset if necessary, e. At each major power level (25%, 60%, and 100%), the local power range monitors (LPRMs) are calibrated, f. The APRMs are calibrated initially at each new power level and following LPRM calibration, g. Completion of the process computer ch eckout is made for a ll variables, and the various options are compared with han d calculations as soon as significant power levels are available, h. Further tests of the RCIC are made with and without injection into the reactor pressure vessel (RPV),
- i. Collection of data from the system ex pansion tests is comple ted for those piping systems which had not pr eviously reached full operating temperatures,
- j. The axial and radial power profiles ar e explored fully by means of the traversing in-core probe (TIP) system at representative power levels during the power ascension, and
- k. Core performance evaluations are made at all test points above the 10% power level and for selected flow transient conditions; the work involves the determination of core thermal power, ma ximum fuel rod surface heat flux, and minimum critical power ratio (MCPR), and other thermal parameters.
- l. Overall plant stability in relation to minor perturbations is shown by the following group of tests which are m ade at selected test points:
- 1. Core power-voi d mode response, 2. Pressure regulat or setpoint change, 3. Water level setpoint change, 4. Turbine valve surveillance, and 5. Recirculation flow setpoint change.
For the first of these tests, a centrally located control rod is moved and the flux response is noted on a select ed LPRM chamber. The n ext two tests require that the changes made should approximate as cl osely as possible a step change in demand, while for the next test the turb ine stop, control, and bypass valves are opened to verify stability and power leve l for surveillance testing. The remaining test is performed to prop erly adjust the control loop of the C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-32 recirculation system. For all of these tests the plant performance is monitored by recording the transient behavior of numerous process variables, the one of principal interest being ne utron flux. Other imposed transients are produced by step changes in demand core flow, par tial loss of feedwater heating, and simulating failure of the operating pressu re regulator to pe rmit takeover by the backup regulator.
Table 14.2-3 shows the power and flow levels at which all these stability tests are performed.
- m. The category of major plant transients includes full closure of all the MSIVs, fast closure of turbine generato r control valves, fast clos ure of turbine generator stop valves, loss of the ma in generator and offsite pow er, tripping a feedwater pump, and several trips of the recirculation pumps. The plant transient behavior is recorded for each test and the result s may be compared with the acceptance criteria and the predicted desi gn performance. Table 14.2-2 shows the operating test condition for a ll the proposed major transients;
- n. A test is made of the relief valves in which leaktightne ss and general operability are demonstrated;
- o. At some major power levels the jet pump flow instrumentation is calibrated;
- p. The as-built characteristics of the recirculation system are investigated as soon as operating conditions pe rmit full core flow; and
- q. The local control loop performance, based on the drive pump, jet pumps, and control equipment is checked.
14.2.11 TEST PROGRAM SCHEDULE
The test program schedule for preoperati onal and startup tests are indicated in Table 14.2-4 and Figure 14.2-4. These schedules are preliminary and will be adjusted to consider actual construction and testi ng progress; they are includ ed to provide general information but are not considered to be identical to the schedules in use during the startup program. The test procedures will be made av ailable for review at least 30 days pr ior to the test date or fuel load.
14.2.12 INDIVIDUAL TEST DESCRIPTIONS
14.2.12.1 Preoperational Test Procedures The following general descriptions are the spec ific objectives of each preoperational test.
During the final construction phas e, it may be necessary to m odify the preoperational test methods as operating a nd preoperational test procedures are devel oped. Consequently, methods described in the following desc riptions are general, not specific.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-33 Specific acceptance criteria for each preoperational test are in accordance with the detailed system and equipment specifications for equipment in those systems. The tests demonstrate that the installed equipment and systems perform within the limits of these specifications.
In addition to the prerequisites listed on each on the following preoperational tests, there will be electrical power availabl e to each of the systems.
Table 14.2-1 lists the preoperational tests anticipated for this facility.
14.2.12.1.1 Reactor Feedwater System Preoperational Test
- a. Purpose To verify the operation of the reactor feedwater system, including pumps, valves, turbines, turbine auxiliaries, and turbine control systems.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The condensate system, control air system, and service water system must have a readiness verification.
- c. General Test Methods and Acceptance Criteria The performance of the reactor feedwater system is verified within the limitations of the auxiliary steam supply by the demonstration of the proper operation of the following:
- 1. Valves and related controls, interlocks, and position indicators, 2. Reactor feedwater pumps , turbines, and auxiliaries, 3. Control logic, and
- 4. Annuciators and pr otective devices.
14.2.12.1.2 Condensate System Preoperational Test
- a. Purpose To verify the operation of the condensat e system, including pumps, valves, and control systems.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-34 b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The condenser, c ondensate filter deminera lizers, feedwater, and control air systems are capable of supporting this test as necessary.
- c. General Test Methods and Acceptance Criteria The performance of the condensate system is verified by the demonstration of the proper operation of the following:
- 1. Valves and related controls, interlocks, and positions indicators, 2. Condensate pumps, condensate booster pumps and auxiliaries, 3. Control logic, and
- 4. Annuciators and pr otective devices.
14.2.12.1.3 Fire Protection Sy stem Preoperational Test
- a. Purpose To verify the operation of the fire protec tion system including the diesel engine, pumps, valves, detection and alarm circuits, and cont rol and instrumentation circuits. To verify the location and status of all portable equipment.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The circulating water system, control and service air system, and electrical distribution syst em are available to support operation.
- c. General Test Methods and Acceptance Criteria Verification of the fire protection system capability is demonstrated by the proper integrated operation of the following:
- 1. Diesel engine and pump operation and related control and logic, 2. Fire alarm and de tection circuits, 3. Fire control panel in the main control room,
- 4. Deluge, wet pipe and preaction spri nkler systems, and 5. Carbon dioxide and Halon systems.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-35 In addition, portable equi pment and hose station capab ility will be verified.
14.2.12.1.4 Reactor Water Cleanup System Preoperational Test
- a. Purpose To verify the operation of the RWCU system, including pumps, valves, and filter/demineralizer equipment.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Filter aid, and ani on and cation resin shoul d be available.
The RCC system and instrument air syst em must have readi ness verification.
- c. General Test Methods and Acceptance Criteria Verification of the RWCU system capability is demonstrated by the proper integrated operation of the following:
- 1. Drain flow regulator flow interlocks,
- 2. System isolation and logic,
- 3. Valve-operating sequence,
- 4. Pump operation and rela ted control and logic, 5. Annuciators, and
- 6. Filter/demineralizer system operation.
14.2.12.1.5 Standby Liquid Control System Preoperational Test
- a. Purpose To verify the operation of the standby liquid control (SLC) system including pumps, tanks, control, l ogic, and instrumentation.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Valves should be previously bench tested and other precautions relative to pos itive displacement pumps ta ken. The re actor vessel should be available for inj ecting demineralized water.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-36 c. General Test Methods and Acceptance Criteria Verification of the SLC system capability is demonstrated by the proper integrated operations of the following:
- 1. SLC system tank level instrumentation, 2. Heaters,
- 3. Alarms and logic,
- 4. Relief valves, 5. Pumps and related c ontrols and logic, and 6. Flow testing with different flow paths.
14.2.12.1.6 Nuclear Boiler Sy stem Preoperational Test
- a. Purpose To verify proper operation of the nuclea r boiler system incl uding safety/relief valves (SRVs) and relate d controls and logic.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Verify that all SRVs have been previously bench tested.
- c. General Test Methods and Acceptance Criteria Functional and capacity tests of SRVs ar e not performed; verification of the NSSS capability is demonstrated by th e proper integrated operation of the following:
- 1. System valves and rela ted sensors and logic, 2. Vacuum breaker in relief valve discharge lines, 3. Automatic isolation function of re actor water sample isolation valves, 4. Isolation and leak detection systems, 5. Automatic depressurization system logic,
- 6. Reactor vessel actuato rs accumulator capacity test, 7. Safety/relief valves air piston operation, 8. Reactor head seal leak detection, and 9. Alarms and annunciators.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-37 14.2.12.1.7 Residual Heat Removal System Preoperational Test
- a. Purpose To verify the operation of the residual heat removal (RHR) system under its various modes of operation: LPCI, shutdown cooling and vessel head spray, containment spray, and suppression pool water cooling.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The RHR servic e water system must have readiness verification. The reactor vessel and recirculation loops shall be intact and capable of receiving water.
- c. General Test Methods and Acceptance Criteria Verification of the RHR system capability is demonstrated by the proper integrated operation of the following:
- 1. System isolation valve control and logic tests,
- 2. RHR and RHR service water pump and motor operation, controls, and related logic features,
- 3. Automatic LPCI initiation logic,
- 4. Verification of all flow paths. The time from initiation signal to full flow should be verified, and
- 5. Alarms and annunciators.
14.2.12.1.8 Reactor Core Isolation Cooling System Preoperational Test
- a. Purpose To verify the operation of the RCIC system including turbine, pump, valves, instrumentation, and control.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-38 b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The turbine, disconn ected from the pump, shall be tested. The turbine instruction manual shall be reviewed in detail in order that precautions relative to turbine operation are followed. Then the system shall be tested within the capability of a temporary steam supply with the pump coupled to the turbine.
- c. General Test Methods and Acceptance Criteria
- 1. All valves and related cont rols, interlocks, and indicators, 2. Manual and automatic initiation,
- 3. Automatic isolation, including leak detection system logic, 4. Turbine speed control, trip, mode selection, and test mode, 5. Barometric condenser condensate pump, and vacuum pump controls, 6. Flow path verification, and
- 7. Annunciators.
14.2.12.1.9 Reactor Recirculation System and Control Preoperational Test
- a. Purpose To verify the operation of the reactor recirculation system including pumps and their associated motors, valves, instrumentation, and controls. The rated conditions tests will be conducted during the st artup testing program.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The RCC system must receive readiness verification. All required testing of equipment up to the operation of the recirculation pump has been completed, including recirculation pump motor (uncoupled) and all control loops.
- c. General Test Methods and Acceptance Criteria After prerequisite testing, verification of system capability is demonstrated by the proper integrated operation of the following:
- 1. System valves, C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-39 2. Logic and interlocks, 3. Recirculation pumps, valves, and related controls and interlocks, 4. Annunciators, and
- 5. Low frequency motor generator (LFMG) set.
14.2.12.1.10 Reactor Manual Contro l System Preoperational Test
- a. Purpose To verify the operation of the reactor manual control (RMC) system, including relays, control circuitry, switches and indicating lights, and control valves.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The CRD pump w ill not be operational during this test.
- c. General Test Methods and Acceptance Criteria Verification of RMC system capability is demonstrated by th e proper integrated operation of the following:
- 1. Rod blocks, alarms, and interlocks for all mode s of the reactor mode switch,
- 2. Rod position information system,
- 3. Rod drift alarm circuit, and
- 4. Rod directional control valve tim e sequence for insert and withdraw commands.
14.2.12.1.11 Control Rod Drive Hydraulic System Preoperational Test
- a. Purpose To verify the operation of the CRD hydraulic system including CRD mechanisms, hydraulic cont rol units, hydraulic power supply, instrumentation, and controls.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-40 b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The CRD manual c ontrol system preoperational test must be completed on associated CRDs. The RCC system and instrument air system must receive readiness verification.
- c. General Test Methods and Acceptance Criteria Verification of CRD system capability is demonstrated by th e proper integrated operation of the following:
- 1. Logic and interlocks,
- 2. CRD pumps and related controls and interlocks,
- 3. Flow controller, pressure control valves, and stabilizer valves,
- 5. CRDs functional testing including latching and position indication,
- 6. Scram testing of control rods at atmospheric pressure, and
- 7. Annunciators.
14.2.12.1.12 Fuel Handling and Vessel Servicing Equipm ent Preoperational Test
- a. Purpose To verify the operation of the fuel handling and vessel servicing equipment including tools used in the servicing of control rods, fuel assemblies, LPRMs and dry tubes, and vacuum cleaning equipment.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, the refueling platform, fuel preparation machine, and fuel racks must be installed and operational; all slings and lifting devices must be certified at their design load, at le ast by the vendor.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-41 c. General Test Methods and Acceptance Criteria Verification of the fuel hand ling and vessel servicing equipment is demonstrated by dry operation of the following equipment:
- 1. Cell disassembly tools,
- 2. Channel replacement tools, 3. Instrument handling tools,
- 4. Vacuum cleaning equipment,
- 5. Interlocks and logic associated with the refue ling and service platform are verified, and
- 6. Proper operation of refueling and service platforms are verified.
14.2.12.1.13 Low-Pressu re Core Spray System Preoperational Test
- a. Purpose To verify the operation of the low-pressu re core spray syst em (LPCS), including spray pumps, sparger ring, spray nozzles, controls, valves, and instrumentation.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The re actor vessel must be ava ilable and ready to receive water.
- c. General Test Methods and Acceptance Criteria Verification of the LPCS system capability is demonstrated by the proper integrated operation of the following:
- 1. Logic and interlocks,
- 2. Low-pressure core spray syst em pumps, including auto initiation, C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-42 3. Flow path verification, including determination of system hydraulic performance to verify proper sizing of restricting orifice in LPCS discharge line to vessel (see Section 6.3.2.2.3), 4. Annunciators,
- 5. The time for initiation signal to full flow should be verified, and
- 6. Photographs to prove acceptability of core spray patterns.
14.2.12.1.14 High-Pressu re Core Spray System Preoperational Test
- a. Purpose To verify the operation of the high-pressure core spray (HPCS) system, including diesel generator and related auxiliary equipment, pumps, valves, instrumentation, and control.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The HPCS diesel generator must be installed and be operational.
- c. General Test Methods and Acceptance Criteria Verification of HPCS system capability is demonstrated by the proper integrated operation of the following:
- 1. Valve controls and interlocks,
- 2. HPCS electrical system tests, including dc and ac,
- 3. HPCS diesel generator functional tests including star ting, rated load, load rejection,
- 4. Pump and motor tests with normal power supply and with diesel generator,
- 5. HPCS flow path and flow rate verification,
- 6. Annunciators, C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-43 7. The time from initiation signal to full flow should be verified, and
- 8. Photographs to prove acceptability of HPCS spray pattern.
14.2.12.1.15 Fuel Pool Cooling and Cleanup System Pre operational Test
- a. Purpose To verify the operation of the fuel pool cooling and cleanup system including the pumps, heat exchangers, controls, valves, and instrumentation.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The instrument air, service air, fuel pool emergency makeup, service wate r, and RHR systems mu st be available.
- c. General Test Methods and Acceptance Criteria Verification of the fuel pool system capab ility is demonstrated by the integrated operation of the following:
- 1. Logic and interlocks,
- 2. Interconnection to RHR system,
- 3. Pump operation and related controls, 4. Cleanup subsystem operation, and
- 5. Annunciators.
14.2.12.1.16 Leak Detection System Preoperational Test
- a. Purpose To summarize the test requirements and verify the leak detection test data for each of the nuclear systems.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The prerequisites are included in the preoperational test specifications for each of the nuclear systems listed below.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-44 c. General Test Methods and Acceptance Criteria As an integral part of each of the following system preoperational tests, the nuclear systems leak detection is ver ified by the proper ope ration of the leak detection features of the following nuclear systems:
- 1. Feedwater control system,
- 5. RCIC system,
- 6. Recirculation system, and
- 7. Radwaste system.
14.2.12.1.17 Liquid and Solid Radwaste System Preoperational Test
- a. Purpose To verify that the radioactive waste system will perform its design functions of processing liquid and so lid radioactive wastes.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
- c. General Test Methods and Acceptance Criteria Testing will demonstrate t hat the pumps, tanks, c ontrols, and valves including automatic isolation, diversion and protec tion features, and instrumentation and alarms will operate and function in accordance with design requirements.
Testing will also verify t hat the CGS Process Contro l Program results in an acceptable waste form as required by 10 CFR 61. Simulated waste will be verified to form a free-standing monolithic solid with no free liquid prior to implementation of the solidification pr ocess on radioactive waste. Liners containing solidified waste will be inspected prior to shipment to the disposal site to verify compliance with 10 CFR 61 requirements.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-45 14.2.12.1.18 Reactor Protection System Preoperational Test
- a. Purpose To verify the proper operation of the re actor protection system (RPS), including sensor logic and their respective scram relays, scram reset time delay, the annunciators, and motor gene rator set power supply.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
- c. General Test Methods and Acceptance Criteria Verification of the RPS c apability is demonstrated by the proper integrated operation of the following:
- 1. Motor generator set performance,
- 2. Sensor logic and scram relay logic,
- 3. Scram reset time delay,
- 4. Sensors input-to-scram trip act uator response time on all channels of each function for which response ti mes are required by the Technical Specifications,
- 5. Annunciators,
- 6. Mode switch tests, and
- 7. Auxiliary sensor operation.
The ability of the system to scram the re actor within a spec ified time must be demonstrated in the CRD hydraulic system preoperati onal test (see Section 14.2.12.1.11
).
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-46 14.2.12.1.19 Neutron Monitoring System Pr eoperational Test
- a. Purpose To verify the operation of the neutr on monitoring system (NMS) including startup, intermediate, and power range detectors, and their related equipment.
- b. Prerequisites The system lineup tests have been complete, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, all source range monitors (SRMs) and pulse preamplifiers, IRMs and voltage preamplifiers, and APRMs will have been calibrated according to th e vendor's instructions.
- c. General Test Methods and Acceptance Criteria Verification of the NMS capability is de monstrated by the proper integrated operation of the following:
- 1. All SRM detectors, and their resp ective insert and retract mechanisms, and cables;
- 2. SRM channel including pulse prea mp, remote meter and record, trip logic, logic bypass and related lamp s and annunciators, control system interlocks, refueling instrume nt trips, and power supply;
- 3. All IRM detectors and their respective insert and retract mechanisms and cables;
- 4. IRM channels including voltage preamp s, remote recorders, RMC system interlocks, RPS trips, annunciators and lamps, and power supplies;
- 5. All LPRM detectors and their respective cables, and power supplies;
- 6. All APRM channels including trips, trip bypasses, annunciators and lamps, remote recorders, RMC syst em interlocks, RPS trips, and power supplies;
- 7. Recirculation flow bias signal in cluding flow unit, flow transmitters, and related annunciators, interlocks, and power supplies, and
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-47 8. Both rod block monitor (RBM) channe ls including trips, trip bypasses, annunciators and lamps, remote recorders, RMC system interlocks, and power supplies.
