ML20070S890
| ML20070S890 | |
| Person / Time | |
|---|---|
| Site: | Quad Cities  |
| Issue date: | 03/19/1991 |
| From: | COMMONWEALTH EDISON CO. |
| To: | |
| Shared Package | |
| ML20070S857 | List: |
| References | |
| NUDOCS 9104030116 | |
| Download: ML20070S890 (931) | |
Text
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QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 D.
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I QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 V G ./ ; Submitted: . M e- 'I u /M [ _.-
$1mul to Fld,11 y/M .tifi ion Coordinator
-Reviewed: 1./__hb _ f.(f//ks.
Qua'd Citte 'Siphilator Training Supervisor l Reviewed: >M e%I- ( h I-d?-N'/f Direc or f rations Program l l ') ' Reviewed: ( .. - tAvf l Simul tor Reyi4W Board Chairman l ! Approved ' d]Cj, l
\ Cm 4,. . , 'I 8
l p Production Training Manager _ -) 1 1
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O o Submitted: Simulator Fidelity / Certification Coordinator Reviewed: Quad Cities Simulator Training Supervisor Reviewed: Director of Operations Program Simulator Review Board Chairman Approved: Production Training Manager 1 1
i QUAD. CITIES' SIMULATOR ANS1/ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, KARCH, 1991
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'# TABLE OF CONTENTS
~SECTION TITLE' PAGE A.1 Simulator Information 3 A.1.1 General 3 A.1.2.1 Control Room Physical Arrangement 4 A.1.2.2 Panels / Equipment 5 A.1.2.3 Systems 11 A.1.2.4 Simulator Control Room Environment 13 A.1.3 Instructor Interface 15 A.1.3.1 Initial Conditions 15 A.1.3.2 Malfunctions 15 A.1.3.3 Controls Provided for Items Outside of Main Control Room 18 A.1.3.4 Additional Special Instructor / Training Features Available 19 A.1.4 Operating Procedures for Reference Plant 21 A.1.5 ' Changes Since Initial Delivery 22 A.2 Simulator Design Database 22 A.3 Simulator Tests 24 A.3.1 Computer Real Time Test 24 A.3.2 Steady State and Normal Operations 24
- (~'T A.3.3 Transient Tests 24
(_) A.3.4 Malfunction Tests Simulator Discrepancy Resolution and 25 A.4 Upgrading Program. 28 APPENDIX 1 List of Initial Conditions (IC's) 29 APPENDIX 2 List of Rer,ote Functions (RF's) 32 APPENDIX 3 -List of Acronyms / Abbreviations 42 APPENDIX 4 Transient Review Board 45 APPENDIX 5 ANSI /ANS-3.5-1985 Certification Report Cross Reference Matrix 48 APPF 7IX 6 Proposed Simulator Malfunction Test Schedule 51 ATTACHMENT 1 Reg Guide 1.149 Requirements for Dual Plant Simulation Facility 60 ATTACHMENT 2 Steady State / Normal Operations /Real Time / Transient Test Results 72 ATTACHMENT 3 Simulator Work Request Procedure 73 ATTACHMENT 4 Simulator Certification Reporting and Testing Program 74 ATTACHMENT 5 Simulator Review Board 75 ATTACHMENT L Simulator and Control Room Layouts 76 ATTACHMENT 7 Malfunction Cause and Effect Sheets 77 O 2
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QUAD CITIES SIMULATOR-ANSI /ANS-3'.5 CERTIFICATION REPORT INITIAL. REPORT,: MARCH, 1991 ' (d A.1' --Simulator Information-A.1.1 General-
- This report is being submitted as the-initial certification report as prescribed in ANSI /ANS-3.5-1985.
The Commonwealth Edison Company and: Iowa-Illinois Gas-
& Electric Company owned General Electric BWR 3, 2511 MWt power plant simulator is- used for training *.he Quad Cities ~ Unit 1 and 2 operators. Because of the near exact-duplication between the two units, it is considered a plant specific simulator for both Quad Cities Units 1.
and 2, hereafter referred to as the Quad Cities Simulator. The Quad Cities simulator is modeled after Quad Cities Unit 1, with Quad Cities Unit 1 being
-considered the reference plant. The simulator was
-constructed by Link-Miles simulation Corporation and declared Ready for Training in April 1990.- Appendix 5 of
-this report lists a Cross-Reference of sections that satisfy-ANSI /ANS-3.5-1985 requirements.
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- QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 A.1.2.1 Control Room Physical Arrangement The physical arrangement of the simulator's control room duplicates Quad Cities station with the - -
following exceptions: (
- 1. The wall mounted area radiation detector which monitors the control room radiation levels is not .
present in the simulator room even though it does have a simulated read out on the 901-21 panel.
- 2. The reference plant control room has a supplied air system which is not present in the simulator room.
- 3. Security badge regress monitors, Sygnatron, are not installed in the simulator room.
- 4. The rimulator room contains Unit 1 and Common Panels only. An instructor station and viewing room are physically located where the Unit 2 panelo would be located.
/"~' These exceptions are considered rainor and the
(,)g_ requirements of ANSI /ANS-3.5-1985, Section 3.2.3, Control Room Environment, have been met. n/ s 4
QUAD-CITIES SIMULATOR-ANSI /ANS-3.5 CERTIFICATION REPORT-INITIAL REPORT, MARCH,_1991 A.1.2.2 Panels / Equipment The: Quad Cities Simulator contains sufficient-
. operational-panels to provide _the controls, instrumentation, alarms, and_other man-machine.
interfaces to conduct normal plant evolutions of ANSI /ANS-3.5-1985, Sections 3.1.1 Normal Plant Evolution-and 3.1.2: Plant Malfunctions for each of the Quad Cities units. Operations normally performed inside the panels'(ex: pulling fuses) are performed using remote functions. The_ age of the reference plant required substituting'some panel equipment. These approved substitutes sometimes have minor appearance-differences with the reference _ plant. Attachment- 6 is the control room layouts of the Quad Cities control room and the simulator. The following panels ar9 simulated . a- 901-1 Computer console
- b. 901-3 Reactor and Containment 1
- c. 901-4 RHR, RWCU, Reactor Recirc
- d. 901-5 Reactor Control O e.
f. 901-6 901-7 Feedwater and Condensate Main Turbine 1 g._ 901-8 Generator and Aux Power
- h. 901-2 Process Rad Monitoring Recorders
- 1.