14.2.12.1.20 Traversing In-Core Probe System Preoperational Test
- a. Purpose To verify the operation of the traversi ng in-core probe (TIP) system including the TIP detector, controls and interl ocks, containment secure lamp, and containment isolation circuits.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. (Additionally, th e TIP detector and dummy detector, ball valve time delay, core t op and bottom limits, clutch , x-y recorder, and purge system will have been shown to be operational.)
- c. General Test Methods and Acceptance Criteria With the exception of the shear valve, wh ich is not tested, verification of the TIP system is demonstrated by the proper integrated operation of the following:
- 1. Indexer cross-calibration interlock,
- 2. Shear valve control monitor lamp, and
- 3. Drive motor manual control and o verride, automatic control and stop, and low speed control.
14.2.12.1.21 Rod Worth Minimize r System Preoperational Test
- a. Purpose To verify the operation of the rod wo rth minimizer (RWM) system under its various modes of operation.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-48 initiation of testing. Additionally, the rod position indication system (RPIS) will have been shown to be operational, rod sequence control (RSC) system bypassed, and computer diagnostic and special tests completed.
- c. General Test Methods and Acceptance Criteria Verification of the RWM system is de monstrated by the proper integrated operation of the following:
- 1. Rod test option,
- 2. System initialization both above and below the low power setpoints, and above and below the low power alarm points,
- 3. RWM program,
- 4. Rod withdrawal and in sertion error block, and
- 5. Rod drift scan, and annunciation.
The RWM program acceptance of an operator-supplied rod position value must
be demonstrated.
14.2.12.1.22 Process Radiation Monitoring System Preoperational Test
- a. Purpose To verify the operation of the proce ss radiation monitoring (PRM) system, including the offgas vent, offgas, main steam line, liquid process, and building ventilation radiation monitoring subsystems.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, th e process radiation monitors, pulse preamplifiers, power supplies, indicato r and trip units, are calibrated.
Insulation resistance and high potentiomete r tests will have b een completed.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-49 c. General Test Methods and Acceptance Criteria Verification of the PRM system is de monstrated by the proper integrated operation of the following:
- 1. Vent preamps, channels, trip poi nts, annunciators and lamps, sample rack, and check source,
- 2. Offgas vial sampler, log radiation monitor (LRM) and their related annunciators, lamps and recorde rs, and high/low flow detector,
- 3. Main steam and LRM channels, trip points, and annunciators and lamps, High-High and Inop trip, and recorders,
- 4. Liquid process preamps, channels, trip points, and annunciators and lamps, and recorders,
- 5. Building ventilation system sensor s, channels, tr ip points, and annunciators and lamps, recorders, and SGTS interlock, and
- 6. Control center air monitoring sensors, channels , annunciators, and indicators.
14.2.12.1.23 Area Radiation Monitoring System Preoperational Test
- a. Purpose To verify the operation of the area radiation monitoring (ARM) system, including channels, trip point s, alarms, and recorder.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, indica tor, trip units, and power supplies are calibrated.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-50 c. General Test Methods and Acceptance Criteria Verification of the ARM system capability is demonstrated by the proper integrated operation of the following:
- 1. Monitor channels,
- 2. Channel trip points,
- 3. Alarm annunciators and lights, and
- 4. Recorder.
14.2.12.1.24 Process Computer Inte rface System Pre operational Test
- a. Purpose To verify the operation of the process computer interface (P CI) system including computer inputs and printout.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, co mputer diagnostic ch ecks and programming are completed.
- c. General Test Methods and Acceptance Criteria Verification of the PCI system is de monstrated by the proper integrated operation of the following:
- 1. Analog input signals,
- 2. Computer printout,
- 3. Digital input signals, and
- 4. Digital output signals.
14.2.12.1.25 Rod Sequence Contro l System Preoperational Test
- a. Purpose To verify the operation of the RSC system under its various modes of operation.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-51 b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, the self-test feature of the RSC system is verified.
- c. General Test Methods and Acceptance Criteria Verification of the RSC system is de monstrated by the proper integrated operation of the following:
- 1. Low power setpoint and low power alarm point tests, 2. RSC system status displays and annunciators, 3. Reactor mode switch test,
- 4. System diagnostic and data quality tests, 5. Rod position data tests,
- 6. Single rod bypass provision,
- 7. Rod sequences tests,
- 8. Rod group assignment,
- 9. Constraints of rod movement tests,
- 10. 100% to 75% contro l rod density tests, 11. 5% to 50% contro l rod density tests, and 12. 0% control rod density to low power setpoint tests.
14.2.12.1.26 Remote Shutdow n Preoperational Test
- a. Purpose To verify the feasibility and operability of the shutdown functions from the remote shutdown pane l and its ability to bring the re actor to a cold condition in an orderly fashion.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, the control power should be supplied to the remote shutdown panel, and the inde pendence of power supply voltage, and fuses should be verified.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-52 c. General Test Methods and Acceptance Criteria Verification of the remote shutdown sy stem is demonstrated by the proper integrated operation of the following tests:
- 1. Operation of valves, controls, instruments, and pumps on systems available from this panel, and
- 2. Transfer switch operation from the control room panels to the remote shutdown panel.
14.2.12.1.27 Offgas Syst em Preoperational Test
- a. Purpose To verify the operation of the offgas system including valves, recombiner, condensers, cooler s, filters, and hydr ogen analyzers.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager (Assistant Plant Manager) has approved the initiation of testing. Additionally, the instrument air system, electrical power, and coo ling water should be operational.
- c. General Test Methods and Acceptance Criteria Verification of the offgas system is demonstrated by the following tests:
- 1. Valve operation including fail safe and isolation features and valve status lights indicate the correct valve position,
- 2. Pump operation,
- 3. Level and temperature control and indication, 4. Recombiner and preheater tests,
- 5. Condenser, cooler, and mo isture separator tests,
- 6. Gas dryer and cooler tests,
- 7. Filter efficiency, C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-53 8. Hydrogen analyzer performance test, and
- 9. Purge and bleed air rate test.
14.2.12.1.28 Environs Radiation Monitoring Preoperational Test
- a. Purpose To verify the operation of the environs radiation monitoring system, including dosimeters, sampling pum p, and filter equipment.
- b. Prerequisites System lineup tests have been complete d, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Additionally, indicator power supplies are calibrated according to the vendor's instruction manual.
- c. General Test Methods and Acceptance Criteria Verification of the environs radiation monitoring system capability is demonstrated by the proper operation of the following:
- 1. Air sample equipment, and
- 2. Thermoluminescent detector (TLD) (passive dosimeters).
14.2.12.1.29 Main Steam Sy stem Preoperational Test
- a. Purpose To verify the proper operation of the MSIVs and related controls.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-54 c. General Test Methods and Acceptance Criteria Verification of the main st eam system is demonstrated by the proper integrated operation of the following:
- 1. Automatic isolation of the MSIVs,
- 2. Minimum closi ng times are met, 3. MSIV accumulato r capacity tests are satisfactory, and
- 4. Valves, heaters, blowers, and in itiating logic of the MSIV leakage control system.
14.2.12.1.30 Radwaste Building Heating, Ventilating, and Air Conditioning System Preoperational Test
- a. Purpose To verify that the radwaste building heating, ventilating, and air conditioning (HVAC) system will function in accordan ce with the design requirements as set forth in the design specifications.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The 480-V ac power system, control air supply service air system, and the turbine service water system is capable of supporting this test as necessary.
- c. General Test Methods and Acceptance Criteria Verification of the radwaste building H VAC system is demonstrated by the proper integrated operation of the following:
- 1. Ventilation fans and their related controls,
- 2. Filters and instrumentation,
- 3. Dampers and controls, and
- 4. Annunciators and pr otective devices.
C OLUMBIA G ENERATING S TATION Amendment 58 F INAL S AFETY A NALYSIS R EPORT December 2005 LDCN-05-002 14.2-55 14.2.12.1.31 Closed Cooling Wate r System Preoperational Test
- a. Purpose
To verify the operation of the RCC syst em including pumps, valves, logic, and annunciator.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The following supp ort systems must have received readiness verifications:
- 1. Control and service air (CAS/SA), 2. Makeup water treatment,
- 3. Essential 480-V ac power, and
- 4. Instrumentation power.
- c. General Test Methods and Acceptance Criteria Verification of the RCC system is de monstrated by the proper integrated operation of the following:
- 1. Surge tank level control,
- 2. System pumps and control logic,
- 3. Chemical addition pump and control, and 4. Remote-operated valves.
14.2.12.1.32 Primary Containment Atmosphe ric Control System Preoperational Test (SYSTEM DEACTIVATED)
- a. Purpose To verify the operation of the primary containment atmospheric control (CAC) system including blowers, coolers, valves, instruments, and alarms.
- b. Prerequisites
The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Primary containm ent, essential 480-V ac power, standby C OLUMBIA G ENERATING S TATION Amendment 58 F INAL S AFETY A NALYSIS R EPORT December 2005 14.2-56 service water (SW), instrument power , and control air systems must have received readiness verification.
- c. General Test Methods and Acceptance Criteria Verification of the primary CAC system is demonstrated by th e proper integrated operation of the following:
- 1. Isolation and control valves, 2. Blowers, 3. Instrumentation,
- 4. Alarms, and
- 5. Recombiner components to the ext ent that flow paths are verified.
Primary CAC system hydrogen/oxygen recombining performance capabilities are not demonstrated during the preoperational test.
14.2.12.1.33 Primary Containment C ooling System Preoperational Test
- a. Purpose To verify the operation of the primary containment cooling system including fans, dampers, related contro ls, and instrumentation.
- b. Prerequisites
The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The 480-V ac power, instrument power, and RCC systems must have received re adiness verification.
- c. General Test Methods and Acceptance Criteria
Verification of the primary containment c ooling system is demonstrated by the proper integrated operation of the following:
- 1. Fans and control logic,
- 2. Cooling coils, 3. Dampers, cooling water flow c ontrol valves and related controls, 4. Instrumentation,
- 5. Related loss-of-power logic, and
- 6. Annunciators.
C OLUMBIA G ENERATING S TATION Amendment 58 F INAL S AFETY A NALYSIS R EPORT December 2005 14.2-57 Primary containment cooling system heat removal capabilities are not demonstrated during the preoperational test.
14.2.12.1.34 Primary Containment In strument Air Preoperational Test
- a. Purpose To verify proper operation of the containment instrument air (CIA) system, including compressors, dryers, valves, and related controls and logic.
- b. Prerequisites
The system lineup tests ha ve been completed, and th e TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The plant service water supply syst em must receive a readiness classification.
- c. General Test Methods and Acceptance Criteria Verification of the CIA system capability is demonstrated by the proper integrated operation of the following:
- 1. Logic and interlocks,
- 2. CIA system air compressors,
- 3. CIA system air dryers,
- 4. System nonreturn check valves,
- 5. Alarms and controls, 6. Nitrogen backup supply, and
- 7. Valve/component failure modes fo r those valves/components supplied by the CIA system to simula ted loss of air supply.
14.2.12.1.35 Primary Containment Atmospheric Monitoring System Preoperational Test
- a. Purpose To verify the capability of the primar y containment atmospheric monitoring system to monitor and display c ontainment atmospheric conditions.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-58 b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Instrument power is available to system components.
- c. General Test Methods and Acceptance Criteria Verification of the primary containment atmospheric monitoring system capability is demonstrated by the proper integrated operation of the following:
- 1. Samples and controls,
- 2. Analyzers, 3. Pressure and temperat ure instrumentation, 4. Radiation monitors,
- 5. Indicating/recording instrumentation, and
- 6. Annunciators.
14.2.12.1.36 Standby Gas Treatment System Preoperational Test
- a. Purpose To verify the reliable operation of the standby gas treatment system (SGTS), including fans, filter trai ns, and related controls.
- b. Prerequisites
The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The following sy stems must have readi ness verification:
- 1. Essential 480-V ac power,
- 2. Instrument power, 3. Control air, and 4. Reactor building heating and ventilation.
- c. General Test Methods and Acceptance Criteria Verification of the SGTS is demonstrated by the proper integrated operation of the following:
- 1. SGTS fans and control logic, C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-59 2. Filter trains and related instruments,
- 3. Automatic valves and control logic,
- 4. System interconnections to reactor building heating and ventilation and primary containment atmospheric control system, and
- 5. Annunciators.
14.2.12.1.37 Loss of Power and Safet y Testing Preoperational Test
- a. Purpose To verify the operation of the 230/
115-kV, 6.9-kV, 4.16-kV, and 480-V distribution systems.
To verify the integrated ability of the pl ant electrical distribution and safety systems to operate on normal and standby power sources during accident conditions.
To verify that loss of a single ac or dc distribution system division (exclusive of the HPCS diesel generator and batteries) will not prevent the remaining systems from actuating during an accident condition.
- b. Prerequisites The system lineup tests and the 69/N (N = number of diesels) consecutive starts from the emergency diesel generators have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The 125-V dc system and the emergency core cooling systems (ECCS) are av ailable to support testing.
- c. General Test Methods and Acceptance Criteria Verification of the 230/115-kV, 6.9-kV , 4.16-kV, and 480-V distribution systems operability shall be demons trated by the following:
- 1. Demonstration of circ uit integrity and integrat ed operation of circuit breakers, controls and interlocks, in strumentation, automatic transfer features, and protectiv e devices and alarms.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-60 2. Demonstration of proper system response to a loss of the 230-kV and 115-kV distribution systems independe ntly and simultaneously both with and without loss-of-coolant accident (LOCA)/containment isolation signals. 3. Demonstration of proper system response to a loss of the 230/115-kV distribution systems and one individual standby diesel generator during an ECCS/containment is olation actuation.
Signals for these tests shall be simu lated from the actual initiating devices when this is practical.
- 4. Testing of the diesel gene rators will include the following:
(a) Sequential loading of ea ch diesel generator unit, (b) Maintenance of specified fr equency and voltage during the loading sequence, (c) Capability to reject and restart their largest single load any time after the design loading se quence is complete, and
(d) Capability to supply power to vital equipment during loss of station normal power conditions.
- 5. Electrical independence will be verified duri ng testing by (a) Verifying that operation of the division/equipment being tested and the nonactuation of deener gized buses/equipment does not affect the proper operation of the remaining buses/equipment.
(b) Monitoring of the major distribu tion buses to ensure absence of voltage. Main power transformers supplying power from the offsite system cannot be full load tested; they ar e tested according to this procedure to the design emergency load. All other in-plant power sources are load tested in their individual preoperational tests.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-61 14.2.12.1.38 Instrument Power Preoperational Test
- a. Purpose To verify the operation of the instrument power systems.
- b. Prerequisites
The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
The 125-V dc and the 480-V ac power systems are energized and capable of supplying power to the inst rument power systems.
- c. General Test Methods and Acceptance Criteria Verification of the instrument power systems shall be accomplished by demonstrating circuit integrit y and integrated operation of
- 1. Static inverters, transformers, and buses, 2. Controls and interlocks,
- 3. Transfer features, 4. Instrumentation, and
- 5. Protective devices and alarms.
14.2.12.1.39 Emergency Lighting System Preoperational Test
- a. Purpose To verify the operation of the emergen cy lighting system within the design requirements of the system.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The 125-V dc system has receiv ed a readiness verification.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-62 c. General Test Methods and Acceptance Criteria Verification of the emergency lighting syst em is to demonstrate proper automatic operation of the system and to provide sufficient lighting during loss of normal lighting.
14.2.12.1.40 Standby Alternating Current Power System Preoperational Test
- a. Purpose To verify the operation of the standby ac power system includi ng diesel engines, auxiliaries, generators, cont rols, and instrumentation.
- b. Prerequisites
The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
The following support systems or components must have received readiness verification:
- 1. Standby service water,
- 2. 125/250-V dc power,
- 3. Instrument power, and
- 4. Essential 4160-V ac power.
- c. General Test Methods and Acceptance Criteria Verification of the standby ac power sy stem is demonstrated by the proper integrated operation of the following:
- 1. The diesel e ngines and auxiliaries, 2. The generators, excite rs, and voltage regulators, 3. Fuel storage and supply system, 4. Start and control logic circuitry and interlocks, 5. Protective devices, 6. Instrumentation, and
- 7. Annunciators.
Testing will be performed to demonstrate the fo llowing design features.
C OLUMBIA G ENERATING S TATION Amendment 60 F INAL S AFETY A NALYSIS R EPORT December 2009 LDCN-08-025 14.2-63 1. The diesel generator's performan ce capability to establish frequency, voltage, and load acceptance with a specified time interval on initiation of an automatic start signal un der both cold and hot conditions.
- 2. Specified full- and over-load performance capabilities.
- 3. The diesel generator's capability to reject the maximum rated load without exceeding speeds or volt age which will cause tripping.
14.2.12.1.41 250-V Direct Current Power System Preoperational Test
- a. Purpose
To verify the operation of the 250-V dc power system including batteries, chargers, controls, inte rlocks, instruments, and protective devices.
- b. Prerequisites
The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Battery room ventilation and 480-V ac power supply to the
chargers have received readiness verification.
- c. General Test Methods and Acceptance Criteria
Verification of the 250-V dc power syst em is demonstrated by the proper integrated operation of the following:
- 1. Battery chargers incl uding capability to recharge the battery in accordance with Section 8.3.2.1.4.3 ,
- 2. Batteries (including charge and discharge ra te/capacity tests and load profiles described in Table 8.3-14
),
- 3. Protective relays and devices, 4. System control logic,
- 5. Instrumentation (inc luding ground detection),
- 6. Breakers, and
- 7. Annunciators.
C OLUMBIA G ENERATING S TATION Amendment 60 F INAL S AFETY A NALYSIS R EPORT December 2009 LDCN-08-025 14.2-64 14.2.12.1.42 125-V Direct Current Power System Preoperational Test
- a. Purpose
To verify the operation of the 125-V dc power system including batteries, chargers, controls, inte rlocks, instruments, and protective devices.
- b. Prerequisites
The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Battery room ventilation and 480-V ac power supply to the
chargers have received readiness verification.
- c. General Test Methods and Acceptance Criteria
Verification of the 125-V dc power syst em is demonstrated by the proper integrated operation of the following:
- 1. Battery chargers incl uding capability to recharge the battery in accordance with Section 8.3.2.1.1.3 ,
- 2. Batteries (including charge and discharge rate/capacity tests and load profiles described in Tables 8.3-11 and 8.3-12),
- 3. Protective relays and devices,
- 4. System control logic,
- 5. Instrumentation (inc luding ground detection),
- 6. Breakers, and
- 7. Annunciators.
14.2.12.1.43 24-V Direct Current Power System Preoperational Test
- a. Purpose To verify the operation of the 24-V dc power system.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-65 b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
- c. General Test Methods and Acceptance Criteria Verification of the 24-V dc power system shall include demonstr ations of battery capacity and battery charger capab ilities described in Section 8.3.2.1.3.3. 14.2.12.1.44 Plant Service Wate r System Preoperational Test
- a. Purpose To demonstrate the proper operation of th e plant service water system, including pumps, valves, and related controls.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
The following support systems or components must have received readiness verification:
- 1. 4160-V ac power,
- 2. 480-V ac power,
- 3. Instrument power,
- 4. Service water pump house structure,
- 5. Various heat exchangers or c oolers utilizing se rvice water, and 6. Tower makeup (TMU).
- c. General Test Methods and Acceptance Criteria Verification of the plant service water system is demonstrated by the proper operation and performance of the servi ce water pumps, the operation of filters, remote-operated valves, related controls, and instrumentation.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-66 14.2.12.1.45 Standby Service Water System Preoperational Test
- a. Purpose To verify the proper operation of the SW system for norma l and abnormal plant operating modes.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The following s upport systems or components must have received readiness verification:
- 1. Essential 4160-V ac power, 2 Instrument power,
- 3. Control air,
- 4. Standby service water pump house structure, 5. Various heat exchangers or coolers utilizing SW, and 6. Tower makeup (TMU).
- c. General Test Methods and Acceptance Criteria Verification of this system is demonstr ated by the proper integrated operation and performance of the following:
- 1. Pumps and related controls,
- 2. Remote-operated valves and controls,
- 3. Automatic-operated va lves and control logic,
- 4. Instrumentation,
- 5. Annunciators,
- 6. Standby service water system control logic resp onse to a simulated loss of normal station power event,
- 7. Pumps net positive suction head (NPSH) adequate and no vortexing,
- 8. Proper operation of basin siphon cross connection, and
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-67 9. The preoperational test program includes tests to confirm the performance characte ristics of the spra y ponds (see Section 9.2.5). 14.2.12.1.46 Plant Communications System Preoperational Test
- a. Purpose To demonstrate that the plant communications and evacuation alarm system will
provide effective communication between various plant locations and to verify proper operation of the emergency evacuation alarm components and system.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
- c. General Test Methods and Acceptance Criteria Proper operation of all the communication system components and the emergency evacuation alar m system and components will be demonstrated.
14.2.12.1.47 Reactor Building Emergency Cooling System Preoperational Test
- a. Purpose To demonstrate the proper integrated operation of the reactor building emergency equipment cooling syst em including fans, cooling coils, instrumentation, and controls.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The following s upport systems or components must have received readiness verification:
- 1. Electrical power to motors, contro l circuits, and instrumentation, and 2. Standby service water system.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-68 c. General Test Methods and Acceptance Criteria Verification of this system is demonstrated by the proper integrated operation of
the fan coil units, their associated controls, in terlocks, and annunciators.
14.2.12.1.48 Control, Cable, and Critical Switchgear Rooms Heating, Ventilating, and Air Conditioning System Preoperational Test
- a. Purpose To verify that the control, cable, a nd critical switchgear rooms HVAC systems will function in accordance with the de sign requirements as set forth in the design specifications.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The following s upport systems have received readiness verification:
- 1. 480-V ac power,
- 2. Instrument power, and
- 3. Chilled water.
- c. General Test Methods and Acceptance Criteria Verification of the control, cable, and critical switchgear room s HVAC system is demonstrated by the proper integr ated operation of the following:
- 1. Supply and exhaust fans and their related controls, 2. Filters, dampers, valv es, and related instrumenta tion and control logic, 3. Coolers, and
- 4. Annunciators.
14.2.12.1.49 Standby Service Water Pump House Hea ting and Ventilating System Preoperational Test
- a. Purpose To verify that the SW pump house hea ting and ventilating system will function in accordance with the design requireme nts as set forth in the design specifications.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-69 b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The 480-V ac power system must ha ve received readiness verification.
- c. General Test Methods and Acceptance Criteria Verification of the SW pump hous e heating and ventilating system is demonstrated by the proper integr ated operation of the following:
- 1. Ventilation fans and their related controls,
- 2. Filters and instrumentation,
- 3. Dampers and controls, and
- 4. Annunciators.
14.2.12.1.50 Reactor Building Crane Preoperational Test
- a. Purpose To verify the operation of the reactor building crane.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. Construction load tests of 125% static and 100%
operational are complete.
Contractor use of the reactor buildi ng crane for construction purposes is complete.
- c. General Test Methods and Acceptance Criteria Verification of the reactor building cr ane is demonstrated by the proper integrated operation of the following:
- 1. Crane traverse components,
- 2. Hook traverse and hoist components,
- 3. Controls and indicators,
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-70 4. Safety devices, and
- 5. Instrumentation.
14.2.12.1.51 Primary Containment Integrated Leak Rate Preoperational Test
- a. Purpose To verify overall primary c ontainment integrity by pressurizing to specified test pressures and conducting integrated leak rate measurements.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The following supporting activities, systems, or components must have been completed or received readiness verification:
- 1. All type B and C local leak testing completed, documented, and verified as a system lineup test; see Section 6.2.6.1 ,
- 2. All containment isolation valves fully operable and closed in the normal manner,
- 3. All containment-associated piping hangers, supports , restraints, and anchors have been insta lled and properly set,
- 4. Residual heat removal and core spray systems preoperational tests complete, and
- 5. A containment area survey complete d to locate, isolate, or remove any instrumentation, light bulbs, etc., which may be damaged by high external pressure.
- c. General Test Methods and Acceptance Criteria Verification of primary containment integrity is demonstrated by pressurizing to the required test pressure. See Section 6.2.6.1 for a detailed test description.
The drywell-wetwell leakage te st will be performe d as part of this test to verify the acceptance criteria described in Section 3.8.3.7.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 LDC N-0 2-0 3 6 14.2-71 14.2.12.1.52 Secondary Contai nment Integrated Leak Ra te Preoperational Test
- a. Purpose To verify overall secondary containment integrity by subjecting the reactor
building to a specified negative pr essure and measuring the inleakage.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The following supp orting activities or systems/components must have been completed or received readiness verification:
- 1. Reactor building structure comple te with personnel and vehicle air lock (railroad bay) doors installed and operable, 2. Reactor building conduit, pipe, and ot her structural penetrations sealed, and
- c. General Test Methods and Acceptance Criteria Verification of secondary containment inte grity is demonstrated by operating the SGTS at a specific capacity while maintaining the reactor building internal structure at a specifi ed negative pressure.
14.2.12.1.53 Diesel Generator Building He ating and Ventilating Sy stem Preoperational Test a. Purpose To verify that the diesel generator bu ilding heating and ventilating system will function in accordance with the design re quirements as set forth in the design specifications.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing. The 480-V ac power system must ha ve received readiness verification.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-72 c. General Test Methods and Acceptance Criteria Verification of the diesel generator building heating and ven tilating system is demonstrated by the proper integr ated operation of the following:
- 1. Ventilation fans and their related controls,
- 2. Filters and instrumentation,
- 3. Dampers and controls, and
- 4. Annunciators.
14.2.12.1.54 Seismic Monitoring System Preoperational Test
- a. Purpose To verify the operation of the seismic monitoring system.
- b. Prerequisites The system lineup tests have been completed, the TWG has reviewed and approved the procedure, and the Test and Startup Manager has approved the initiation of testing.
- c. General Test Methods and Acceptance Criteria Verification of the seismic monitoring sy stem is demonstrat ed by the proper integrated operation of the following:
- 1. Annunciators, and
- 2. Instrumentation.
14.2.12.2 General Discu ssion of Startup Tests All those tests comprising the startup test phase (Table 14.2-4) are discussed in this section.
For each test a description is pr ovided for test purpose, test prer equisites, test description, and statement of test acceptance criteria, where applicable.
In describing the purpose of a test, an attempt is made to identify those operating and safety-oriented characte ristics of the plant wh ich are being explored.
Where applicable, a definition of the relevant ac ceptance criteria for th e test is given and is designated either Level 1 or Level 2. A Level 1 criterion normally rela tes to the value of a process variable assigned in the design of the plant, components, systems, or associated C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-73 equipment. If a Level 1 criterion is not sa tisfied, the plant will be placed in a suitable hold-condition until resolution is obtained. Tests compatible with this hold-condition may be continued. Following resolution, applicable tests must be repeated to verify that the requirements of the Level 1 criterion are now satisfied.
A Level 2 criterion is associated with expectations relating to the performance of systems. If a Level 2 criterion is not satisfied, operating and tes ting plans would not necessarily be altered.
Investigations of the measuremen ts and of the analytic al techniques used for the predictions would be started.
For transients involving oscillatory response, the criteria are specified in terms of decay ratio (defined as the ratio of successive maximum amplitudes of the sa me polarity). The decay ratio must be less than unity to meet a Level 1 cr iterion and less than 0.25 to meet a Level 2 criterion.
14.2.12.3 Startup Test Procedures 14.2.12.3.1 Test Number 1 - Chemical and Radiochemical
14.2.12.3.1.1 Purpose. The principal objectives of this test are to (a) secu re information on the chemistry and radiochemistry of the reactor coolant, and (b) determine that the sampling equipment, procedures, and analytic techniques are adequate to supply the data required to demonstrate that the chemistry of all parts of the entire reacto r system meet specifications and process requirements.
Specific objectives of the test program include eva luation of fuel performance, evaluations of demineralizer operations by direct and indirect met hods, measurements of filter performance, confirmation of condenser integrity, demonstration of proper steam sepa rator-dryer operation, measurement and calibration of the offgas system, and calibration of certain process instrumentation. Data for thes e purposes is secured from a vari ety of sources: plant operating records, regular routine coolant analysis, radiochemical measurements of specific nuclides, and special chemical tests.
14.2.12.3.1.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.1.3 Description. Prior to fuel loading a complete set of chemical and radiochemical samples will be take n to ensure that all required sample stations are functioning properly and to determine initial concentrations. Subsequent to fuel loading during reactor heatup and at each major power level change, samples will be taken and measurements will be made to determine the chemical and radiochemical quality of reactor water and reactor C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-74 feedwater, amount of radiolytic gas in the steam, gaseous activ ities leaving the air ejectors, decay times in the offgas lines and pe rformance of filters and demineralizers.
Calibrations will be made of monitors in the stack, liquid waste system, and liquid process lines.
14.2.12.3.1.4 Criteria. Level 1 Chemical factors defined in th e Technical Specifications and Fuel Warranty must be maintained within the lim its specified.
The activity of gaseous liquid effluents must conform to license limitations.
Water quality must be known at all times and shou ld remain within the guidelines of the Water Quality Specifications.
Level 2 Not applicable.
14.2.12.3.2 Test Number 2 - Radiation Measurements
14.2.12.3.2.1 Purpose. The purposes of this test ar e to (a) determin e the background radiation levels in the plant environs prior to operation for base data on activity buildup, and (b) monitor radiation at select ed power levels to ensure th e protection of personnel during plant operation.
14.2.12.3.2.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.2.3 Description. A survey of natural background radiation throughout the plant site will be made prior to fuel l oading. Subsequent to fuel loading, during reactor heatup and at nominal power levels of 25%, 60%, and 100% of rated power, gamma dose rate measurements and where appropriate, neutron dose rate measurem ents will be made at significant locations throughout the plant. All potentially high radiation areas will be surveyed.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-75 14.2.12.3.2.4 Criteria. Level 1 The radiation doses of plant or igin and the occupancy times of personnel in radiation zones shall be controlled consistent with the guidelines of the St andards for Protection Against Radiation outlined in 10 CFR 20 and the NR C General Design Crite ria in 10 CFR 50, Appendix A.
Level 2 Not applicable.
14.2.12.3.3 Test Number 3 - Fuel Loading
14.2.12.3.3.1 Purpose. The purpose of this test is to l oad fuel safely and efficiently to the full core size.
14.2.12.3.3.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiation of testing. Also the following prerequisites will be met prior to commencing fuel loading to ensure that this operation is performed in a safe manner:
- a. The status of all systems required for fuel loading will be specified and will be in the status required;
- b. Fuel and control rod inspections will be complete. Control rods will be installed and tested;
- c. At least three movable neutron detectors will be ca librated and operable. At lease three neutron detectors will be connected to the high flux scram trips.
They will be located so as to provide acceptable signals during fuel loading;
- d. Nuclear instruments will be source checked with a neutron source prior to loading or resumption if sufficient delays are incurred;
- e. The status of secondary containment will be specified and established;
- f. Reactor vessel status will be specified relative to internal component placement and this placement established to ma ke the vessel ready to receive fuel;
- g. Reactor vessel water l evel will be established and minimum level prescribed;
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-76 h. The standby liquid control system will be operable and in readiness;
- i. Fuel handling equipment will have been checked and dry runs completed;
- j. The status of protection systems, interlocks, mode switches, alarms, and radiation protection equipm ent will be prescribed an d verified. The high flux trip points will be set for a relatively low power level;
- k. Water quality must meet required specifications; and
- l. A neutron source will be installe d near the center of the core.
14.2.12.3.3.3 Description. Prior to fuel loading, cont rol rods and neut ron sources and detectors will be installed and tested. Fuel l oading will begin at the center of the core and will proceed radially to the fu lly loaded configuration.
Control rod functional tests, s ubcriticality checks, and shutdown margin demonstrations will be performed periodicall y during the loading.
14.2.12.3.3.4 Criteria. Level 1 The partially loaded core must be subcritical by at least 0.38% k/k with the analytically strongest rod fu lly withdrawn.
Level 2 Not applicable.
14.2.12.3.4 Test Number 4 - Full Core Shutdown Margin
14.2.12.3.4.1 Purpose. The purpose of this test is to demonstrate that the reactor will be subcritical throughout the first fuel cycle with any single control rod fully withdrawn.
14.2.12.3.4.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiation of testing. Also the following prerequisites will be complete prio r to performing the full core shutdown margin test: a. The predicted critical rod position is available,
- b. The standby liquid contro l system is available, C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-77 c. Nuclear instrumentation is available with neutron count rate of at least
0.5 counts
per sec and signal to no ise ratio greater than two, and
- d. High-flux scram trips are set conservatively low.
14.2.12.3.4.3 Description. This test will be performed in the fully loaded core in the xenon-free condition. The shutdown margin test will be performed by withdrawing the control rods from the all-rods-in configuration until criticality is reached. If the highest worth rod will not be withdrawn in sequence, ot her rods may be withdrawn prov iding that the reactivity worth is equivalent. The difference between the measure K eff and the calculated K eff for the in sequence critical will be applied to the calculated value to ob tain the true shutdown margin.
14.2.12.3.4.4 Criteria. Level 1 The shutdown margin of the fully loaded, cold (68 F or 20C), xenon-free core occurring at the most reactive time during the cyc le must be at least 0.38% k/k with the analytically strongest rod (or its reactivity equivalent) withdrawn. If the shutdown ma rgin is measured at some time during the cycle other than the most active time, compliance with the above criterion is shown by demonstrating that the shutdown margin is 0.38% k/k plus an exposure dependent correction factor which corrects the shutdown margin at that time to the minimum shutdown margin. Level 2 Criticality should occur within 1% k/k of the predicted critical (predicted critical to be determined later).
14.2.12.3.5 Test Number 5 -
Control Rod Drive System
14.2.12.3.5.1 Purpose. The purposes of the CRD system te st are to (a) demonstrate that the CRD system operates properly ov er the full range of primar y coolant temperatures and pressures from ambient to opera ting, and (b) determine the initia l operating characteristics of the entire CRD system.
14.2.12.3.5.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiati on of testing. The RMC system preoperational tes ting must be completed on CRDs being tested. The reactor vessel, RCC system, condensate supply system, and instrument ai r system must be operational to the extent required to conduct the test.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-78 14.2.12.3.5.3 Description. The C R D tests performed dur i ng the startup test program are designed as an extension of the te sts performed during the preoperational CRD system tests.
Thus, after it is verified that all CRDs op e rate properly when ins t alled, they are tested periodically during hea t up to ensu re that there is not signifi c ant binding caused by thermal expansion of the core components.
Test Conditions Reactor Pressure with Core Loaded Accumulator psig (kg/c m 2) Action Pressure 0 600 (42.2) 800 (56.2) Rated Position indication All Normal stroke ti m es All 4* insert/withdraw
Coupling Al l** 4*
Friction All 4*
Scram Normal All 4* 4* All Scram Minimum 4*
Scram Zero 4*
Scram Normal 4***
NOTE: Single CRD scrams should be performed with the char ging valve closed. (Do not ride the charging pump head.)
- Refers to four CRDs selected for continuous monitoring bas ed on slow normal accumulator pressure scram times, or unusual op erating characteristics, at ze ro reactor pressure or rated reactor pressure when this data is available.
The "four selected CRDs" must be compatible with the RWM, RSC system, and CRD sequence requirements.