- 901-10 Process Radiation
- j. . ** 901-14 Blank
- k.
- 901-21 Containment Monitoring
- 1. 901-36 Neutron Monitoring (SRM/IRM)
- m.
- 901-37. Neutron Monitoring (APRM/RBM)
- n. 901-13 TIP's
- o.
- 901-15 RPS "A" relays-
- p. * :901-16 Individual rod scram-
- q.
- _ 901-17 RPS 7 "B" relays
- r.
- 901-18 Flow instrumentation
- s. * .901-19. Flow instrumentation
- t. ** 901-20-Blank
- u. 901-11 Area Radiation Monitors V. 901-54 Off Gas W. 901-55 "A" ACAD/ CAM
- x. 901-56 "B" ACAD/ CAM
- y. 941-1 Computer Console Desk z._ 941-9 -Computer Console Desk aa. 941-24 R.O. Computer Console bb.
- 912-1 Common-Services I cc. 912-2 345KV Switch Yard-5
QUAD CITIES SIMULATOR i ANSI /ANS-3.5 CERTIFICATION REPORT i INITIAL REPORT, KARCH, 1991
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dd.
- 912-5 Standby Gas Treatment, Ventilation, Heating and Air Conditioning ee. 912-8 Lift Station and Safe Shutdown Pump
.ff.
- 912-4 Chimney Process Radiation gg.
- 912-7 Primary Containment Oxygen Analyzer hh. 901-53 Hydrogen Addition
- Partially simulated panels, the remainder of the panel will be visually simulated hardware.
** These panels are filler panels as in the Quad Cities Control Room.
List of partially modeled panels. The following panel components are modeled:
- 1. 901-10
- a. Process radiation
- 2. 901-37
- a. Neutron monitoring (APRM/RBM)
- 3. 901-13
("] a. TIP's V
- 4. 901-15
- a. RPS relays - All switches, indicators, and circuit breakers (all relays will not be wired) . Audible sounds for relay chatter and MSIV relay snap will be simulated.
- 5. 901-16
- a. Individual scram switches are simulated.
- 6. 901-17
- a. RPS relays - All switches, indicators, and circuit breakers (all relays will.not be wired) . Audible sounds for relay chatter and MSIV relay snap will be simulated.
- 7. 901-18
- a. CRD flow integrator will be provided. The
-Eagle signal timer will be fully operational.
- 8. 901-19
- a. Indicating lights are simulated.
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. e ,_ - . . _ . _ . . . . _ . _ _ . . _ -_ __ __
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. QUAD: CITIES-SIMULATOR' :
ANSI /ANS-3.5 CERTIFICATION-REPORT l INITIAL REPORT,--MARCH, 1991 l i 9. 912 a.10 nit'1 auxiliary systems (ext-RBCCW, TBCCW)
~
- b. Common plant' auxiliary systems (ex: Service
, -water)
-10. 912-5 a.fSBGT system b.' -
Unit 11 and common plant.HVAC.
- 11. 912-4
- a. Chimney radiation monitor
- b. Metro tower indication T
- c. One SPING terminal
- 12. 912-7
- a. Unit 1 Oxygen Analyzer 13, 901-14'and 901-20 are blank panels.
- 14. 901-21=
- a. RX vessel temperature' recorder The Quad: Cities-simulator does not model the i
/ following panels / equipment:
- 1. 901-10 a.:The-Off Gas' timer is visually simulated--in
. that11t will not accept manual adjustments. .7
- Timer is-integral part of. simulation computer.-
2.. 901-37 au-All.LPRM circuit cards are not simulated. b.- APRM, RBM electrical adjustmentLdevices are s not simulated..
- c. Flow converters-
- 3. '901-13 a.-Computer tie to. PRIME computer is not H simulated. j 4 .~ 901-15 a.ENot all~RPS relays are wired. A sufficient number of relays are wired to perform plant:
normal and abnormal operations. .; l S. 901-16 .. E a. Computer and brush: recorder terminal points-4 are not simulated.- Lo , u _. u . - ., _ _ . _ . - .~. _ . _ . . . . _ . , _ - . - - . . _ . _ . . _ _ . _ . . _ . _ . - . _ _ , , - . _ _ . _ . - - . - .
QUAD CITIES FIMULATOR ANSI /ANS-3.5 CERTI?1 CATION REPORT INITIAL REPORT MARCH, 1991 ry
- 6. 901-17 a..Not all RPS relays are wired. A sufficient number of relays are wired to perform plant normal and abnorr=.1 operations.
- 7. 901-18 and 901-19
- a. Propt>rtional amplifiers and square root converters for various system indications are dummied.
- 8. 912-1
- a. Unit 2 auxiliary systems are not fully simulated.
-9. 912-5
- a. Unit 2 HVAC systems are not fully simulated.
- 10. 912-4
- a. The upper SPING-is not simulated.
- 11. 912-7
- a. Unit 2 Oxygen analyzer is not fully simulated.
(~s - 12.-901-21 ( a. CRD temperature recorder is not simulated beyond a photograph.
- 13. 901-54 a.. Gas Reheater Dowpoint Temp recorder is not installed on the simulator. The Gas Reheater Dewpoint Temp recorder in the plant control room has a sticker on it with " RECORDER NO LONGER USED" handwritten on.it..
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!~ QUAD CITIES SIMULATOR-ANSI /ANS-3.5 CERTIFICATION RL' PORT INITIAL REPORT, MARCH,-1991
'The_in-plant computer possesses. sufficient-modeling for the^ operators to review;the necessary data for the normal, abnormal, and emergency.
, evolutions required-by ANSI /ANS-3.5-1985. If an On Demand (OD) _ program is not utilizedf by the control' room operators during a plant-evolution, it is not necessary-for training to be-performed on-that program -
The Quad Cities Simulator plant-process computer does not model the following OD' programs-
- 1. OD-1, Full Core LPRM Calibration Justification: Used by the Nuclear Engineers not !
the: control room personnel.
- 2. 0D-2, Individual LPRM Calibration
- Justification: Used by the Nuclear Engineers not the control _ room personnel.
- 3. OD-3, CMC Heat Balance-Justification: Heat balance is available using 0D-5.
- 4. OD-6, Thermal 1 Limits Data O, ' Justification: Used by the Nuclear Engineers to determine which control rods can be-withdrawn,-
not the control rcom personnel.
- 5. OD-11, Preconditioning Data Justification: Used by the Nuclear Engineers to determine which control rods can be withdrawn,- 3 not.the control' room personnel.
1
- 6. OD-15, Computer Outage Recovery _.
l Justification: _Used by the Nuclear Engineers to restart CMC af ter a computer outage, not used by the centrol room-personnel.-
- 7. OD-17, Print Last CMC Justification:-Not available since a true' history of the core. is not available, OD-20 will give current thermal'. limits data.
- 8. OD-18, Kf< Curve Selection Justification: Set by the nuclear engineers, not-used_by the control-room _ personnel.
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; QUAD CITIES SIMULATOR-
-ANSI /ANS-3.5 CERTIFICATION REPORT.
INITIAL REPORT,-MARCH, 1991 9.. OD-29, Hiway Switch or Restore Justification: Not~necessary since there is no Hiway. (Hiway is used to describe the -interf ace-
. from.the Honeywell to PIU).
- 10. OD-34, Restore RPIS or TIP PIU.
Justification: Not necessary since there are no PIU's. Normally used-by_the nuclear engineer, g not the control room personnel.
- 11. OD-35, PIU Status Justification: Not necessary since there are no PIU's.
- 12. 0D-55, PIU Point Summary l Justification: Not necessary since there are no i PIU's.
- 13. 0D-61,. Scram Timing Justification: Not necessary since this is-performed by tech staff not1the control room personnel.
- 14. OD-71, Friction Testing l L I Justification: Not necessary since this is
--- performed.by toch staff not the control room personnel.
- 15. 0D-78, APRM Statistical Composition-Justification: Used by the Nuclear Engineers not the control room personnel.
16.'OD-79, TIP Statistics Justification: Used by the Nuclear Engineers.not the control room personnel.
- 17 . OD-83, Leak Rate Program Justification: Not necessary_since this is i performed by. tech staff not the control room personnel.
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_. _ _ _. - .m _ _ - . . QOAD-CITIES SIMULATOR ~- ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL. REPORT, MARCH, 1991 O A.1.2.3 Systems
- 1. LThe Quad Cities Simulator _models most of the plant's control room operated systems. A' system-component not modeled is the: Unit 1LCRD temperature recorder on the 901-21 panel.
This recorder is visually ~ simulated with'a photograph _because, the recorder does not-normally-run. The actual recorder would turn on for a high temperature alarm condition', but past I m experience shows this occurs rarely, even with adverse conditions. This non modeled component does not detract from training. 1
- 2. The "A" model computer program, software and hardware, are not presently modeled on the Quad -r Cities Simulator. The "A" model takes iodine l indication from in plant. detectors to determine t off-site dose calculations..Although the reference plant control room hardware-is.in place, the model is not functional. The-simulation of this model will require'the addition of_a special PRIME computer. The contract on these leased computers may soon be-O< cancelled. Once a final resolution has been determined by the reference plant, .the "A" model can be added to the simulator.
- 3. Unit 2 cross-ties-that are modeled. include the following:
9 a.-Unit 2 electrical available to Unit i via electrical crosstie breakers. Availability is governed by remote function-ED16 which designates- if Unit 2; is ON-LINE or OFF-LINE.
- b. Unit 2 CRD flow and pressure is'available to Unit i via crosstie lines controlled by remote function RD09.
- c. Unit 2 heating and ventilation. systems and .
fans are logically;modeled. IE;1 station blackout causes-them to'deenergize.
- d. Electrical supply to Unit 1 orJ1/2 equipment as alternate feeds are controlled by remote functions.-(exception is the Safe Shutdown Makeup Pump system) 11
QUAD CITIES SIMULATOR ANSI /ANS-3.B CERTIFICATION REPORT INITIAL' REPORT, MARCH, 1991 , ,h . w- e. Unit 2 service water can supply Unit i since they have a common discharge header,
- f. Unit 2 reactor building ventilation isolation dampers which are affected by Group II isolation on Unit 1.
- 3. The tasks related to non-modeled systems, including Unit 2, are handled administratively.
to ensure procedural compliance is maintained. In addition the non-modeled systems do not impact on the ability to perform the plant evolutions listed in ANSI / ANS-3. 5-1985, Section 3.1.1 or respond to the malfunctions in Section 3 .1. 2 . -
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QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 i
\_/ A.1.2.4 Simulator Control Room Environment The Quad Cities Simulator simulates the centrol room environment to a high degree with the following exceptions:
- 1. The simulator page system can not be accessed from the regular telephone system as it can in the referenced plant. Both the unit operator station and the center desk operator station have the page system so the fact that they can not use the phone tie to the page system has no impact on training.
- 2. The simulator radio pager, which is an electronic tone page received over the walkie-talkie radios carried by in plant operators, does not work.
This requires the center desk operator to summon te plant operators using the plant page system - r the telephone. Since the radio pager does not 9enerate any sound in the control rocm, the non-operation of the pager does not .etract from training.
- 3. The annunciator tones in the simulator vary
(-m) from those at-the reference plant in both tone and pitch. None of these dif ferences detract from training since the operators respond to an alarm regardless of it's tone quality or pitch. Modification number M-4-1-87-051, is an on-going modification which is replacing all control room annunciator horns. The reference plant modification is scheduled to be completed in approximately two years. '
- 4. The simulator lighting system is as close to exact replication of the reference plant as possible but minor differences exist. Building codes require certain lighting to remain on near exits. This is true in the simulator' room and all lighting does not go off during a simulated loss of all AC power. The fact that the majority of the room lighting goes out and a definite change in room lighting is experienced-is the training needed for the operators.
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l' QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 f~
- 5. The-reference plant contains a weather radio in the control room and this radio does not exist in the simulator. Aside from appearance this piece of equipment would serve no useful function in the simulator training program. This radio's sound is normally OFF unless manually activated by depressing a button. The exception to this is automatically received severe weather warnings from the National Weather Service.-Such information is given to the operators during training sessions via the scenario plant r turnover.