- Established initially that this ch eck is normal opera ting procedures.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-79 14.2.12.3.5.4 Criteria. Level 1 a. Each CRD must have a normal withdraw speed less than or equal to 3
.6 in./sec (9.14 cm/sec), indicated by a full 12-ft stroke in greater than or equal to 40 sec.
- b. The mean scram time of all operable C R Ds with functioning accumulators must not exceed t h e following times (s cr a m ti m e is m e asured fr o m the time t h e pilot scram valve solenoids are deenergized):
Position Inserted From Scram Time Fully Withdrawn (sec) 45 0.430 39 0.868 25 1.936 05 3.497 c. The mean scram time of t h e three fa stest CRDs i n a two-by-two array must not exceed the f o llowing times (s cr am time is meas u r ed from the time the pilot scram valve solenoids are dee n ergi z e d): Position Inserted From Scram Time Fully Withdrawn (sec) 45 0.455 39 0.920 25 2.052 05 3.706 Level 2 a. Each CRD must have normal inse rt or withdraw speed of 3.0 0.6 in./sec (7.62 1.52 cm/sec), indicated by a full 12-ft stroke in 40 to 60 sec.
- b. With respect to the CRD friction tests, if the differential pressure variation exceeds 15 psid (1.1 kg/cm
- 2) for a continuous drive in , a settling test must be performed, in which case the differential settling pressure should not be less
than 30 psid (2.1 kg/cm
- 2) nor should it vary by more than 10 psid (0.7 kg/cm
- 2) over a full stroke.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 LDC N-0 2-0 0 0 14.2-80 Level 3 a. On receipt of a simulated or actual scram signal (maximum error), the flow control valve must close to its mini mum position within 10 sec to 30 sec.
- b. The CRD system flow shoul d not change by more than 3.0 gpm as reactor pressure varies from 0 to rated pressure.
- c. The decay ratio of any oscilla tory controlled variable must be 0.25 for any flow setpoint changes or for syst em disturbances caused by the CRDs being stroked.
14.2.12.3.6 Test Number 6 - Source Range Monitor Performance and Control Rod Sequence 14.2.12.3.6.1 Purpose. The purpose of this test is to demonstrate that the operational sources, SRM instrumentation, and rod withdrawal sequences pr ovide adequate information to achieve criticality and increase power in a safe and efficient manner.
The effect of typical rod movements on reactor power will be determined.
14.2.12.3.6.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiati on of testing. The CRD system must be operational.
14.2.12.3.6.3 Description. Source range monitor count-range data will be taken during rod withdrawals to critical and comp ared with stated criteria on si gnal count-to-noi se count ratio.
A withdrawal sequence has been calculated which completely sp ecifies control rod withdrawals from the all-rods-in condition to the rated power configuration. Critical rod patterns will be recorded periodically as the reactor is heated to ra ted temperature.
Movement of rods in a prescrib ed sequence is monitored by the rod control and information system, which will prevent out of sequence withdrawal. Also not more than two rods may be
inserted out of sequence.
As the withdrawal of each rod group is completed during the power ascension, the electrical power, steam flow, control valve positi on, and APRM response will be recorded.
14.2.12.3.6.4 Criteria. Level 1 There must be a neutron signal-to-noise ratio of at least 2 to 1 on the required operable SRMs or fuel loading chambers.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-81 There must be a minimu m count rate of 0.5 counts/sec on the required operable SRMs or fuel loading chambers.
The IRMs must be on scale before th e SRMs exceed the rod block setpoint.
Level 2 Not applicable.
14.2.12.3.7 Test Number 7
Not applicable.
14.2.12.3.8 Test Number 8
Not applicable.
14.2.12.3.9 Test Number 9
See test number 16B in Section 14.2.12.3.16.2.
14.2.12.3.10 Test Number 10 - Intermedia te Range Monitor System Performance
14.2.12.3.10.1 Purpose. The purpose of this test is to adjust the IRM system to obtain an optimum overlap with the SRM and APRM systems.
14.2.12.3.10.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiation of testing. All SRMs and pulse preamplifiers, IRMs and voltage preamplifiers, and APRMs have been calibrated in accordance with the vendor's instructions.
14.2.12.3.10.3 Description. Initially the IRM system is se t to maximum gain. After the APRM calibration, the IRM gains will be adjusted to optimize th e IRM overlap with the SRMs and APRMs.
14.2.12.3.10.4 Criteria. Level 1 Each IRM channel must be on scale before the SRMs exceed their rod block setpoint. Each APRM must be on scale before the IRMs exceed their rod block setpoint.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-82 Level 2 Each IRM channel must be adjus ted so that a half decade ov erlap with the SRMs and one decade overlap with the APRMs are ensured.
14.2.12.3.11 Test Number 11 - Loca l Power Range M onitor Calibration
14.2.12.3.11.1 Purpose. The purpose of this test is to calibrate the LPRM system.
14.2.12.3.11.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation for calibration has been checked and installed.
14.2.12.3.11.3 Description. The LPRM channels will be calibrated to make the LPRM readings proportional to the neutron flux in the LPRM water gap at the chamber elevation.
Calibration factors will be obtai ned through the use of either an off-line or a process computer calculation that relates the L PRM reading to average fuel as sembly power at the chamber height.
14.2.12.3.11.4 Criteria. Level 1 Not applicable.
Level 2 Each LPRM reading will be within 10% of its calculated value.
14.2.12.3.12 Test Number 12 - Aver age Power Range Monitor Calibration
14.2.12.3.12.1 Purpose. The purpose of this test is to calibrate the APRM system.
14.2.12.3.12.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation for calibration has been checked and installed.
14.2.12.3.12.3 Description. A heat balance will generally be made each shift and after each major power level change. Each APRM channel re ading will be adjusted to be consistent with the core thermal power as determined from the heat balance. Duri ng heatup a preliminary calibration will be made by adjusting the APR M amplifier gains so that the APRM readings agree with the results of a constant heatup rate heat balance. The APRMs should be recalibrated in the power range by a heat balance as soon as adequate feedwater indication is C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-83 available. Recalibration of the APRM system will not be necessary from safety considerations if at least two APRM channels per RPS trip circuit have readings gr eater than or equal to core power.
14.2.12.3.12.4 Criteria. Level 1 The APRM channels must be calibrated to read e qual to or greater t han the actual core thermal power.
Technical Specifications and Fuel Warranty Limits on APRM scram and rod block shall not be exceeded.
In the startup mode, all APRM channels must produ ce a scram at less than or equal to 15% of rated thermal power.
Level 2 If the above criteria ar e satisfied then the APRM channels will be considered to be reading accurately if they agree with the heat balance or the minimu m value required based on peaking factor maximum linear heat generation rate (M LHGR) and fraction of ra ted power to within
(+7, -0)% of rated power.
14.2.12.3.13 Test Number 13 - Process Computer
14.2.12.3.13.1 Purpose. The purpose of this test is to ve rify the performance of the process computer under plant operating conditions.
14.2.12.3.13.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Computer diagnostic test ing has been completed. Constr uction and construc tion testing on each input instrument and its cabling has been completed.
14.2.12.3.13.3 Description. Computer system program verifications and calculational program validations at static and at si mulated dynamic input conditions will be preoperationally tested at the co mputer supplier's site and following delivery to the plant site. Following fuel loading, during plant heatup a nd the ascension to rated power, the NSSS and the balance-of-plant system process variables sensed by the co mputer as digital or analog signals will become available. Verify that the computer is receiving correct values of NSSS process variables and that the resu lts of performance calculations of the NSSS is correct. At steady-state power conditions the dynamic system te st case will be performed.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-84 As discussed in Test 19 the BUCLE offline comput ation system will be used to evaluate core performance until the process co mputer performance is verifi ed. A manual computation method is available at the site if both the pr ocess computer and BUCLE are not available.
14.2.12.3.13.4 Criteria. Level 1 Not applicable.
Level 2 Programs OD-1, P1, and OD-6 will be considered operational when
- a. The MCPR calculated by BUCLE and the process computer either
- 1. Are in the same fuel assembly and do not differ in value by more than 2%, or
- 2. For the case in which the MCPR calculated by the process computer is in a different assembly than that calcul ated by BUCLE, for each assembly, the MCPR and CPR calculated by th e two methods shall agree within 2%. b. The MLHGR calculated by BUCL E and the process computer either
- 1. Are in the same fuel assembly and do not differ in value by more than 2%, or
- 2. For the case in which the MLHGR ca lculated by the process computer is in a different assembly than that calculated by BUCLE, for each assembly, the MLHGR and LHGR calc ulated by the two methods shall agree within 2%.
- c. The maximum average planar linear heat generation rate (MAPLHGR) calculated by BUCLE and the process computer either
- 1. Are in the same fuel assembly and do not differ in value by more than 2%, or
- 2. For the case in which the MAPLHGR calculated by the process computer is in different assembly than that calculated by BUCLE, for each C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-85 assembly, the MAPLHGR and APLHGR calculated by the two methods shall agree within 2%.
- d. The LPRM gain adjustment factors calculated by BUCLE and the process computer agree to within 2%.
- e. The remaining programs will be considered operational on successful completion of the static and dynamic testing.
14.2.12.3.14 Test Number 14 - Reactor Core Isolation Cooling System
14.2.12.3.14.1 Purpose. The purpose of this test is to verify the proper operation of the RCIC system over its expected operating pressure range.
14.2.12.3.14.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
14.2.12.3.14.3 Description. The RCIC system test consists of two parts: Injection to the condensate storage tank and injec tion to the reactor vessel. Th e initial condensate storage tank (CST) injections consist of manual and automatic starts at 150 psi and at rated reactor pressure. The pump discharge pr essure during these tests is th rottled to 100 psi above reactor pressure. This initial testing is done to demonstrate system operability and making initial controller adjustments. This is followed by vessel injecti ons beginning with cold RCIC hardware; "cold" being defined as a minimum of 3 days wit hout any kind of RCIC operation.
The vessel injections verify the adequacy of the startup transient and also include steady-state controller adjustments. Five consecutive successful system initiations starting from cold condition and with the same equipm ent settings are necessary to demonstrate system reliability.
Two of these initiations are vessel injection tests with one pe rformed using the controllers on the remote shutdown panel.
After final controller settings are determined, three CST injections at rated pressure and/or 150 psig pressure are done with initially cold RCIC equipment.
These runs provide a bench mark for future surveillance testing and provide further assu rance of system reliability.
A demonstration of extended ope ration of 30 minutes of continuous running until pump and turbine oil temperature is stabili zed is scheduled at a convenie nt time during the test program, probably in conjunction w ith one of the system reliability te sts. During this demonstration, automatic RCIC suction transfer from the CST to the suppression pool will be performed to confirm system stability in this configuration.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-86 During vessel injections all reac tor steam is routed to the turbine bypass valves. The steam admission valves of the main and feedwater turb ines should be closed whenever the moisture carryover threshol d is reached.
14.2.12.3.14.4 Criteria. Level 1 The average pump discharge flow must be equal to or greater than 600 gpm after 30 sec have elapsed from automatic initiati on at any reactor pressure between 150 psig and rated.
The RCIC turbine must not trip off or isolate during auto or manual start tests.
If any Level 1 criteria are not met, the reactor operation will be restricted to the power level defined by Figure 14.2-5. This restriction is in addition to a n y restricti o ns defined by the Technical Specifications.
Level 2 The turbine gland seal condenser system shall be capable of preventing steam leakage to the atmosphere.
The differential pressure switch for the RCIC steam supply line high flow isolation trip shall be adjusted to actuate at the valve specified in the Technical Specifi cations (about 300%).
The speed and flow control loops shall be adjusted so that the decay ratio of any RCIC system related variable is not greater than 0.25.
To provide an overspeed trip av oidance margin, the transient st art first and subsequent speed peaks shall not exceed 5% above th e rated RCIC turbine speed.
14.2.12.3.15 Test Number 15
Not applicable.
14.2.12.3.16 Test Numbers 16A and 16B 14.2.12.3.16.1 Test Number 16A - Selected Process Temperatures. 14.2.12.3.16.1.1 Purpose. The purpose of this test is to (a) ensure that th e measured bottom head drain temperature corres ponds to bottom head coolant temperature during normal operations, (b) identify any reactor operating modes that cause temperature stratification, (c) determine the proper setting of the low flow control limiter fo r the recirculation pumps to C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-87 avoid coolant temperature stratification in the RPV bottom head region, and (d) familiarize the plant personnel with the temp erature differential limitations of the reactor system.
14.2.12.3.16.1.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
14.2.12.3.16.1.3 Description. The adequacy of bottom drain lin e temperature sensors will be determined by comparing it with recirculation loop coolant temp erature when core flow is 100% of rated.
During initial heatup while at hot standby conditions, the bottom drain line temperature, recirculation loop suction temperature, and applicable reactor parameters are monitored as the recirculation flow is slowly lowered to either minimum stable flow or the low recirculation pump speed minimum valve position, whichever is the greater.
The effects of cleanup flow will be investigated as operational limits allow. Using this data it can be determined whether coolant temperature stratification occurs and if so, what minimum recirculation flow will
prevent it.
Monitoring the preceding informa tion during planned pump trips will determine if temperature stratification occurs in the idle recirculation loops or in the lower plenum when one or more loops are inactive.
All data will be analyzed to determine if c hanges in operating proce dures are required.
14.2.12.3.16.1.4 Criteria. Level 1 a. The reactor recirculation pumps shall not be starte d nor flow increased unless the coolant temperatures between the steam dome and bottom head drain are within 145 F (81 C). b. The recirculation pump in an idle l oop must not be star ted, active loop flow must not be raised, and power must not be increased unless the idle loop suction temperature is with in 50 F (28 C) of the active loop suc tion temperature. If two pumps are idle, the loop sucti on temperature must be within 50 F (28 C) of the steam dome temperature before pump startup.
Level 2 During two-pump operation at rated core flow, the bottom head temperat ure as measured by the bottom drain line thermo couple should be within 30 F (17 C) of the recirculation loop temperatures.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-88 14.2.12.3.16.2 Test Number 16B - Water Le vel Reference Leg Temp erature Measurement. 14.2.12.3.16.2.1 Purpose. The purpose of this test is to measure the reference leg temperature and recalibrate the affected level inst ruments if the measur ed temperature is different than the value assume d during the initial calibration.
14.2.12.3.16.2.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiation of testing. All applicable system instrumentati on is installed and calibrated.
14.2.12.3.16.2.3 Description. To monitor the reacto r vessel water level, five level instrument systems are provided. These are
- a. Shutdown range level system,
- b. Narrow range level system,
- c. Wide range level system,
- d. Fuel zone level system, and
- e. Upset range.
These systems are used respectively as follows:
- a. Water level measurement in cold shutdown conditions (shutdown range level system),
- b. Feedwater flow and wate r level control functions in hot operating conditions (narrow range level system),
- c. Safety functions in hot operating conditions (wide range level system),
- d. Safety functions in cold shutdown co nditions (fuel zone level system), and
- e. High water level protection, hot operating condition (upset range).
The test will be done at rate d temperature and pressure and unde r steady-state conditions and will verify that the reference leg temperature of the level instrument is the value assumed during initial calibration. If not, the instruments will be recalibrated using the measured
value.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-89 14.2.12.3.16.2.4 Criteria. Level 1 Not applicable.
Level 2 The indicator readings on the narrow r ange level system should agree with 1.5 in. of the average readings or the reading calculated from the correct reference leg temperatures.
The wide and upset range level syst em indicators should agree within 6 in. of the average readings or the readings calculated from the correct reference leg temperatures.
14.2.12.3.17 Test Number 17 - System Expansion
14.2.12.3.17.1 Purpose. The purpose of this test is to (a) verify that piping systems and components are unrestrained with respect to thermal expansion, (b) verify that suspension components are functioning in the specified manner, (c) provide confirmatory data for the calculated stress levels in nozzles and weldme nts, (d) perform an inspection to satisfy ASME Section XI, IWF-220 post heatup (shakedown) inspection requi rements, and (e) satisfy the inspection requirements for the condensate and feedwater system s according to Regulatory Guide 1.68.1.
14.2.12.3.17.2 Prerequisites. Necessary preoperational test s have been completed. The preheatup examination program relating to component supports as contained in the CGS Preservice Inspection Program Plan has been completed. The POC has reviewed and the Plant Manager has approved the test procedure and initiation of testing.
Instrumentation has been installed and calibrated.
14.2.12.3.17.3 Description. A significant mechanical desi gn objective for nuclear piping support systems is to provide for unrestricted thermal expansi on of piping and components, from ambient to rated temperature. The co mbination of visual and remote monitoring of selected piping systems will provide the data ne cessary to evaluate th e support system. The criteria used for syst em selection is Standard Review Plan Section 3.9.2 and those systems with a normal operating temperature greater than 250 F. The drywell piping systems selected for visual inspection and remote monitoring are the following:
- a. Reactor recirculation, b. Main steam,
- c. Feedwater,
- d. Residual heat removal (shutdown cooling supply and return line), e. Reactor core isolation cooling (steam supply and head spray line),
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-90 f. Safety/relief valve discharge piping, and g. Reactor water cleanup.
In addition, visual inspections only of the following drywell systems will be conducted:
- a. High-pressure core spray,
- b. Low-pressure core spray,
- c. Sacrificial shield wall penetrations,
- d. Residual heat removal (LPCI) injection lines, e. Main steam flow instrumentation piping, f. Main steam drain piping,
- g. Reactor head vent piping,
- h. Reactor coolant sample piping, and
- i. Standby liquid cont rol injection piping.
Piping support system components (hangers, sway struts, boxes , snubbers, and whip restraints) for the systems listed will be visually insp ected at ambient (less than or equal to 200 F), during the initial heatup cycle at an in termediate temperature (200 F to 300 F, equivalent to 30 psig reactor pressure) and at normal operating temperature (545 F, equivalent to 1000 psig reactor pressure). Data from the remote monitoring instrumentation will be recorded and evaluated at similar intervals. Exceptions to this are feedwater, main steam relief va lve (MSRV) discharge piping, and the reactor head sp ray and vent piping above the dryw ell bulkhead. The feedwater piping will attain rated temperatures only at higher reactor power le vels, which precludes drywell entry. The MSRV pipi ng is only heated up during valve actuation, which also represents a potential inspection personnel hazard. The area abo ve the bulkhead is considered hazardous due to confinement and high temperatures. The methods used to evaluate these are as follows:
- a. Feedwater drywell piping is instrumented and will be ev aluated at 25% and 100% reactor power using the data collected by the lanyard potentiometers.
- b. Two MSRV lines will be in strumented allowing data eva luation to be applied to all lines during SRV actuation.
- c. The piping above the bulkhead will be vi sually inspected pr ior to drywell head installation.
Feedwater and the SRV piping systems will also be inspected during the shakedown inspection.
The instrumented nodes will be provided with three sensors to indica te movement in three orthogonal plans. The ac tual node locations will be select ed through a coor dinated effort between the CGS Plant Technical and Technology organizations. In this way the analytically best suited node will be coupled with accessible locations. General El ectric will provide C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-91 locations and acceptance criteria for the recirculation and main steam systems. The Energy Northwest Mechanic's Department will provide similar information for the remainder of the systems tested. The in struments will provide thermal movement and vibration data that will be compared with predicted values. If these measured displace ments confirm the calculated values, coupled with acceptable vi sual inspections, the piping system will be considered to have responded as designed.
The type of lanyar d potentiometer monitors us ed enable the collection of thermal movement and vibration data. With the acceptance criteria for all testing based on the system design, conformance to the acceptance criteria indicates adherence to the analytical limits. On completion of the startup test, the piping response data and the comp leted test procedure will be reviewed by the Energy Northwest Engineering Department responsible for the Stress Report Review and GE. The review will determ ine if the test results indicate the piping responded in a manner cons istent with the Stress Report pred ictions and the ASME Code limits.
An Energy Northwest Level 3 inspector and the American Nuclear Insure rs (ANI) will sign all data sheets performing ASME Section XI inspections.
The drywell piping testing/inspections w ill be conducted during the PATP as follows:
- a. The visual inspections and thermal expansion data will be taken during the initial reactor heatup at thermal equilibrium conditions,
- b. During the course of the PATP, data will be collected during steady state and transient conditions for vibr ation level evaluation, and
- c. Near the end of the PATP a final dr ywell entry and inspection is scheduled.
Visual inspections will be c onducted on selected piping systems outside the drywell during thermal equilibrium, steady-state operation, and selected transient c onditions. The systems selected are:
- a. Main steam,
- b. Condensate and feedwater,
- c. RCIC steam supply and exhaust,
- d. RCIC injection piping, e. RHR shutdown cooling supply and return, f. Reactor water cleanup, and
- g. Main steam leakage control system.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-92 14.2.12.3.17.4 Criteria. Level 1 Thermally induced displacement of system components shall be unrestrained with no evidence of binding or impairment.
Spring hangers shall not be bottomed out or have the spring fully stretched.
Snubbers shall not reach the limits of their travel. The displacements at the established transducer locations used to me asure pipe deflections shall not exceed the allowable values.
The allowable values of displacement shall be based on not exceeding ASME Section III Code Stress allowables.
Level 2 Spring hangers will be in their operating r ange (between the hot and cold settings).
Snubber settings must be within their expected operating range.
The displacements at the estab lished transducer locations shall not exceed the expected values.
14.2.12.3.18 Test Number 18 - Core Power Distribution
14.2.12.3.18.1 Purpose. The purpose of this test is to determine the reproducibility of the TIP system readings.
14.2.12.3.18.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiati on of testing. The TIP detector and dummy de tector, ball valve time delay, core top and bo ttom limits, clutch, x-y recorder, and purge system will have been shown to be operational. Instrumentation has been calibrated and installed.
14.2.12.3.18.3 Description. The TIP reproducibility consists of a random noise component and a geometric component. The geometric component is due to variation in the water gap geometry and TIP tube orienta tion from TIP location to loca tion. Measurement of these components is obtained by taking repetitive TI P readings at a single TIP location, and by analyzing pairs of TIP readings taken at TIP locations which are symmetrical about the core diagonal of fuel loading symmetry.
One set of TIP data will be taken at the 50%
power level and at least one other set at 75%
power or above.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-93 The TIP data will be taken with the reactor operating with an oc tant symmetric rod pattern and at steady-state conditions.
The total TIP reproducibility is obtained by dividing the standard deviation of the symmetric TIP pair nodal ratios by two. The nodal TIP ratio is defined as the nodal base value of the TIP
in the lower right half of the core divided by its symmetric counterpart in the upper left half.
The total TIP reproducibility value t hat is compared with the test criterion is the average value of the data sets taken.
The random noise uncertainty is obtained from successive TIP runs made at the common hole, with each of the TIP machines making six runs. The standard devi ation of the random noise is derived by taking the square root of the average of the variances at nodal levels 5 through 22, where the nodal variance is obtaine d from the fractional deviations of the successive TIP values about their nodal mean value.
The geometric component of TI P reproducibility is obt ained by statistically subtracting the random noise component from the total TIP reproducibility.
14.2.12.3.18.4 Criteria. Level 1 Not applicable.
Level 2 The total TIP uncertainty (including random noise and geometrica l uncertainties) obtained by averaging the uncertainties for all da ta sets shall be less than 6.0%.
The data acquired for random noise uncertainty does not have specific acceptance criteria value and is used only to aid in th e analysis of the TIP uncertainty.
14.2.12.3.19 Test Number 19 - Core Performance
14.2.12.3.19.1 Purpose. The purposes of this test are to (a) evaluate the core thermal power, and (b) evaluate the following core performance parameters are within limits: (a) maximum linear heat generation rate (MLHGR), (b) minimum critical power ratio (MCPR), and (c) maximum average planar linear heat generation rate (MAPLHGR).
14.2.12.3.19.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
System instrumentation has been installed and calibrated, and te st instrumentation has been calibrated.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-94 14.2.12.3.19.3 Description. The core performance evaluati on is employed to determine the principal thermal and hydraulic par ameters associated with core behavior. These parameters are a. Core flow rate,
- b. Core thermal power level,
- c. MLHGR,
- d. MAPLHGR, and
- e. MCPR. The core performance parameters will be evaluated by manual calculati on techniques described in Startup Test Instruction 19 or may be obtained from the process computer.
If the process computer is used as a primary means to obtain these parameters, it must be proven that it agrees with BUCLE within 2% on all thermal parameters (s ee Test Number 13). If both BUCLE and the process co mputer are not available, th e manual calculation techniques described in Startup Test Inst ruction 19 can be used for the core performance evaluation.
14.2.12.3.19.4 Criteria. Level 1 The MLHGR of any rod during steady-state conditions shall not exceed the limit specified by the Technical Specifications.
The steady-state MCPR shall not exceed the minimum limits specified by the Technical Specifications.
The MAPLHGR shall not exceed the limits specifi ed by the Technical Specifications.
Steady-state reactor power shall be limited to the rated MWt and values on or below the design flow control line. Core flow s hall not exceed its rated value.
Level 2 Not applicable.
14.2.12.3.20 Test Number 20 - Steam Production
14.2.12.3.20.1 Purpose. The purpose of performing this test is to demonstrate that the NSSS is providing steam sufficient to satisfy all appropriate warranties as de fined in the contract.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-95 14.2.12.3.20.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
14.2.12.3.20.3 Description. Warranty demonstration consists of recording sufficient data under steady-state conditions to determine the reactor power level , the pressure and quality of the steam, and the steam flow rate from the reactor.
These measurements will include the temperature, pressure, and flow rate of feedwater entering the reactor; the energy added to the reactor water by th e recirculation drive pumps; the flow rate through and temperature ente ring and leaving the reactor cleanup system; the flow rate and temperature of the CRD coolin g water; the carryover of reac tor water into the steam lines, and the steam pressure outside the drywell near the MSIV.
Each set of measurements shall be taken at fr equent intervals, ever y 5 or 10 minutes as appropriate, for a total test run duration of 4 hr. The a verage measure quantity, suitably corrected for all ca libration factors, is used to determine NSSS output during the test run.
Where the contract requires a 100-hr demonstration, two test r uns shall be made, one in the first 50 hr and one in the second 50 hr. The demonstrated output is the average of the values from the two test runs. During the balance of the 100-hr demonstration, the NSSS output shall be held constant within 5% of the nominal steam flow rate as indicated by the installed plant feedwater instrumentation.
14.2.12.3.20.4 Criteria. Level 1 a. The NSSS parameters as determined by using normal operati ng procedures shall be within the appropriate license restrictions.
- b. The NSSS will be capable of suppl ying steam in an amount and quality corresponding to the final feedwater temperature and other conditions shown on the rated steam output curve in the NSSS technical descri ption. The rated steam output curve provides the warrantable re actor vessel steam output as a function of feedwater temperature, as well as warrantable steam conditions at the outboard MSIVs.
- c. Thermodynamic parameters are consiste nt with the 1967 ASME steam tables.
Correction techniques for conditions that differ from the contracted conditions will be mutually agreed to prior to the performance of the test.
Level 2 Not applicable.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-96 14.2.12.3.21 Test Number 21 - Core Power-Void Mode
14.2.12.3.21.1 Purpose. The purpose of this test is to measure the stability of the core power-void dynamic response and to demonstrate that its behavio r is within specified limits.
14.2.12.3.21.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
System instrumentation has been installed and calibrated, and test instrumentation calibrated.
14.2.12.3.21.3 Description. The core power void loop mode that results from a combination of the neutron kinetics and core thermal hydraulic dynamics is le ast stable near the natural circulation end of the rated 100% power rod line.
A fast change in the reactivity balance is obtained by a pressu re regulator step change (see test 22) and by moving a very high worth rod only 1 or 2 notches. Both local flux and total core response will be ev aluated by monitoring selected LPRMs dur ing the transient.
14.2.12.3.21.4 Criteria. Level 1 The transient response of any sy stem-related variable to any test input must not diverge.
Level 2 The decay ratio for each system-related variable containing os cillatory modes mu st be less than or equal to 0.5.
14.2.12.3.22 Test Number 22 - Pressure Regulator
14.2.12.3.22.1 Purpose. The purposes of this test are to: (a) determine the optimum settings for the pressure control loop by analysis of the transients indu ced in the reactor pressure control system by means of th e pressure regulators, (b) demonstrate the backup capability of the pressure regulators via simula ted failure of the controlling pr essure regulator and to set the regulating pressure difference between the two regulators at an appropriate value, (c) demonstrate smooth pressure control tr ansition between the control valves and bypass valves when reactor steam gene ration exceeds steam used by the turbine, and (d) demonstrate that affected parameters are within acceptable limits during pressure-regulator-induced transient maneuvers.
14.2.12.3.22.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initiation of testing.
Instrumentation has been checked or calibrated as appropriate.
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-97 14.2.12.3.22.3 Description. The pressure setpoint will be decreased rapidly and then increased rapidly by about 10 psi (0.7 kg/cm
- 2) and the response of the system will be measured in each case. It is desirable to accomplish the setpoint change in less than 1 sec. At specified test conditions the load limit setpoi nt will be set so that the transient is handled by control valves, bypass valves, and both. The regulators will be tested by simulating a failure of a selected pressure regulator so that the other regulator will take over control. The response of the system will be measured and evaluated and regulator settings will be optimized.
14.2.12.3.22.4 Criteria. Level 1 The transient response of any pre ssure control system related variable to an y test input must not diverge.
Level 2 a. Pressure control system variables may c ontain oscillatory modes of response. In these cases, the decay ratio for each controlled m ode of response must be less than or equal to 0.25, b. The pressure response time from initia tion of pressure set point change to the turbine inlet pressure peak shall be 10 sec,
- c. Pressure contro l system deadband, delay, etc., shall be small enough that steady-state limit cycles (if any) shall produce steam flow variations no larger than 0.5% of rated steam flow,
- d. For all pressure regulator transients the peak neutron flux and/or peak vessel pressure shall remain belo w the scram settings by 7.5% and 10 psi respectively (maintain a plot of power versus the pe ak variable values along the 100% rod line), and
- e. The variation in increm ental regulation (ratio of the maximum to the minimum valve of the quantity, "increment al change in pr essure control signal/incremental change in steam flow," for each flow range) shall meet the following:
C OLUMBIA G ENERATING S TATION Amendment 57 F INAL S AFETY A NALYSIS R EPORT December 2003 14.2-98 Steam Flow Obtained With Valves Wide Open (%)
Variation 0 to 90 4:1 90 to 97 2:1 90 to 99 5:1 Level 3 a. Additional dynamics of the control syst em, outside of the regulator compensation filters, shall be equivalent to a time const ant no greater than 0.10 sec. This also includes any dead time which may exist, b. Control or bypass valve motion must respond to pressure inputs with deadband (insensitivity) no greater than 0.1 psi, and
- c. Dynamics of both pressure regulators will be essentially identical.
14.2.12.3.23 Test Number 23 - Feedwater System
14.2.12.3.23.1 23A - Water Level Setpoint and Man ual Flow Changes. 14.2.12.3.23.1.1 Purpose. The purpose of this test is to verify that the feedwater system has been adjusted to provide acceptable reactor water level control.
14.2.12.3.23.1.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.23.1.3 Description. Reactor water level setpoint changes of approximately 3 in. to 6 in. (8 cm to 15 cm) will be used to evaluat e (and adjust if necessary) the feedwater control system settings for all power and feedwater pump modes. The level setpoint changes will also demonstrate core stability to subcooling changes.
14.2.12.3.23.1.4 Criteria. Level 1 The transient response of any leve l control system-related variable to any test must not diverge.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-99 Level 2 a. Level control system-related variables may contain oscillatory modes of response. In these cases, the decay ratio for each controlled mode of response must be less than or equal to 0.25;
- b. The open loop dynamic flow response of each feedwater actuator (turbine or valve) to small (<10%) step disturbances shall be
- 1. Maximum time to 10% of a step disturbance 1.1 sec 2. Maximum time from 10% to 90% of a 1.9 sec step disturbance
- 3. Peak overshoot (% of step disturbance) 15%
- 4. Settling time, 100%, 5% 14 sec c. The average rate of response of the feedwater actuator to large (>20% of pump flow) step disturbances shall be be tween 10% and 25% rated feedwater flow/sec. This average re sponse rate will be assessed by determining the time required to pass linearly through the 10% and 90% respon se points; and
- d. At steady-state generation for the 3/1 element system , the input scaling to be mismatch gain should be adjusted such that level error due to biased mismatch gain output should be within 1 in. Level 3 a. The dynamic response of each individual level or flow sensor shall be as fast as possible. Band width must be at leas t 4.0 radians/sec (f aster than 0.25 sec equivalent time constant), except for the steam flow sensors which must have band width of at least 1.
0 radian/sec (faster than 1.0 sec equivalent time constant);
- b. Vessel level, feedwater flow, and steam flow sensors must be installed with sufficiently short lines and proper damping adjustment so that no resonances exist;
- c. Initial settings of the function genera tors should give a straight line. The function generators must be adjusted so that the change in slope (actual fluid flow change divided by dem and change for small dist urbances) shall not exceed a factor of 2 to 1 (maximum slope versu s minimum slope) over the entire 20% to C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-100 100% feed flow range. Also the function generators should be used to minimize the differences between f eedwater actuators (pumps and/or valves); and
- d. All auxiliary controls which have direct impact on reactor level and feedwater control (e.g., feed pump minimum recirc ulation flow valve control) should be functional, responsive, and st able. The minimum low valve control should be fast enough to avoid pump trips and yet sl ower than the feedwater startup valve to avoid possible reactor flux scram due to a cold water slug.
14.2.12.3.23.2 23B - Loss of Feedwater Heating 14.2.12.3.23.2.1 Purpose. The purpose of this test is to demonstrate adequate response to a feedwater temperature loss.
14.2.12.3.23.2.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.23.2.3 Description. The condensate/feedwater system will be studied to determine the single failure that will cause th e largest loss in feed water heating. This event will then be performed at between 80% and 90
% power with the recirculation flow near its rated value.
14.2.12.3.23.2.4 Criteria. Level 1 a. For the feedwater heater loss test, the maximum feedwater temperature decrease due to a single failure case must be 100 F. The resultant MCPR must be greater than the fuel th ermal safety limit; and
- b. The increase in simulated heat flux cannot exceed the predicted Level 2 value by more than 2%. The predicted value will be based on the actual test values of feedwater temperature change and power level.
Level 2 The increase in simulated heat flux cannot exceed the predicted value in the Transient Safety Analysis Design Report referenced to the ac tual feedwater temper ature change and power level.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-101 14.2.12.3.23.3 22C - Feedwater Pump Trip. 14.2.12.3.23.3.1 Purpose. The purpose of this test is to demonstrate the capability of the automatic core flow runback feature to prevent lo w water level scram follo wing the trip of one feedwater pump.
14.2.12.3.23.3.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.23.3.3 Description. One of the two operating feed water pumps will be tripped and the automatic recirculation runba ck circuit will act to drop the pow er to within the capacity of the remaining feedwater pump.
Prior to the test a simulation of the feed water pump trip will be done to verify the runback capability of the recirculation sy stem. This test should be performed after test 23D (limiting pump speeds).
14.2.12.3.23.3.4 Criteria. Level 1 Not applicable.
Level 2 The reactor shall avoid low wate r level scram by a 3-in. marg in from an initial water level halfway between the high- and low-level alarm setpoints.
14.2.12.3.23.4 23D - Maximu m Feedwater Runout Capability. 14.2.12.3.23.4.1 Purpose. This test calibrates the feedwater flow and determines if the maximum feedwater runout capability is compatible with the licensing.
14.2.12.3.23.4.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.23.4.3 Description. The test is divided into two parts: first, the initial calibration of the speed controller and second, verification of calibration by measured data which includes a verification that the maximum feedwater flows do not exceed the flows (different flows at different vessel pressures) in the FSAR.