The above minor differencos do not impact training and the requirements o C ANSI / ANS-3. 5-1985, section 3.2.3, Control Room Environment-have been met. P o 14
QUAD CITIES SIMt!LATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, KARCH, 1991 A.1.3 Instructor Interface A.1.3.1 Initial Conditions The Quad Cities Simulator has 30 predetermined initial conditions. An additional 46 initial conditions are available and may be used by the instructor when appropriate to store non-protected initial conditions. Additionally, the simulator has 60 backtrack steps. These steps can be set to vary from 10 second to 10 minute intervals. The requirements of ANSI /ANS-3.5-1985, Section 3.4.1 have been met. A list of initial conditions can be found in Appendix 1. A.1.3.2 Malfunctions The current malfunction description sheets, which serve as malfunction test abstracts, can be found in Attachment 7. The Quad Cities simulator malfunction assessment process utilizes LER's, deviation reports (DVR's) and'other industry events for determining ( additions / deletions to the existing simulator malfunctions. The applicable malfunctions from Attachment 7 are cross-referenced to the ANSI /ANS-3.5-1985, Section 3.1.2 required malfunctions as follows: Simulator Malfunctions ANSI /ANS-3.5-1985 corresponding to the Section 3.1.2 reauirement
- 1) Loss of coolant: 1) a) Significant-PWR S/G a) N/A - PWR tube leaks b) Inside/Outside primary b) CUO3, FW10, containment FW11, FW12 c) Large/small Rx coolant c) RR10, .RR11, breaks (including RR12, RR13 demonstration of saturation condition) d) Failure of safety / relief d) AD01, AD02, valves AD03, AD07 15
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 l l d Simulator Malfunctions l ANSI /ANS-3.5-1985 corresponding to the l Section 3.1.2 raggirement
- 2) Loss of instrument air to the 2; I A01, I A02, I A04, extent that the whole systet or IA05 i I
individual headers can lose pressure and affect the plant's static or dynamic performance. 1
- 3) Loss of degraded electrical 3) ED01, ED02, ED03, power to the station, including EDOS, ED07, ED09, loss ?>f off-site power, loss of ED10, ED12, ED13, l emergancy power, loss of ED14, DGol, DG02, emergency generators, loss of DG03, DG04 power to the }ilant's electrical distributien 1;uses and loss of power to the individual instrumentation buses (AC as well as DC) that prcvide power to control room indication or plant control functions r~T affecting the plant's response.
V 4) Loss of forced core coolant 4) RR01, RR02, RR04 flow due to single or multiple pump failure.
- 5) Loss of condenser vacuum 5) MC01, FW21, FW22 including loss of condenser level control.
- 6) Loss of service water or 6) SWO1, SW11, SW12 cooling to individual SW15 components.
- 7) Loss of shutdown cooling 7) RH01,RH02
- 8) Loss of component cooling 8) SWO3, SWO6, SWO7 system or cooling to individual components.
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i QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 f"'j- i V Simulator Malfunctions ANSI /ANS-3.5-1985 corresponding to the Section 3.1.2 requirement i
- 9) Loss of normal feedwater or 9) FWO1, FWO4, FWO7, normal feedwater system failure FWO8, FW14, FW15, FW16, PW17, FW18, FW19 10)-Loss of all feedwater (normal 10) FWO2 and emergency)
- 11) Loss of protective system 11) RP03, SLO 1, SLO 2 channel
- 12) Control rod failure including 12) RD01, RD02, RD03, stuck rods, uncoupled rods, RD04 drifting rods, rod drops, and misaligned rods.
- 13) Inability to drive control 13) RD07, RD08 rods
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- 14) Fuel cladding failure resulting in high activity
- 14) CR01, CR02 in reactor coolant or off gas and the associated high radiation alarms.
- 15) Turbine trip 15) TC01, TUO1, TUO2
- 16) Generator trip 16) EG01
- 17) Failure in automatic control 17) RR09, RR14, RR15, system (s) that affect RR23 reactivity and core heat.
removal.
- 18) Failure of reactor control 18) N/A - PWR pressure and volume control syste7s (PWR)
- 19) Reactor trip 19) RP04 L/ 17 l
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QUAD CITIES SIMULATOR-ANSI /ANG-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 2991 h Simulator Malfunctions ANSI /ANS-3.5-1985 corresponding to the Section 3.1.2 reauirement
- 20) Main steam line as well as 20) FH09, FH10, FW11, main feed line break (both FH12, MS05, MS06, inside and outside MSO9, MS10 containment)
- 21) Nuclear instrumentation 21) NM01, NM02, NMO 5, failure (s) NM06, NM08, NM10
- 22) Process instrumentation, 22 ) FH06, RR12, RR13, alarms, and control system RR17, RR18, RR19, failures. RR21, RR23
- 23) Passive malfunctions in 23) HP01, HP03, HP09, systems, such as engineered HP11, HP13, HP14, safety features, emergency HP16, HP17, RC01, feedwater systems RCO2, RC04, RC05, RC06, RC07, RC11, RC12, RC14
- 24) Failure of the automatic 24) RP02 O%.
reactor trip system
- 25) Reactor pressure control 25) TC08, TC09, TC11 system failure including turbine bypans failure (BWR)
A.1.3.3 Controls provided for items outside the control room Appendix 2 is a listing of remote functions for the simulator on the date of this report. The appropriate remote functions exist for systems that are operated outside of the Control Room and that are also needed to perform normal plant evolutions and/or malfunctions required by ANSI /ANS-3.5-1985 Section- 3.1.1/3.1.2. O .8 l
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991
\' A.1.3.4 Additional special instructor / training features available
- a. Backtrack As previously mentioned, the Quad Cities simulator has the capability of backtracking. The time frame for tracking the backtrack snapshots is adjustable so that, if the instructor desires, he can offer a backtrack capability of 60 discrete steps with the amount of time between each step varying from 10 seconds to 10 minutes.
- b. Freezing The Quad Cities Simulator has the capability to freeze the dynamic simulation. " Frozen / Static" simulator examinations have been administered on the Quad Cities simulator with no problems noted.
- c. Simulator Speed The Quad Cities Simulator has the capability to vary the speed of simulation. The most useful portion r'g of this feature is slowing down the
() simulator to allow the students and instructor to observe and discuss all parameters. Slow time can be varied from 1/2 to 1/10 real time. The simulator also has the capability to go into fast time for the following parameters 1.) RR pump neatup 2.) Main condenser vacuum 3.) Xenon concentration 4.) Core decay heat 5.) Turbine metal temperatures 6.) Turbine coastdown. These parameters fast time mode can be varied from 1 to 10 times real time.
- d. Override The Quad Cities Simulator has the capability of failing any-control board panel control switch or light either in the ON or OFF position. -In addition,.each control board meter-can be overridden to various positions.
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QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991
'/ e. Annunciator The Quad Cities Simulator has the capability of failing any driven annunciator either ON, OFF, or CRY WOLF. CRY-WOLF is a feature where an annunciator will randomly alarm and then allow the operator to reset the annunciator, this will be repeated until CRY-WOLF is removed for that annunciator.
- f. Auxiliary The Quad Cities Simulator has an Instructor auxiliary instructor's console which can be used when the Console instructor wishes to interact to a large degree with tha students. This console is a full scope instructor's station with all options available,
- g. Plant The Quad Cities Simulator also uses Parameters Plant Parameters which give the instructor the flexibility to modify parametern which are outside-the operating staff's centrol. Examples include atmospheric temperature, gg atmospheric pressure and river V temperature.
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QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 A.1.4 Opezating Procedures for Reference Plant Tae procedures used on Quad cities simulator are the actua! plant controlled procedures. When required, tempo;ary procedure changes are used to accommodate differences between the simulator and the plant proe2dures. Quad Cities Station utilizes the same set of procedures for operating both Units 1 and 2, with a copy of these procedures kept on each unit. O 21 l
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CER"lIFICATION REPORT INITIAL REPOPP, MARCH, 1991
- t' A.1.5 Changes Since Initial Delivery This section is not appli7able since this is an Initial Certification Report. This section will be applicable to subsequent Updates to the Certification Report.
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QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O \" A.2 Gimulator Design Database The simulator design database for the Quad Cities , Simulator is Quad Cities Unit i data. This database includes he data from which the simulator was designed and built, and cn which upgrades and modifications are based. The database includes design documents, performance data, records, 4-aumptions, simplificatior.J, derivations and other definable
' on which the current design of the simulator hardware and
- vare is based. These documents can be found in the General F1.as, Simulator (SIM) file.
O
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O A.3 Simulator Tests A.3.1 Computer Real Timo Tests Computer real time test was performed per Appendix A of ANSI /ANS-3.5-1985. The results of the test are as follows with the full test being located in Attachment 2.
- a. 1991 Test Acceptable A.3.2 Steady State and Normal Operations Steady stato tests woro performed por Appendix B of ANSI /ANS-3.5-1985. The required power levels, and subsequent hold points were checked using actual plant data. The results we o reviewed by a panel of experts and the results of these tests are as follows. The full test is found in Attachment 21
- a. 25% Test Acceptable
- b. 40% Test Acceptable
- c. 50% Test Acceptable
- d. 75% Test Acceptable
- e. 100% Test Acceptable
( Normal operations test was performed por Appe; dix B of ANSI /ANS-3.5-1985. The results of those tests are as follows with the full test found in Attach'sent 21
- a. Acceptable Surveillance tests were performed 1.cr Appendix B of ANSI /ANS-3.5-1985. The results of these tests are as follows with the lull test found in Attachment 2:
- a. Acceptablo A.3.3 Transient Testa a Transient tests were performed per Appendix B of ANSI /ANS-3.5-1985. Appendix 4 contains the Transient Review Board used for transient test analysis. The results of these tests can be found in Attachment 2.
- a. Manual scram Acceptable
- b. Simultaneous trip off all foodwater pumps Acceptable
- c. Simultaneous closure of-main steam isolation valves Acceptable 24
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991
- d. Simultaneous trip off all recirculation pumps Acceptable
- e. Single recirculation pump trip Acceptable
- f. Main turbine trip (maximum power level which does not result in immediate reactor trip) Acceptable
- 9. Maximum rate power ramp (master recirc in MANUAL, 100%-75%-100%) Acceptable
- h. Maximum size reactor coolant system rupture combined with loss of offsite power Acceptable
- 1. Maximum size unisolable main steam line rupture Acceptable
- j. Simultaneous closure of main steam isolation valves combined with single stuck open safety / relief valve (inhibit high pressure ECCS) Acceptable A.3.4 Malfunction Tests Malfunctions have been tested in accordance with ANSI /ANS-3.5-1985. Approximately 25% of the malfunctions identified in Appendix 6 are tested annually. The individual tests can be found in the General Files, Simulator (SIM) file. The malfunction test results were-O satisfactory with the following exceptions:
KALF BRIEF DESCRIPTION WORK REQUEST DATE WR NUMEER CLEAREQ_ RD09 With RD09A active. B_CEQ_ puton OC-90-693 . does nqt_ trio _ SW15 , DG coolina water Dumn trio after DR-A0166 _ _ _ _ DG auto start . . [X3 does not __ destrov itself O 25 i
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O- In the event of a malfunction failing it's test a Work Request is written to correct the problem. In the interim, any malfunctions that are unavailable for training are documented on a "NO". AUTHORIZED FOR USE" letter which is kept at the insttoctor station. This letter informs each instructor as to which malfunctionu are currently unavailable for training. In order to avoid negative training which can result when the simulator progresses beyond design limits, the instructor system computer console displays a message to the instructor. This message alerts the instructor when selected paratneters approach values indicative of events beyond the implemented model or known plant behavior. The requirements of ANSI / ANS-3. 5-1985, Section 4. 3, Simulator operating Limits, have been met. t ' 9 I O- 26 1
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 (3
'd- A License Event Report (LER) review of all Quad Cities events is performed on a semi annual basis. The LER's will be reviewed as part of the plant malfunction assessment process. A summary of the 1989 and 1990 Quad Cities Unit 1 LER that were determined to effect simulation follows:
LIB DESCRIPTION COHMENTS , 89-003 Unit One Manual Scram LER tested satisfactorily. DVR-04-01-89-029 LER added to Malfunction Cause and Effect Book. 89-004 Relief Valve 1-203-3D Stuck LER tested satisfactorily. Open. LER added to Malfunction DVR-04-01-89-031 Cause and Effect Book. 89-007 1A Refuel Floor Rad Monitor LER tested satisfactorily. ' spiked high. LER added to Malfunction DVR-04-01-89-049 Causo and Effect Dook, 89-010 Rx scrammed on turbine trip. LER tested satisfactorily. DVR-04-01-89-058 LER added to Malfunction Cause and Effect Book. 89-015 Off-Gas isolation. LER tested satisfactorily. DVR-04-01-89-070 LER added to Malfuncticn Cause and Effect Book. 90-004 Unit 1 generator LER tested satisfactorily. trip / reactor scram. LER added to Malfunction DVR-04-01-90-021 Cause and Effect Book. h 90-007 Reactor ventilation and LER tested satisfactorily. ' control roon vent isolation. LER added to Malfunction DVR-04-01-90-026 Cause and Effect Book. 90-016- Failure of 1/2A fire pump to LER tested satisfactorily, start on low fire header LER added to Malfunction pressure or manually. Cause and Effect Book. DVR-04-01-90-069 90-018 Unit 1 Diesel generator LER tested satisfactorily. trip. LER added to Malfunction DVR-04-01-90-018 Cause and Effect Book. 90-025 Group II Isolation on LER tested satisfactorily. reactor level instrument LER added to Malfunction return to service. Cause and Effect Book DVR-04-01-90-136 27 l
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT j INITIAL REPORT, HARCH, 1991 A.4 Simulator Discrepancy Resolution and Upgrading
- 1. Identifying, logging, correcting, and testing simulator discrepancies.