- a. The speed controller calibration is done by first obtai ning vendor pump performance curves. The pump performance curves are then used to determine C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-102 the turbine speed corresponding to th e maximum allowable flow rated vessel pressure specified by the FSAR and the minimum speed that corresponds to 0%
flow at 865 psia. Additionally, for good level control system performance it should reach 115% nuclear boiler rated (NBR) flow at 1080 psia and 90% NBR flow at 1024 psi in the one pump tripped condition. Adjustable equipment (i.e., feed pump turbine speed loops, mec hanical limiters, and feedwater control system function generator, etc.) are set to prevent the feedwater pumps from exceeding their maximum allowed out put and yet allow the desirable performance; and
- b. During the data collection and verifica tion of calibration portion of the test, pressure, flow, and controlle r data will be collected between 60%-100% power.
Measured data will be compared against expected values to ensure proper calibration. The measured maximu m flow will be adjusted to the FSAR pressures using the measured data. The maximum flows stated in the FSAR are used as licensing assumptions; therefor e, the FSAR maximum flows should not be exceeded. If, however, the FSAR ma ximum flows are ex ceeded two options exist. The system can be adjusted so that the licensing assumption is not exceeded or an additional penalty can be applied to the CPR. The CPR can be revised by applying a 0.01 adder for each 5% of rated feedwater flow difference (between the determined actual maximum flow and the FSAR maximum flow).
14.2.12.3.23.4.4 Criteria. Level 1 Maximum speed attained shall not exceed the speeds which will give the following flows with the normal complement of pumps operating.
- a. F% NBR at P psia, and
- b. [F% + A(P-P rated)] % NBR at P rated, psig where: F = 135%, P = 107 5 psia, A = 0.2%/psig.
Level 2 The maximum speed must be greater than th e calculated speeds required to supply:
- a. With rated complement of pumps -115% NBR at 1075 psi, and b. One feedwater pump tripped c ondition -68% NBR at 1025 psia.
NOTE: Level 1 test criteria are originated from NSSS transient Performance Engineering Unit. Level 2 test criter ia are originated from the Control System Design Unit.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-103 14.2.12.3.24 Test Number 24 - Turbine Valve Surveillance 14.2.12.3.24.1 Purpose. The purpose of this test is to demonstrate the acceptable procedures and maximum power levels for re commended periodic surveillance testing of the main turbine, control, and stop and bypa ss valves without produc ing a reactor scram.
14.2.12.3.24.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.24.3 Description. Individual main turbine cont rol and stop and bypass valves are tested routinely during plant opera tion as required for turbine surveillance testing. At several test points the response of the reactor will be observed. It is reco mmended that the maximum possible power level for perform ance of these tests along the 100%
load line be established.
First, actuation should be between 45% and 65% pow er and used to extrapolate to the next test point between 75% and 90% powe r and ultimately to the maximu m power test condition with ample margin to scram. Note the prox imity to APRM flow bias scram point and preconditioning cladding interim operating manag ement recommendation (PCIOMR) envelope.
Each valve test will be manua lly initiated and reset. The rate of valve stroking and timing of the close-open sequence will be such that the minimum practical disturbance is introduced and that PCIOMR limits are not exceeded.
14.2.12.3.24.4 Criteria. Level 1 Not applicable.
Level 2 a. Peak neutron flux must be at least 7.5% below the scram trip setting. Peak vessel pressure must remain at leas t 10 psi below the high pressure scram setting. Peak heat flux mu st remain at least 5.0%
below its scram trip point; and b. Peak steam flow in each line must remain 10% below the high flow isolation trip setting.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-104 14.2.12.3.25 Test Number 25 -
Main Steam Isolation Valves 14.2.12.3.25.1 25A - Main Steam Isolation Valve Function Tests. 14.2.12.3.25.1.1 Purpose. The purposes of this test are to (a) functionally check the MSIVs for proper operation at selected power levels, (b) determine isol ation valve closure times, and (c) determine a maximum power at which full cl osures of a single va lve can be performed without a scram.
14.2.12.3.25.1.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.25.1.3 Description. At 5% and greater reactor power levels, individual fast closure of each MSIV will be performed to verify their functional performance and to determine closure times. The times to be determ ined are (a) the time from de energizing the solenoids until the valve is 100% closed (t sol), and (b) the val ve stroke time (t s) Time t sol equals the interval from deenergizing the solenoids until th e valve reaches 90% closed plus 1/8 times the interval from 10% to 90% closure. Time t s equals the interval from when th e valve starts to move until it is 100% closed and is based on th e interval from 10% to 90%
closure and linear valve travel from 0% to 100% closure.
To determine the maximum power level at whic h full individual closur es can be performed without a scram, first actuation will be perf ormed between 40% to 55% power and used to extrapolate to the next test point between 60% and 85% power and ultimately to the maximum power test condition with ample margin to scram.
14.2.12.3.25.1.4 Criteria. Level 1 The MSIV stroke time (t s) shall be not faster than 3.0 sec (average of the fastest valve in each steam line) and for any individual valve 2.5 sec t s5 sec. Total effective closure time for any individual MSIV shall be t sol plus the maximum instrumentati on delay time as determined in preoperational test GE-4 and shall be 5.5 sec. Level 2 a. The reactor shall not scram or isolate, and
- b. During full closure of individual valves , peak valve pressure must be 10 psi (0.7 kg/cm
- 2) below scram, peak neutron flux must be 7.5% below scram, and C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-105 steam flow in individual lines must be 10%
below the isolation trip setting. The peak heat flux must be 5% less than its trip point.
14.2.12.3.25.2 25B -
Full Reactor Isolation. 14.2.12.3.25.2.1 Purpose. The purpose of this test is to determine the reactor transient behavior that results from the simultaneous full closure of all MSIVs.
14.2.12.3.25.2.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.25.2.3 Description. A test of the simultaneous fu ll closure of all MSIVs will be performed at >75% of rated th ermal power. Correct perform ance of the RCIC and relief valves will be shown. Reactor process variables will be monitored to determine the transient behavior of the system during and following the main steam line isolation.
14.2.12.3.25.2.4 Criteria. Level 1 a. Reactor must scram to limit the severity of the neutron flux and simulated fuel surface heat flux transient, b. Feedwater system settings must prevent flooding of the steam lines,
- c. The recorded MSIV full closure times must meet th e previously stated timing specifications (test 25A), and
- d. The positive change in vessel dome pr essure occurring within 30 sec after closure of all MSIV valves must not exc eed the Level 2 crit eria by more than 25 psi. The positive change in simulated heat flux shall not exceed the Level 2 criteria by more than 2% of rated value.
Level 2 a. The temperature measured by the ther mocouples on the discharge side of the SRVs must return to within 10F of the temperature reco rded before the valve was opened. If pressure sensors are ava ilable, they shall retu rn to their initial state upon valve closure;
- b. For the full MSIV closure from full po wer predicted analytical results based on beginning-of-cycle design basis analysis, assuming no equipment failures and C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-106 applying appropriate parametric corrections, will be used as the basis to which the actual transient is compared.
- c. Initial action of RCIC and HPCS shall be automatic if low water level (L2) is reached, and system performance shall be within sp ecification, and
- d. Recirculation pump trip shall be initiated if low water level (L2) is reached.
Recirculation pump power will shift to the LFMGs if low water level (L3) is reached. 14.2.12.3.26 Test Number 26 - Relief Valves
14.2.12.3.26.1 Purpose. The purposes of this test are to (a) verify the prope r operation of the main system relief valves, (b) verify that the discharge piping is not blocked, (c) verify their proper seating following operation, (d) obtain signature information of relief valve response for subsequent comparisons, and (e) determine their capacities.
14.2.12.3.26.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.26.3 Description. The main steam relief valves will each be opened using the "manual" control mode so that at any time only one is open. Duri ng heatup at 250 psig (17.5 kg/cm 2), each valve will be opened and closed to demonstrate proper functioning. Flow verification of each relief valve will be determined at rate pressure by observing bypass or control valve motion and by observing a change in discharge th ermocouple readings. Proper reseating of each relief valve will be verified by observation of temperatures in the relief valve discharge piping. At selected test conditions each valve w ill be manually actuated and appropriate system parameters recorded during the transient. Data analysis will include a comparison of the system response during each of the valve actuati ons. Capacity of each relief valve will be determined at rate d pressure by the amount of bypass or control valve closure required to maintain reactor pressure.
14.2.12.3.26.4 Criteria. Level 1 There should be positive indication of steam di scharge during the manual actuation of each valve.
The sum of capacity measurements from all relief valves shal l be equal to or greater than 15.8 x 10 6 lb/hr at an inlet pressure of 103% at 1205 psig. The tota l flow capacity of the SRVs used in the automatic depressurization system must be equal to or greater than 4.8 x 10 6 lb/hr C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-107 at 1125 psig when the valve having the highest measured capacity is a ssumed to be out of service.
Level 2 Relief valve leakage shall be lo w enough that the temperature me asured by the thermocouples in the discharge side of the valves returns to within 10F (5.6C) of the temperature recorded before the valve was opened. The thermocouples are expected to be operating properly.
The pressure regulator must sa tisfactorily control the reactor transient and close the control valves or bypass valves by an amount equivalent to the relief valve discharge. The valve transients recorder signatures for each valve must be returned to GE in San Jose for relative system response comparison.
Each relief valve sha ll have a capacity between 90% a nd 122.5% of its expected value corrected to an inlet pressu re of 103% at 1205 psig.
No more than 25% of the relie f valves may have an individual corrected flow rate that is between 90% and 100% of thei r expected flow rates.
The transient recorder signatures for each valve must be analy zed for relative system response comparison.
14.2.12.3.27 Test Number 27 - Turbin e Trip and Generator Load Rejection
14.2.12.3.27.1 Purpose. The purpose of this test is to de monstrate the respons e of the reactor and its control systems to protective trips in the turb ine and generator.
14.2.12.3.27.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiation of testing. All controls and interlocks are checked and instrumentation calibrated.
The plant electrical system will be aligned in the normal mode for the operating condition at which th e test is performed.
14.2.12.3.27.3 Description. Turbine trip (closure of the main turbine stop valves within 0.1 sec) and generator trip (closu re of the main turbine contro l valves in about 0.1 sec to 0.2 sec) will be perfor med at selected power le vels during the startup test program. At low power levels, reactor protection following the trip is provided by high neutron flux and vessel high pressure scram. For the protective trip s occurring at intermediate and higher power levels, reactor will scram by relays, actuated by control or stop valve motion.
A generator trip will be performed at low power level such that nuclear boiler steam generation is just within the bypa ss valve capacity to dem onstrate scram avoidance.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-108 For the trips performed at inte rmediate power range, reactor scram is most important in controlling the tr ansient peaks.
Above 40% power, the recircula tion pump circuit breakers are bot h automatically tripped, and subsequent transient pressure rise will be limited by the opening of the bypass valves initially and the SRVs if necessary.
14.2.12.3.27.4 Criteria. Level 1 a. For turbine and generator trips at power levels greater than 50% NBR, there should be a delay of less t han 0.1 sec following the begi nning of control or stop valve closure before the beginning of bypass valve ope ning. The bypass valves should be opened to a point corresponding to greater than or equal to 80% of their capacity within 0.3 sec from the be ginning of control or stop valve closure motion; b. Feedwater system settings must prevent flooding of the steam line following these transients;
- c. The two pump drive flow coastdown tr ansient during the first 6 sec must be equal to or faster than that specified in test 30B (see Figure 14.2-6
);
- d. The positive change in vesse l dome pressure occurring w ithin 30 sec after either generator or turbine trip must not ex ceed the Level 2 criteria by more than 25 psi;
- e. The positive change in simulated heat flux shall not exceed the Level 2 criteria by more than 2% of the rated value; and
- f. The total time delay from start of tu rbine stop valve motion or control valve motion to the complete s uppression of electrical ar c between the fully open contacts of the recirculation pump trip (RPT) circuit breakers shall be less than 190 msec.
Level 2 a. There shall be no MSIV closure during the first 3 mi nutes of the transient, and operator action shall not be required during that period to avoid the MSIV trip. (The operator may take action after the first 3 minutes, including switching out of run mode. The operator may also switch out of run mode in the first C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-109 3 minutes if measured data confirms that his acti on did not prevent MSIV closure);
- b. The positive change in ves sel dome pressure and in si mulated heat flux which occurs within the first 30 sec after the in itiation of either generator or turbine trip must not exceed the pr edicted values. [Predicted values will be referenced to actual test conditions of initial power life and dome pressure and will use beginning of life (BOL) nuclear data. Worst case design or Technical Specification values of all hardware perfor mance shall be used in the prediction with the exception of control rod insertion time and the dela y from beginning of turbine control valve or st op valve motion to the generation of the scram signal. The predicted pressure and heat flux will be corrected for the actual measured values of these two parameters];
- c. For the generator grip within the bypass valves capacity, the reac tor shall not scram for initial thermal power values within that bypass valve capacity;
- d. The measured bypass capac ity (in percent of rated power) shall be equal or greater than that used for the FSAR analysis (3,576,000 lb/hr);
- e. Recirculation LFMG sets shall take over after the initia l recirculation pump trips and adequate vessel temp erature difference shall be maintained;
- f. Feedwater level control shall avoid loss of feedwater due to possible high level (L8) trip during the event;
- h. The temperature measured by thermocouples on the di scharge side of the SRVs must return to within 10F of the temperature recorded before the valve was opened. In addition the acous tical monitors should indicate the valve is closed after the transien t is complete.
14.2.12.3.28 Test Number 28 - Shutdown From Outside the Ma in Control Room
14.2.12.3.28.1 Purpose. The purpose of this test is to demonstrate that th e reactor can be brought down from a normal initia l steady-state power level to the point where cooldown is established and under control with reactor vessel pressure and water level controlled from outside the control room.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-110 14.2.12.3.28.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.28.3 Description. The test will be performed at a low power level and will consist of demonstrating the capability to control reactor level and pressu re from outside the control room. The reactor will be scra mmed and isolated from the cont rol room. Reactor pressure and water level will be controlled using SRVs, RCIC, and RHR from outside the control room during the subsequent c ooldown. In addition, the RHR shut down cooling mode will be placed in service from outside the control room. All other operator actions not directly related to maintaining vessel water level and pressure will be performed in the main control room.
Operation from the main control room to protect or secure systems not re lated to the controlled cooldown of the reactor is perm itted during this test. These actions are recorded and later evaluated to determine if th ey had bearing on the transient.
14.2.12.3.28.4 Criteria. Level 1 Not applicable.
Level 2 During a simulated main control room evacuation, the reactor must be brought to the point where cooldown can be initiated, and the reactor vessel pressure and water level must be controlled using equipment and controls outside the main control room.
14.2.12.3.29 Test Number 29 - Recirculation Flow Control
14.2.12.3.29.1 29A - Valve Position Control. 14.2.12.3.29.1.1 Purpose. The purpose of this test is to demonstrate the recirculation flow control systems capability while in the valve position (POS) mode.
14.2.12.3.29.1.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiation of testing. All controls are checked and in strumentation calibrated.
14.2.12.3.29.1.3 Description. The testing of the recirculation flow control system follows a "building block" approach while the plant is ascending from low to high power levels: Components and inner control loops are tested first, followed by dri ve flow control and plant power maneuvers to adjust and th en demonstrate the outer l oop controller performance. Preliminary component and valve position loop tests will be run wh en the plant is in cold C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-111 shutdown to visually observe th e hydraulic cylinder response. While operating at low power with the pumps using the low frequency power s upply, small step changes will input into the position controller and th e response recorded.
14.2.12.3.29.1.4 Criteria. Level 1 The transient response of any reci rculation system related variables to any test input must not diverge.
Level 2 a. Recirculation system related variabl es may contain oscillatory modes of response. In these cases, the decay ratio for each controlled mode of response must be less than or equal to 0.25, b. Maximum rate of change of valve position shall be 10 1% sec. During TC-3 and TC-6 while operating on the high speed (60 Hz) source, gains and limiters shall be set to obtain the following response, c. Delay time for position demand step shall be
For step inputs of 0.5% to 5% 0.15 sec.
For step inputs of 0.2% to 0.5%-
- d. Response time for positi on demand step shall be For step inputs of 0.5% to 5% 0.45 sec.
For step inputs of 0.2% to 0.5%-, and
- e. Overshoot after a small position demand in put (1% to 5%) step shall be 10% of magnitude of input.
Level 3 a. Gains shall be set to give as fast a response as possi ble for small position demand input within the overshoot cr iterion (e) and without additional valve duty cycle. (See t e st 2 9 B, Section 14.2.12.3.29.2 , for valve duty cycle measurement.)
- b. Position loop dead band shall be 0.2% of full valve stroke.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-112 NOTE: At a minimum, performing tests near the high and low end of the specified range is acceptable for verifying step input response.
14.2.12.3.29.2 29B - Recirc ulation Flow Loop Control. 14.2.12.3.29.2.1 Purpose. The purposes of this test are to (a) demonstrate the core flow system's control capability over the entire flow control range, in cluding both core flow neutron flux and load following modes of op eration, and (b) determine t hat all electrica l compensators and controllers are set for desired system performance and stability.
14.2.12.3.29.2.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the test procedures and initiation of testing. All controls are checked and in strumentation calibrated.
14.2.12.3.29.2.3 Description. Following the initial position mode tests of 29A the final adjustment of the position loop gains, flow loop gains, and preliminary valves of the flux loop adjustments will be made on the mid-power line.
This will be the most ex tensive testing of the recirculation control system. Th e core power distribution will be adjusted by control rods to permit broader range of maneuverab ility with respect to PCIOMR. In general, the controller dials and gains will be raised to meet the maneuvering performance objectives. Thus, the system will be set to be the sl owest that will perform satisfactorily to maximize stability margins and to minimize equipmen t wear by avoiding co ntroller overactivity.
Because of PCIOMR power m aneuvering rate restrictions , the fast flow maneuvering adjustments are performed along a mid-power rod line, and extr apolation made to the expected results along the 100% rod line. The utility has the option to decide to
- a. Perform the faster power changes on the 100% rod line that are greater than what the PCIOMR allow, or
- b. To accept the mid-power load line demonstrations as acceptable proof of maneuverability.