Administrative Procedure PTAO-103, Simulator Work Request Procedure describes how an identified simulator discrepancy is retcived. See Attachment 3 for a copy of PTAO-103, Simulator Work Request Procedure. 3
- 2. Tracking of design changes incorporated into the reference plant but not yet incorporated into the simulator.
Production Training Department receives modifications f rom Quad Cities Station. Modifications are reviewed per PTAO-101, Document Tracking and Review, and if a change to simulation is required, a Work Requent is written in accordance with PTAO-103, Simulator Work Request Procedure. In addition, all modifications that require simulator work are approved and tracked by the Simulator Review Board in accordance with PTAO-104, Simulator Review Board procedure. See Attachment 5 for a copy of PTAO-104, Simulator Review Board procedure. O O 28
.- .,n . ._, -. - _
QUAD CITIES SIMULATOR
- j. ANSI /ANS-3.5 CERTIFICATION REPORT L
INITIAL REPORT, MARCH, 1991 l i? APPENDIX 1 l LIST OF INITIAL CONDITICNS
- This Appendix lists simulator initialization conditions. These initial conditions include a variety of plant operating conditions, fission product poison concentrations, and various times in core life as required by ANSI /ANS-S.5-1985 Section 3.4.1.
v O 29
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 APPENDIX 1 4 LIST OF INITIAL CONDITIONS (IC's) l NOII
)O IC's 1 through 30 are Protected, this prevents accidentally snapping an IC over them.
The initial ATP references different initial condition numbers and descriptions than these listed here. IC-01 QGP 1-1, Step S-1.1, BOC, all systems shutdown, ready to start QGP 1-S1. IC-02 QGP 1-1, Step D.1.1, BOC, ready to pull rods. IC-03 QGP 1-1, Step D.1.1, BOC, 3 rods subcritical. IC-04 QGP 1-1, Step D.6.s, BOC, 40% power. IC-05 QGP 1-1 Completed, 500, 100% power, QGP 3-1. O \_/ IC-06 QGP 1-1, Step D.1, MOC, QGP 1-Si complete, ready to pull rods. IC QGP 1-1, Step D.1.1, MOC, 3 rods subcritical. IC-08 QGP 1-1, Step D.1, EOC, QGP 1-S1 complete, ready to pull rods. IC-09 QGP 1-1, Stop D.1.1, EOC, 6 rods suberitical. IC-10 QGP 1-1, Step D.3.a., EOC, startup/ critical. , IC-11 QGP 1-1, Step D.3.j, EOC, startup/heatup. IC-12 QGP 1-1, Step D.3.k, EOC, startup/heatup. IC-13 QGP 1-1, Step D.3.m, EOC, startup/heatup. IC-14 QGP 1-1, Step 0.3.t, EOC, startup/heatup. IC-15 -QGP 1-1, Step D.3.y, EOC, ready to go into RUN, startup/heatup. IC-16 QGP 1-1, Step D.4, EOC, ready to roll turbine, startup/heatup. 30
- .. - ~ - . - _ _ _ . . - .- .-. . .____ -_ _ _ _ _- -
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 l APPENDIX 1 LIST OF INITIAL CONDITIONS (IC's) IC-17 QGP 1-l', Step D.6.p, EOC, 25% power, startup/heatup. ; I IC-18 QGP 1-1, Stop D.6.t, EOC, 40% power, startup/heatup. IC-19 QGP 1-1 Completed, EOC, 50% power, startup. IC-20 QGP 3-1, EOC, 75% power, 100% flow control lino. IC-21 QGP 1-1 Completed, EOC, 100% power. IC-22 QGP 1-1, Step D.1.j, EOC, hot scram recovery, approximately 6 rods subcritical. IC-23 QGP 1-1, Step D.5, EOC, generator off-line, turbine at set speed. IC-24 QGP 2-4 Coastdown. IC-25 QGP-1-2, Hot Standby, MSIV's closed,-3 rods suberitical. IC-26 QGP 2-1, Step D.5, EOC, 40% power, shutting down. IC-27 QGP 2-1, Step 18, EOC, 12% power, shutting down. IC-28 QGP 2-1, Step 45, EOC, ready for shutdown cooling. IC-29 Refuel, EOC, ready to flood the vessel. IC-30 Refuel, EOC, vessel flooded. IC-31 SPARE Thru IC-76 , 31 l
QUAD c1 TIES SIMULATOR ANSI /ANS-3.ti CERTITICATION REPORT INITIAL REPORT, MARCH, 1991 APPENDIX 2 LIST OF REMOTE TUNCTIONS (RF's)
- This Appendix lists remote functions which exist for syntums that are operated outside of the Control Room and also those which ate needed to perform normal plant evolutions and/or malfunctions required by ANSI /ANS-3.5-1985 Section 3.1.1/3.1.2.