For immediate commercial operati on, the flux loop will be set slower and the operator will limit manual mode maneuvers. If PCIOMRs are ever withdrawn, the tested faster auto settings can be inserted onto the controller with only a brief dynamic test, rath er than a full startup test.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-113 14.2.12.3.29.2.4 Criteria. Level 1 The transient response of any reci rculation system related variabl e to any test input must not diverge.
Level 2 a. The decay ratio of the flow loop res ponse to any test inputs shall be <0.25, b. The flow loops provide equal flows in the two loops during steady-state operation. Flow loop gains should be se t to correct a flow imbalance in less than 25 sec, c. The delay time fo r flow demand step ( 5%) shall be 0.4 sec or less,
- d. The response time for flow demand step ( 5%) shall be 1.1 sec or less, e. The maximum allowable flow over shoot for step demand of 5% of rated shall be 6% of the demand step, and
- f. The flow demand step settling time shall be 6 sec. Level 3 a. Incremental gain from function generator for valve position demand input to sensed drive flow shall not vary by more than 2 to 1 over the entire flow range, and b. Flow loop upper limit should be checked for proper setting.
Flux Loop Criteria Level 1 The flux loop response to test inputs shall not diverge.
Level 2 a. Flux over shoot to a flux demand step shall not exceed 2% of rated for a step demand of 20% of rated, C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-114 b. The delay time for flux respons e to a flux demand step shall be 0.8 sec, c. The response time for flux demand stop shall be 2.5 sec, and
- d. The flux setting time shall be 15 sec for a flux demand step 20% of rated.
Scram Avoidance and General Criteria Level 1 Not applicable.
Level 2 For any one of the above loops test maneuvers, the trip avoidance margins must be at least the following:
- a. For APRM 7.5%, and b. For simulated heat flux 5.0%.
Flux Estimator Test Criteria Level 1 Not applicable.
Level 2 a. Switching between estimated and sensed flux should not exceed 5 times/5 minutes at steady state, and
- b. During flux step transient there should be no switching to sensed flux or if switching does occur, it should switch back to estimated flux with in 20 sec of the transient.
Flux Control Valve Duty Test Criteria Level 1 Not applicable.
C OLUMBIA G ENERATING S TATION Amendment 55 F INAL S AFETY A NALYSIS R EPORT May 2001 LDC N-0 1-0 0 0 14.2-115 Level 2 The flow control valve duty cycle in any opera ting mode shall not exceed 0.2% Hz. Flow control valve duty cycle is defined as Integrated valve movement in percent (%Hz)2x time span in seconds 14.2.12.3.30 Test Number 30 - Recirculation System
14.2.12.3.30.1 30A - One Pump Trip. 14.2.12.3.30.1.1 Purpose. The purposes of this test are to (a) obtain recirculation system performance data during the pump trip, flow coastdown, and pump restart, and (b) verify that the feedwater control system c an satisfactorily control water level without a resulting turbine trip/scram.
14.2.12.3.30.1.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.30.1.3 Description. The reactor coolant recirculation system consists of the reactor vessel and two piping loops. Each loop contains a constant speed centrifugal recirculation pump, a flow control valve and two isolation valves located in the drywell, and 10 jet pumps in parallel, situated in the reactor downcomer and discharges through a manifold system to the nozzles of the 10 jet pumps. Here the flow is augmented by suction flow from the downcomer and delivered to the re actor inlet plenum.
A potential threat to plant availability is the hi gh water level turbine trip scram caused by the level upswell that results after an unexpected recirculation one pum p trip. The change in core flow and the resultant power decrease causes vo id formation which the level sensing system senses as a rise in water level. The one-pump tr ip tests are to prove that the water level will not rise enough to threaten a high level trip of the main tu rbine or the feedwater pumps.
14.2.12.3.30.1.4 Criteria. Level 1 The reactor shall not scram during the one-pump trip recovery.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-116 Level 2 The reactor water level margin to avoid a high level trip shall be 3.0 in. during the one-pump trip.
NOTE: Margin to trip is defined as Margin (high level trip <8 setpoint) - (maximum water level reached ruing test) - (high level alarm <7 setpoint - initial water level)
a The simulated heat flux margin to avoid a scram shall be 5.0% during the one-pump trip and also during the recovery, and
14.2.12.3.30.2 30B - Recirc ulation Trip of Two Pumps. 14.2.12.3.30.2.1 Purpose. The purpose of the test is to record and verify acceptable performance of the recirculation two pump circuit trip system.
14.2.12.3.30.2.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.30.2.3 Description. In case of higher power turbine or generator trips, there is an automatic opening of circuit brea kers in the pump power supply.
The result is a fast core flow coastdown that helps reduce peak neutron and heat flow in such events. This two-pump trip test verifies that this flow coastdown is satisfactory prior to the high power turbine/generator trip tests and subsequent operation.
14.2.12.3.30.2.4 Criteria. Level 1 The two-pump-drive flow coastdown transient during the first 6 sec must be bounded by the limiting curves. (See Figure 14.2-6
.)
(The limiting curves will be determined based on measurement of the recirculation flow delta P using the elbow flow meters, transm itter time delay, and time constant.)
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-117 Level 2 Not applicable.
14.2.12.3.30.3 30C - System Performance. 14.2.12.3.30.3.1 Purpose. The purpose of this test is to record recirculation system parameters during the power test program.
14.2.12.3.30.3.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.30.3.3 Description. Recirculation system parameters will be recorded at several power-flow conditions and in conjunction with single pump trip recoveries and internals vibration testing (if applicable).
14.2.12.3.30.3.4 Criteria. Level 1 Not applicable.
Level 2 a. The core flow shortfall shall not exceed 5% at rated power,* b. The measured core delta P s hall not be 70.6 psi above prediction,*
- c. The calculated jet pump M ration s hall not be 0.2 points below prediction,*
- d. The drive flow shortfall shall not exceed 5% at rated power,*
- e. The measured recircula tion pump efficiency shall not be 78% points below the vendor tested efficiency, and
- f. The nozzle and riser plugging criteria shall not be exceeded.
- The GE Steam Generation System Design Unit will provide pred ictions for the comparisons for these criteria.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-118 14.2.12.3.30.4 30D - Recirculation Pump Runback. 14.2.12.3.30.4.1 Purpose. The purpose of this test is to verify the adequacy of the recirculation runback to mitigate a sc ram on the loss of one feedwater pump.
14.2.12.3.30.4.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.30.4.3 Description. While operating at near rated recirculation flow, a loss of a feedwater pump will be simulated. The transient and final condition will be studied to determine the adequacy of the system in preventing a scram during the scheduled loss of a single feedwater pump test (test 23C).
14.2.12.3.30.4.4 Criteria. Level 1 Not applicable.
Level 2 The recirculation flow control valves shall runback on a trip of the runback circuit.
14.2.12.3.30.5 30E - Recirc ulation System Cavitation. 14.2.12.3.30.5.1 Purpose. The purpose of this test is to verify that no reci rculation system cavitation will occur in the operable region of the power-flow map.
14.2.12.3.30.5.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.30.5.3 Description. Both the jet pumps and the reci rculation pumps will cavitate at conditions of high flow and low power where NPSH demands are high and little feedwater subcooling occurs. However, the recirculation flow will autom atically run back on sensing a decrease in subcooling (as measured by the difference between the steam and recirculation loop temperature), to lower the reactor power.
The maximum recirculation flow is limited by approximate stops which will run back the recirculation flow away from the possible cavitation region. It will be verified that these limits are sufficient to prevent operation where recirculation pump or jet pump cav itation is predicted to occur.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-119 The recirculation system flow c ontrol valves will cavitate at conditions of high differential pressure and low power (low subcooling). The recirculation flow will automatically run back on sensing a decrease in subcooli ng (as measured by a low feedwater flow). This limit will be verified to ensure that operation is prevented where flow control valve cavitation may occur.
In both the above cases, flow runback is caused by a shift in the power supply to the recirculation pump motors from normal power to the LFMGs.
14.2.12.3.30.5.4 Criteria. Level 1 Not applicable.
Level 2 Runback logic shall have settings adequate to prevent operation in areas of potential cavitation.
14.2.12.3.31 Test Number 31 - Loss of Turbine-Generator and Offsite Power
14.2.12.3.31.1 Purpose. This test determines electri cal equipment and reactor system transient performance duri ng a loss of auxiliary power.
14.2.12.3.31.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
The plant electrical system will be aligned in the normal mode for the operating condition at which th e test is performed.
14.2.12.3.31.3 Description. The loss of auxiliary power test will be performed at 20% to 30% of rated power. The proper response of reactor plant equipment, automatic switching equipment, and the proper sequencing of the diesel generator load will be verified.
Appropriate reactor parameters will be recorded during the resultant transient.
14.2.12.3.31.4 Criteria. Level 1 a. Reactor protection system actions shall prevent viola tion of fuel thermal limits.
- b. All safety systems, such as the RPS , the diesel generators, and HPCS must function properly without manual assistance. The HPCS and/or RCIC system action, if necessary, shall keep the reactor water level above the initiation level C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-120 of the LPCS, LPCI, automatic depressu rization systems, and MSIV closure. Diesel generators shall start automatica lly and when they reach rated frequency and voltage the diesel breakers will clos e and restore power to the engineered safety features (ESF) buses.
Level 2 a. Proper instrument display to the re actor operator shall be demonstrated, including power monitors, pressure, water level, control rod position, suppression pool temper ature, and reactor cooling syst em status. Displays shall not be dependent on specially in stalled instrumentation, and
- b. If SRVs open, the temper ature measured by thermoc ouples on the discharge side of the SRVs must re turn to within 10F of the temperature recorded before the valve was opened. If pressure sensors ar e available, they sha ll return to their initial state on valve closure.
14.2.12.3.32 Not Applicable
14.2.12.3.33 Test Number 33 - Piping Vibration
14.2.12.3.33.1 Purpose. The purpose of this test is to veri fy that the design stress levels due to piping vibration are not exceeded and satisfy the inspection requirements for condensate and feedwater systems according to Regulatory Guide 1.68.1.
14.2.12.3.33.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been installed and calibrated.
14.2.12.3.33.3 Description. This test is an extension of te st 17 and has been procedurally combined with the system expansion test. During reactor operation, it is desirable to show that destructive level piping vibrations do not o ccur during steady-state conditions and during planned transients. Acceptable vibration levels are verified by measurement (using the same sensors used in test 17) and by visual observation during system walkdowns for selected piping systems outside containment. See Section 14.2.12.3.17.2 for systems selected and selection criteria.
14.2.12.3.33.4 Criteria. Level 1 The measured vibration amplitude (peak-to-peak) of the systems monitored shall not exceed the maximum allowable displacements.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-121 Level 2 The measured amplitude (peak-to-peak) of vibration shall not exceed the expected values.
Visual Inspection Acceptance Criteria The vibration levels experienced will be evaluated as acceptable if they are too small to be detected by the naked eye with consideration given to the following:
- a. Proximity to sensitive equipment (pumps, valves, mo tor control centers, control panels, etc.),
- b. Branch connection behavior, and
- c. Performance of near by component supports.
If an acceptable assessment of the observed de flections cannot be pe rformed and corrective measures are not available, the inspector will then obtain the magnitude and frequency of the vibration using a por table vibration instrument. The inform ation will then be evaluated by the piping design engineer to verify acceptance. Unacceptable vibration levels will be treated as a Level 1 violation.
14.2.12.3.34 Test Number 34 - Reactor Pressure Vessel Internals Vibration
14.2.12.3.34.1 Purpose. The purpose of this test is to pr ovide information n eeded to confirm the similarity between the reactor internal s design and the prototype with respect to flow-induced vibration. Testing is in response to Regulatory Guide 1.20 for a vibration measurement program for nonprot otype, Category IV reactor in ternals, and the GE vibration test specification 22 A6601, Revision 0.
14.2.12.3.34.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.34.3 Description. During operation, the reactor structure may be forced into many modes of vibrations. Analytical work indica tes that unacceptable leve l vibrations will not occur.
Detailed descriptions of sensor locations ar e given in GE Test Specification 22A6601, Revision 0.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-122 Sensors used for the measurements are resistance wire strain gauges and accelerometers with double integrating output signal c onditioning. Sensors will be in stalled in a manner to sense the most probable mode of vibra tion as indicated by analysis.
The test program consists of at power tests performed with the system at normal operating pressure and temperature.
During the vibration test the vibration engin eer will monitor and record vibrating amplitudes and frequencies obtained from th e sensors mounted on the various components. The measured amplitudes and frequencies are then compared to the acceptance criteria to ensure that all measured vibration amplitudes are within acceptable levels.
14.2.12.3.34.4 Criteria. Level 1 The peak stress intensity ma y exceed 10,000 psi (single am plitude) when the component deformed in a manner corresponding to one of its normal or natural mo des, but the fatigue usage factor must not exceed 1.0.
Level 2 The peak stress intensity shall not exceed 10,000 psi (single amp litude) when the component is deformed in a manner corresponding to one of it s normal or natural modes. This is the low stress limit which is suitable for sustained vibration in the reac tor environment for the design life of the reactor components.
14.2.12.3.35 Test Number 35 - Reci rculation System Flow Calibration
14.2.12.3.35.1 Purpose. The purpose of this test is to perform complete calibration of the installed recirculation syst em flow instrumentation.
14.2.12.3.35.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.35.3 Description. During the testing program at operating conditions, which allow the recirculation system to be operated at rated flow at rated pow er, the jet pump flow instrumentation will be adjusted to provide correct flow indicati on based on the jet pump flow. After the relationship between drive flow and core flow is es tablished, the flow biased APRM/RBM system will be adjusted to match this relationship.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-123 14.2.12.3.35.4 Criteria. Level 1 Not applicable.
Level 2 Jet pump flow instrumentation shall be adjusted su ch that the jet pump total flow recorder will provide a correct core flow i ndication at rated conditions.
The APRM/RBM flow-bias instrumentation shall be adjusted to functi on properly at rated conditions.
The flow control system shall be adjusted to lim it maximum core flow to 102.5% of rated by limiting the flow control valve opening position.
14.2.12.3.36 Test Number 70 -
Reactor Water Cleanup System
14.2.12.3.36.1 Purpose. The purpose of this test is to demonstrate specific aspects of the mechanical operability of the RWCU system. (This test, performe d at rated reactor pressure and temperature, is actually the completion of the preoperational testing that could not be done without nuclear heating.)
14.2.12.3.36.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.36.3 Description. With the reactor at rated temperature and pressure, process variables will be recorded duri ng steady-state operation in th ree modes as defined by the system process diagram: hot shutdown with loss of RPV recirculation pumps, normal, and blowdown. A comparison of the bottom head flow indicator and the RWCU inlet flow indicator will be made. The RWCU system sample stati on shall be tested at hot process conditions.
14.2.12.3.36.4 Criteria. Level 1 Not applicable.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-124 Level 2 The temperature at the tube side outlet of the nonregenerative heat ex changers shall not exceed 130 F (54C) in the blowdown mode and shall not exceed 120F in the normal mode.
The pump available NPSH will be 13 ft or grea ter during the hot shutdown with loss of RPV recirculation pumps mode defin ed in the process diagrams.
The cooling water supplied to th e nonregenerative heat exchangers shall be less than 6% above the flow corresponding to the heat exchanger capacity (as determined from the process diagram) and the existing temper ature differential across the heat exc hangers. The outlet temperature shall not exceed 180 F.
Recalibrate bottom head flow indicator (R610) against RWCU flow indicator (R609) if the deviation is grea ter than 25 gpm.
Pump vibration shall be less than or equal to 2 mils peak-t o-peak (in any direction) as measured on the bearing housing and 2 mils peak-to-peak shaft vibrati on as measured on the coupling end.
14.2.12.3.37 Test Number 71 -
Residual Heat Removal System
14.2.12.3.37.1 Purpose. The purpose of this test is to demonstrate the ability of the RHR system to remove heat from the reactor syst em so that the refue ling and nuclear system servicing can be performed.
14.2.12.3.37.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.37.3 Description. During the first suitable reactor cooldown, the shutdown cooling mode of the RHR system will be demonstrated. Unfortunately, the decay heat load is insignificant during the startup te st period. Use of the mode with low core exposure could result in exceeding the 100 F/hr cooldown rate of the vessel if both RHR heat exchangers are used simultaneously. Late in the test program after accumula ting significant core exposure, this demonstration would mo re adequately demonstrate th e heat exchanger capacity.
14.2.12.3.37.4 Criteria. Level 1 Not applicable.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-125 Level 2 The RHR system shall be capable of operating in the suppression pool cooling and shutdown cooling modes (with each heat exchanger) at the flow rates and temper ature differentials determined by the flow rates and temperature differentials indi cated on the process diagrams.
14.2.12.3.38 Test Number 72 - Dryw ell Atmosphere Cooling System
14.2.12.3.38.1 Purpose. The purpose of this test is to verify the ability of the drywell atmosphere cooling system to maintain desi gn conditions in the dr ywell during operating conditions and post scram conditions.
14.2.12.3.38.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.38.3 Description. During heatup and power opera tion, data will be taken to ascertain that the drywell atmospheri c conditions are within design limits.
14.2.12.3.38.4 Criteria. Level 1 Not applicable.
Level 2 The drywell cooling system sha ll maintain drywell air temperat ures at or below the design values as specified fo r the NSSS equipment.
14.2.12.3.39 Test Number 73 - Cooling Water Systems
14.2.12.3.39.1 Purpose. The purpose of the test is to verify that the heat removal performance of the SW system, the reactor bu ilding RCC system, and the plant service water (TSW) system is adequate.
14.2.12.3.39.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.39.3 Description. The SW, the RCC, and the TSW systems heat exchanger heat transport capabilities will be verified.
Verification will be conduc ted in the following manner.