O 32 1 l 1
, _ . ~ . - - - - - , - - . . , . - - - , , . . -
3 QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 (
\2 APPENDIX 2 LIST OF REMOTE FUNCTIONS (RF's)
~
CRO1 ist Half Of Core Except Assemblies SRM Ch 21 & 23 CR02 2nd Half of Core Except Assemblies SRM Ch 22 & 24 CR03 Defuel/ Refuel Assemblies Around SRM Ch 21 & 23 CR04 Defuel/ Refuel Assemblies Around SRM Ch 22 & 24 CRO5 High FCL/ Low Flow Oscillation Trigger CR06 Inhibit Auto Fuel Failure At 2200 Degf CS01 CCST Manual Isolation Valve 1-1402-2A CSO2 CCST Manual Isolation Valve 1-1402-2B CS03 Cond Xfer System Manual Isolation Valve 1-3399-129 CSO4 RHR/CS Fill System Pump 1-1402-57 Trip CUO1 RWCU Isolation Valve 1-1299-10 CUO2 RWCU NRHX (1A-1204) & RHX (1A-1203) Out/In Service CUO3 RWCU NRHX (18-1204) & RHX (1B-1203) Out/In Service CUO4 RWCU NRHX & RHX Bypass Valve 1-12 1-9 CUO5 RWCU Isolation Valve 1-1299-14 COO 6 RWCU NRHX/RHX/CU Recirc Pump Bypass Vlv 1-1299-12 CUO7 RWCU Filter Demineralizar Input Isol Viv 1-1299-11 CUOB RWCU Recirc pump Bypass Valve 1-1299-13 CUO9 RWCU Filter Domineralizer 1-1279-1A Out/In Of Service O CU10 Cull RWCU Filter Demineralizer 1-1259-1B Out/In of Service RWCU T'.lter Demineralizer 1-1279-1A Boron Injection CU12 RWCU 111ter Demineralizer 1-1279-1B Boron Injection CU13 RWCU Filter Demineralizer FCV-1279-15A Fetpt Adjustment CU14 RWCU Filter Demineralizer FCV-1279-15B Setpt Adjustment CU15 RWCU SBLC To Cleanup Isolation Valve 1-1101-20 0016 RdCU Boron Source Selection Precoat Tank /SBLC Tank CU17 Rh00 Pilter Demin Panel 2201-63 Alarm Ack CU18 RWCU Isolation Bypass (QCOP 1200-7) DG01 DG-1 Droop Setting DG02 DG-1/2 Droop Setting DG03 DG-1 Lockout Reset DG04 DG-1/2 Lockout Roset DG05 DG-1 PB Engine Reset DG06 DG-1/2 PB Engine. Reset DG07. DG-1 Day Tank Instantaneous Fill DG08 DG-1/2 Day Tank Instantaneous Fill DG09 DG-1 Local Trip DG10 DG-1/2 Local Trip DG11 BUS 23-1 Csnnection To Unit 2 DG12 DG Bkr 2321 Pigtail DG13 DG Bkr 1321 Pigtail DG24 DG-1/2 Output Skr Keylock Switch 33
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QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCil, 1991 O APPENDIX 2 LIST OF REMOTE FUNCTIONS (RF's) DG15 Deleted DG16 Deleted DG17 Deleted-DG18 DG-1 Local Alarm Ack/ Reset DG19 DG-1/2 Local Alarm Ack/ Reset ED01 Switch Gear 11 125V DC Control Power ED02 Switch Gear 12 125V DC Control Power ED03 Switch Gear 13 125V DC Control Power ED04 Switch Gear 14 125V DC Control Power EDOS Switch Gear 13-1 125V DC Control Power ED06 Switch Gear 14-1 125V DC Control Power ED07 Switch Gear 15 125V DC Control Power ED08 Switch Gear 16 125V DC Control Power ED09 Switch Gear 17 125V DC Control Power ED10 Switch Gear 18 125V DC Control Power ED11 Switch Gear 19 125V DC Control Power ED12 125V DC BUS 1A To 1B-1 Breaker ED13 OCB 6-7 Local Control ED14 OCB 7-8 Local Control ED15 Unit 1 Line Disconnect O' ED16 Unit 2 Generator Status ED27 Ros Aux Xfmr 12 Disconnect ED1B Res Aux Xfmr 12 U.V. Reset Y Windings ED19 Res Aux Xfmr 12 U.V. Roset X Windings ED20 4KV Bkr 1101 Lockout Reset Tr 11 to BUS 11 ED21 4KV Bkr 1104 Lockout Reset Tr 12 to BUS 11 ED22 4KV Bkr 1205 Lockout Roset Tr 11 to BUS 12 ED23 4KV Bkr 1202 Lockout Roset Tr 12 to BUS 12 ED24 4KV Bkr 1203 Lockout Roset Tr 11 to BUS 13 ED25 4KV Bkr 1309 Lockout Reset Tr 12 to BUS 13 ED26 4KV Bkr 1412 Lockout Roset Tr 11 to BUS 14 ED27 4KV Bkr 1405 Lockout Reset Tr 12 to BUS 14 ED28_ 4KV Bkr 1410 Lockout Reset Tr 14 to BUS 14-1 ED29 4KV Bkr 1327 Lockout Roset Tr 13 to BUS 13-1 ED30 4KV Bkr 1427 Lockout Reset Tr 14 to BUS 14-1 ,
-ED31 4KV Bkr 1312 Lockout Roset Tr 13 to BUS 13-1 ED32 4KV Bkr 2425 Lockout Roset Tr 24-1 to BUS 31 ED33 Res Aux Xfmr 12 86 Relay Roset ED34 Unit 2 4KV BUS 24-1 Status ED35 250V DC Link A03 Status ED36 250V DC 101 MCC2B To MCC 1 ED37 250V DC Bkrs A02/A03 Toggle ED38 125V DC Battery BUS #1 Charger Bkrs O 34 i
1