The system water flow rate thr ough each heat exchanger will be measured. The system water C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 14.2-126 temperature drop across each he at exchanger will also be meas ured. From these acquired water flow rates and temperature dr op data, the heat transport rates will be calculated. Where available, the calculated heat transport data will be compared directly with design calculations to determine acceptability. For those systems in which no design calculations of the heat transport rate have been directly calculated, the heat removal performance of the particular heat exchanger will be considered acceptable if the components serv iced by the cooling system exhibit proper operation. If prope r performance is not experien ced, adjustments in the heat transport capability (i.e., increa sed flow to the heat exchanger or increased flow to a particular load) would be made. In addition to the heat exchanger heat transport rate verification, the actual SW pump he ad will be determined for all three SW pumps. This actual SW pump head will be compared to the design requirements for acceptability.
14.2.12.3.39.4 Criteria. Level 1 Not applicable.
Level 2 The system heat transport parameters either meet the requirement s of the design specifications, or provide adequate cooling to the components se rviced such that they operate satisfactorily.
14.2.12.3.40 Test Number 74 - Offgas System
14.2.12.3.40.1 Purpose. The purposes of this test are to verify the proper operation of the offgas system over its expect ed operating parameters and to dete rmine the perfor mance of the activated carbon adsorbers.
14.2.12.3.40.2 Prerequisites. The preoperational tests have been completed, reviewed by POC, and the Plant Manager has approved the te st procedures and initi ation of testing.
Instrumentation has been checked or calibrated as appropriate.
14.2.12.3.40.3 Description. The pressure, temperature, relative humidity, system flow, and percentage of radioly tic hydrogen in the offgas are peri odically monitored during startup and at steady-state conditions. Prior to initial st eam flow to the main condenser, charcoal bed hold-up times will be measure experimentally using a pulsed Krypton-85 gas injection technique. The charcoal bed dynamic adsorpti on coefficient will then be determined by established analytical me thods. The performance of the cata lytic recombiner will be compared the catalytic recombiner guar anteed performance curve.
C OLUMBIA G ENERATING S TATION Amendment 54 F INAL S AFETY A NALYSIS R EPORT April 2000 LDC N-9 9-0 0 0 14.2-127 14.2.12.3.40.4 Criteria. Level 1 The release of radioactive gaseous and particulate effluents must not exceed the limits specified in the Technical Specifications. There shall be no loss of flow of dilution steam to the noncondensing stage when the stea m jet air ejectors are pumping.
Level 2 The system flow, pressure, temperature, and relative humidity shall comply with design specifications. The cata lytic recombiner, the hydrogen analyzer, the activ ated carbon bed, and the filters shall be performing their required function.
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1998 Table 14.2-1 Preoperational Tests Section Refe r e nce Title 14.2-129 14.2.12.1.1 Reactor Feedwater System 14.2.12.1.2 Condensate System 14.2.12.1.3 Fire Protection System 14.2.12.1.4 Reactor Water Cleanup System 14.2.12.1.5 Standby Liquid Control System 14.2.12.1.6 Nuclear Boiler System 14.2.12.1.7 Residual Heat Removal System 14.2.12.1.8 Reactor Core Isolation Cooling 14.2.12.1.9 Reactor Recirculation System and Control 14.2.12.1.10 Reactor Manual Control System 14.2.12.1.11 Control Rod Drive Hydraulic System 14.2.12.1.12 Fuel Handling and Vessel Servicing Equipment 14.2.12.1.13 Low Pressure Core Spray System 14.2.12.1.14 High Pressure Core Spray 14.2.12.1.15 Fuel Pool Cooling and Cleanup System 14.2.12.1.16 Leak Detection System 14.2.12.1.17 Liquid and Solid Radwaste System 14.2.12.1.18 Reactor Protection System 14.2.12.1.19 Neutron Monitoring System 14.2.12.1.20 Traversing In-Core Probe System 14.2.12.1.21 Rod Worth Minimizer System 14.2.12.1.22 Process Radiation Monitoring System 14.2.12.1.23 Area Radiation Monitoring System C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1 998 Table 14.2
-1 Preoperational Tests (Continued)
Section Reference Title 14.2-130 14.2.12.1.24 Process Computer Interface System 14.2.12.1.25 Rod Sequence Control System 14.2.12.1.26 Remote Shutdown 14.2.12.1.27 Offgas System 14.2.12.1.28 Environs Radiation Monitoring System 14.2.12.1.29 Main Steam System 14.2.12.1.30 Radwaste Building Hea t ing, Ve ntilation, and Air Conditioning System 14.2.12.1.31 Closed Cooling Water System 14.2.12.1.32 Primary Containment Atmospheric Control System 14.2.12.1.33 Primary Containment Cooling System 14.2.12.1.34 Primary Containment Instrument Air System 14.2.12.1.35 Primary Containment Atmospheric Monitoring System 14.2.12.1.36 Standby Gas Treatment System 14.2.12.1.37 Loss of Power and Safety Testing 14.2.12.1.38 Instrument Power System 14.2.12.1.39 Emergency Lighting 14.2.12.1.40 Standby Alternating Cu rrent Power System 14.2.12.1.41 250-V Direct Current Distribution System 14.2.12.1.42 125-V Direct Current Distribution System 14.2.12.1.43 24-V Direct Current Distribution System 14.2.12.1.44 Plant Service Water System 14.2.12.1.45 Standby Service Water System 14.2.12.1.46 Plant Communication System C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT November 1 998 Table 14.2
-1 Preoperational Tests (Continued)
Section Reference Title 14.2-131 14.2.12.1.47 Reactor Building Emergency Cooling System 14.2.12.1.48 Control Cable and Critical Switchgear Rooms Heating, Ventilation, and Air Conditioning System 14.2.12.1.49 Standby Service Water Pump House Heating and Ventilating System 14.2.12.1.50 Reactor Building Crane 14.2.12.1.51 Primary Containment Integr ated Leak Rate Test 14.2.12.1.52 Secondary Containment Integr ated Leak Rate Test 14.2.12.1.53 Diesel Generator Building He ating and Ventilating System
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-132 Table 14.2
-2 Major Plant Transients Test Condition Approxima te Power (% rated) 20-25 60-75 95-1 0 0 Test Title Approxima t e Core Flow
(% rated) 37 100 100 23C Feedwater p u mp trip X 23B Loss of feedwater heating X 25 MSIVs (all valves, full isolation)
X 27 T-G stop valve fast close X 27 T-G control valve fast close X X 28 Shutdown f r om outside control room X 30 Recirculation pu m p trips X X 31 Loss of generator and o f fsite power X Test condition 1, 2 3 6 C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-133 Table 14.2
-3 Stability Tests Test Condition Approxima te Power (% rated) 20 40 60-75 60-75 95-1 0 0 40-50 Test Title Approxima t e Core Flow (% rated) 37 50 100 55 100 NC 21 Core power - void mode response X X 22 Pressure regul ator setpoint changes X X X X X X 22 Pressure regulator backup regulator X X X X X X 23A Feedwater syst em: water level setpoint change X X X X X X 23B Feedwater s y s t em: h e ater loss X 24 Turbine valve survei l l ance X a X b 29 Recirculation flow control system X X X X X X Test condition 1 2 3 5 6 4 a 45-65% P o wer b 75-90% P o wer Table 14.2
-4 Power Ascension Test Program Test Condition s a Test Name Cold Test or Open RPV Heat Up 1
2 3
4 5
6 Warranty C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-134 1 Chemical and radiochemical X X X X X X 2 Radiation m e asurements X X X X X X 3 Fuel loading X 4 Full core shutdown ma r g in X 5 Control rod drive X X X b X b X b 6 SRM performance and control rod sequence X X X X X X 7 Not applicable 8 Not applicable 9 See 16B 10 IRM performance X X X 11 LPRM calibration X X X X Table 14.2
-4 Power Ascension Test Program (Continued)
Test Condition s a Test Name Cold Test or Open RPV Heat Up 1
2 3
4 5
6 Warranty C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-135 12 APRM calibration X X X X X X X 13 Process computer X X X c 14 RCIC X X 15 Not applicable 16A Selected process temperatures X X X X X X 16B Water level reference leg temperature measurement X X X X X X X 17 System expan s ion and p i ping vibration X X X X X X 18 Core power distribution X X 19 Core performance X X X X X X X 20 Steam production X 21 Core power void mode response X X Table 14.2
-4 Power Ascension Test Program (Continued)
Test Condition s a Test Name Cold Test or Open RPV Heat Up 1
2 3
4 5
6 Warranty C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-136 22 Pressure regulator: setpoint changes X,BP X,BP X,NO BP,M X,BP X,BP, M X,M, BP Backup regulator X,BP X,BP X,NO BP,M X,BP X,NO, BP,M X,M, BP 23 Feedwater s y s t em C feedwater pump trip M d A water level setpoint c hange X X X,M X X X,M B heater loss X e D maximum runout capability X f X f X X 24 Turbine valve survei l l ance X , g,h SP X , i,j SP 25 MSIVs: each valve X X , c S one valve X , g,i,j X , k SP Table 14.2
-4 Power Ascension Test Program (Continued)
Test Condition s a Test Name Cold Test or Open RPV Heat Up 1
2 3
4 5
6 Warranty C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-137 full isolation X , b X , l SD 26 Relief valves:
Flow demonstration X l,m Operational X X m 27 Turbine stop valve X b,l Stop SD Generator load X,BP X b,l Rejection X , n SD 28 Shutdown f r om outside control room X X o Table 14.2
-4 Power Ascension Test Program (Continued)
Test Condition s a Test Name Cold Test or Open RPV Heat Up 1
2 3
4 5
6 Warranty C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-138 29 Recirculation flow control system L L M , m X , m L m X , m L , m M , m A m L g M , g X g L , g X g 30 Recirculation system:
Trip one pump X l,n X l,n Trip two pumps X l,n System performance X X l,m X g X l Runback X d Noncavitation verification X 31 Loss of T-G and offsite power X , b,l SD 32 Not applicable 33 Not applicable Table 14.2
-4 Power Ascension Test Program (Continued)
Test Condition s a Test Name Cold Test or Open RPV Heat Up 1
2 3
4 5
6 Warranty C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-139 34 RPV Internals X m X m X g X g 36-69 Not applicable 70 Reactor water cleanup system X 71 Residual heat removal system X 72 Drywell atmosphere cooling X X X X 73 Cooling w a t e r system X X 74 Offgas system X X X X X a See Figure 14.2-1 for test conditions region map.
b Perform test 5, timing of f our slowest control rods in c onjunction with these scrams.
c Between test conditions 1 and 3.
d Demonstrate recirculation system runback feature.
e 80%-90% power.
f At either heatup or test condition 1.
Table 14.2-4 Power Ascension Test Program (Continued)
C OLUMBIA G ENERATING S TATION Amendment 53 F INAL S AFETY A NALYSIS R EPORT N o v e mb e r 1998 14.2-140 g Between or at test conditions 5 and 6.
h Between 45% and 65% pow er on 100% load line.
i Future maximum power test point.
j Determine maximum po wer without scram.
k Between 40% and 55% power on the 100% load line.
l Do test 17 in conjunction with this test.
m Between test c onditions 2 and 3.
n Perform test 34 in conjunction with this test.
o After one of the scram transients from te st condition, during the reactor cooldown, the last part of the shutdown from outside the control room test will be comple ted by demonstrating the operation of the shutdown cooling mode of RHR from the remote shutdown panel. LEGEND L = Local position command mode operation, POS M = Flux command m ode operation, FLX X = Combined flow command mode operation, FLO A = Automatic load following mode operation, ALF SP = Scram possibility SD = Scram definite BP = Bypass valve response Figure Amendment 53November 1998 Form No. 960690Draw. No.Rev.960690.93Test Condition Region Definition 14.2-1 130 120 110 100 90 80 70 60 50 40 30 20 10 0 Percent Core Flow Percent Power0102030405060708090100110 A. Natural CirculationB. Low Recirculation Pump Speed Valve Minimum Position C. Low Recirculation Pump Speed Valve Maximum Position D. Rated Recirculation Pump Speed Valve Minimum Position E. Analytical Lower Limit of Master Power Flow Control F. Analytical Upper Limit of Master Power Flow Control(Truncate @ 100%
Core Flow and Power)
No. 3 No. 6 No. 1 No. 2 No. 4 A B C D E F 105% Rod Line 100% Rod Line 75% Rod Line 50% Rod Line Minimum Flow Control Line forTransfer to 100% SPD Cavitation Region Recommended Startup Path No. 5 Rated Core Flow Line Condition (TC)1Before main generator synchronization and recirc pumps operating on low frequency power supply from approximately 5 to 20 percent thermal power2Between 50% and 75% control rod lines, at or below the analytical lower limit of master flow control mode3From 50% to 75% control rod lines and core flow between 80% and maximum allowable4Natural circulation and within 5% of the intersection with 100% rod line5Mid-power range within 5% of 100% control rod line and 0 to +5% core flow of the minimum flow line, for master flow control in manual mode, and for automatic power control in auto mode6Within 0 to -5% of rated thermal power, and within 5% of rated core flow rate Columbia Generating StationFinal Safety Analysis Report Figure Amendment 53November 1998 Form No. 960690Draw. No.Rev.Test and Startup Relation to Other Energy Northwest Departments 960222.77 14.2-2 Licensing and Assurance Director Quality Assurance Manager Plant QA/QC ManagerTechnology Director Engineering Manager Power Generation Director Plant Manager Other Plants Assistant Plant Manager*Test Group Manager Plant Administrative ManagerTechnical Manager Operations Manager Maintenance Manager HP/Chem ManagerTest Group
SupervisorTest Group SupervisorTest Group Supervisor Matrix Management Q A Audit Function* Reports Administratively to Test and Startup Programs Manager Columbia Generating StationFinal Safety Analysis Report Figure Amendment 53November 1998 Form No. 960690Draw. No.Rev.CGS Startup Organization 960222.78 14.2-3Plant ManagerAssistant Plant ManagerPlant QA/QCManagerIndustrial SafetyAE, NSSS andProject SupportMaintenanceManager TrainingManager OperationsManagerAdministrationManagerTechnicalManagerHP/ChemistryManagerTest GroupManagerTest GroupManagerTest GroupManagerTest Group SupervisorTest Group SupervisorTest Group SupervisorTest EngineersTest EngineersTest EngineersTest Group SupervisorTest EngineersTest Engineers S/U SupportCraftTest Group Supervisor S/U Support CoordinatorTest Group SupervisorTest Group SupervisorTest Group SupervisorTest EngineersTest Engineers Plan/SchedEngineersEngineering Support Systems Completion CoordinatorHanger Engineers S/U Support Group S/U ServicesTest Engineers Columbia Generating StationFinal Safety Analysis Report Figure Amendment 53November 1998 Form No. 960690Draw. No.Rev.960690.83PreoperationalTest Schedule 14.2-4 1234 1234 1234 1234 412341234 12341234 123412341234 12341234 1234 12344 1234 1234 1234 4123412341234 12341234 1234 1234 1234123412341234 1234 41234 123 412341234 12341234 1234 412341234123412341234123412341234 1234 123412341234 1234 1234 123 4 134 21234FUEL LOAD1 PREPARE PREOPTEST PROCEDURES 2 REVIEW3APPROVE 4TESTACTIVITY LEGEND:NOTE:TIME SCALE LISTEDACROSSTHE BOTTOM OF PAGE IS IN MONTHSCONDENSATEPLANT SERVICEWATERSTANDBY SERVICEWATERFEEDWATERPRIMARY CONTAINMENTATMOSPHERIC CONTROL PRIMARY CONTAINMENT COOLINGPRIMARY CONTAINMENT INSTRUMENTAIRPRIMARY CONTAINMENTATMOSPHERIC MONITORING
125V DC DISTRIBUTIONLOSS OF POWERAND SAFETYTEST 250V DC DISTRIBUTIONINSTRUMENT POWEREMERGENCY LIGHTING 24V DC DISTRIBUTIONSTANDBYAC POWER HIGH PRESSURE CORELOW PRESSURE CORE SPRAYSTANDBY GASTREATMENTRESIDUAL HEAT REMOVALFUEL HANDLING & VESSEL SERVICING EQUIPMENTFUEL POOL COOLINGSECONDARY CONTAINMENT ILRT PRIMARY CONTAINMENT ILRT NUCLEAR BOILERREACTORWATER CLEANUPCONTROL ROD DRIVE MANUAL CONTROLCONTROL ROD DRIVE HYDRAULICROD WORTH MINIMIZER ROD SEQUENCE CONTROLTRAVERSING INCORE PROBEREACTOR RECIRCULATIONREACTOR CORE ISOLATION COOLING PROCESS COMPUTERSTANDBY LIQUID CONTROL LEAK DETECTIONNEUTRON MONITORINGCLOSED COOLING WATERREACTOR PROTECTIONPROCESS RADIATION MONITORINGAREA RADIATION MONITORINGENVIRONS MONITORINGREACTOR BUILDING CRANEREACTOR BUILDING EMERGENCY COOLINGCONTROL, CABLE, & CRITICAL SWCHGR ROOMS HVACSTANDBY SERVICEWATER PUMPHOUSE H&VDIESEL GENERATOR BUILDING H&V V SECURITY OFFGAS MAIN STEAMPLANT COMMUNICATION REMOTE SHUTDOWNLIQUIDAND SOLID RADWASTERADWASTE BUILDING HVAC FIRE PROTECTION Columbia Generating StationFinal SafetyAnalysis Report Figure Amendment 53 November 1998 Form No. 960690 Draw. No.Rev.960690.82 RCIC Acceptance Criteria Curves for Capacity and Actuation Time 14.2-50102030405060708090100 0 10 20 30 40 50 60 70 80 90 100 Percent Rated Power0102030405060708090100 0 50 100 150 200 250 300 350 400 450 Time Delay, Sec Percent RCIC Design Flow Percent Rated Power Unsafe Unsafe Safe Columbia Generating Station Final Safety Analysis Report Safe up to Limited Power Figure Amendment 53November 1998 Form No. 960690Draw. No.Rev.960690.81Maximum Acceptable Drive Flow Response 14.2-6 30 40 50 60 70 80 90 100 0 1 2 3 4 5 6 Percent Drive FlowTime in Seconds Startof TCV/TSV Movement After Columbia Generating StationFinal Safety Analysis Report