QUAD. CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 APPENDIX 2 LIST OF REMOTE FUNCTIONS (RF's) ED39 125V DC Receive Feed From Unit 2 BO4/A01 ED40 Pump Cavitation Trip Reset ED41 250V DC Link WO1 Status ED42 125V DC Unit 2 Power To Switchyard ED43 480V MCC 16/26-1 Power Supply ED44 480V MCC 16/26-4 Power Supply ED45 480V MCC 16/26-5 Power Supply ED46 480V MCC 16/26-6 Power Supply ED47 480V MCC 17/27-3 Power Supply ED48- 480V MCC 17/27-4 Power Supply ED49 All Unit 2 AC BUS Status - For Station Blackout EG01- SCW Pumps. Test Switch-Y45 Valve EG02 Main Generator Disconnects EG03 Main Generator Lockout Resets EG04 Add Generator Hydrogen Valve VI-5301 EGOS Main Generator Field Breaker EG06 Exciter Field Breaker EG07 Hydrogen Purity Adjustment EG08 SCW Local Panel Acknowledge / Reset Hydrogen Seal Oil Local Panel Acknowledge / Reset O EG09 EG10 Hydrogen Seal Oil Pump Test Switch FP01 Diesel Pump A Local Control Switch FP02 Diesel Pump B Local Control Switch FP03 Water Supply To Fire Hose From Main Header FPO4 Fire Protection PB For Horn / Light Ack/Rst FP05 Fire Protection PB For Horn / Light Ack/Rst FWO1 OG Condenser Bypass V1v 1-3399-131 FWO2 Condensate Demineralizer Inlet Viv MO-1-3301A FWO3 Condensate Domineralizer Inlet Vlv MO-1-3301B FWO4 Condensate Domineralizer Inlet Viv MO-1-3301C FWOS Condensate Demineralizer Inlet V1v MO-1-3301D FWO6 Condensate Demineralizer Inlet Viv MO-1-3301E FWO7 Condensate Demineralizer Inlet Vlv MO-1-3301F FWOB Condensate Demineralizer Inlet Vlv MO-1-3301G FWO9 Contaminated CST Fill Viv 1/2-4399-8 FW10 Clean CST Fill Vlv 1/2-4399-10 FW11 SJAE A Inlet Viv 1-3399-42 FW12 SJAE B Inlet Vlv 1-3399-43 FW13 Gland Steam Condenser A Inlet Vlv 1-3399-46 FW14 Gland Steam Condenser B Inlet Vlv 1-3399-47 FW15 Off Gas Condenser A Inlet Vlv 1-3399-132A n# 35
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 APPENDIX 2 i LIST OF REMOTE FUNCTIONS (RF's) FW16 off Gas Condenser B Inlet Vlv 1-3399-132B FW17 Condensate To Condenser FCV-1-3401 FW18 Condensate System Fill Line Vlv 1-3399-35 FW19 Condensate Sys X-Tie From Unit 2 To Unit 1-5599-68 , FW20 Htr 1B1 Drn To FTK 1A1 LCV-1-3502A Latch Sw l FW21 Htr 1B2 Drn To FTK 1A2 LCV-1-3502B Latch Sw FW22 Htr 1B3 Drn To FTK 1A3 LCV-1-3502C Latch Sw FW23 Htr 1C1 Drn To 1B1 LCV-1-3504A Latch Sw FW24 Htr 1C2 Drn To 1B2 LCV-1-3504B Latch Sw I FW25 Htr 1C3 Drn To 1B3 LCV-1-3504C Latch SW FW26 Htr 1D1 Drn To 1C1 LCV-1-3506A Latch Sw FW27 Htr 102 Drn To IC2 LCV-1-3506B Latch Sw FW28 Htr 103 Drn To 1C3 LCV-?.>-5506C Latch Su FW29 Cond Demin Trouble Panel 901-6-F-12 Local Panel Ack FW30 Low Flow FW Reg Isol Valve 1-3207A FW31 Condensor Emergency Reject Inlet Isolation Valve 1-3399-1 FW32 Condensor Normal Reject Inlet Isolation Valve 1-3399-3 FW33 Condensor Makeup Bypass Valve 1-3399-63 FW34 Hotwell Reject To CRD Setpoint FW35 Gland Water Tank LCV Bypass 1-4299-21 () FW36
-HP01 RFP High Level Trip Bypass (QCOP 1600-3)
HPCI-Fill Lino Valve 1-2301-107 HP02 HPCI Turb Exhaust SteLm Line Valve 1-2301-74 HP03 Safe Shutdown Suction Source (C-2901-74 Or 0-2901-2 & 3) HPO4 Finger Blocks For QOS 2300-13, Hot fast Initiation HP05 HPCI Auxiliary 011 Pump Breaker HP06 HPCI Valve 2301-4 Deonergized Signal HP07 HPCI Valve 2301-8 Control Power Breaker HP08 Vlv 0-2941-06 Manual Operation - Only for Loss of Power HP09 Vlv 1-2901-08 Manual Operation - Only for Loss of Power HP10 HPCI Valve 2301-9 Control Power Breaker HP11 HPCI Valve 2301-8 Manual Operation HP12 HPCI Valve 2301-9 Manual Operation HP13 High Torus Level Transfer Bypass (QCOP 2300-9) HP14 .HPCI Drain Level Isolation Bypass (QCOP 201-10) HP15 HPCI Steam Supply Isolation Valvo Bypass (QCOP 201-10) HP)6 Safe Shutdown Pump Deadhead overcurrent Trip Reset HV01 Fan 1-5708A RO-Dmpr 1-5722-53A Open HV02 Fan 1-5708B RO-Dmpr 1-5722-53B Open HV03 Deleted MV04 Unit 2 RB Vent Flow HV05 Unit 2 Chimney Flow HV06 Wind Speed HV07 Wind Direction 36
__ _ _ _ . _ _ - _ _ - - - .. = . . _ _ - _ - - - . QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O APPENDIX 2 LIST OF REMOTE FUNCTIONS (RF's) HV08 Deleted HV09 Deleted HV10 Control Room Isolation Roset HVil RB Supply Fan 1A Local Trip HV12 RB Supply Fan 1B Local Trip HV13 RB Supply Fan 1C Local Trip HV14 RB Exhaust Fan 1A Local Trip HV15 RB Exhaust Fan 1B Local Trip RV16 RB Exhaust ran 1C Local Trip HV17 RHR Room Cooler 1B Power Supply HV18 CR AHU B Cooling Water Supply HV19 Outside Air Temperature HV20 River Temperature HV21 "B" Control Room AHU Fan Local control HV22 "B" AFU Booster Fan Local Control HV23 Fan 1-5795-10 circuit Bkr Status HV24 Fan 1-5795-30 circuit Bkr Status HV25 Group II Isol And RB Vent Isol Bypass (QCOP 1600-17) IA01 Instrument Air /N2 Changeover Valve 1-4799-207 IA02 Drywell Pnoumatic Compressor O IA03 IA04 Service Air To IA Backup Manual Vlv 1-4799-223 N2 To DW Pneu System Backup Manual V1v 1-4799-163 IA05 IA To Turbine Building Isolation Viv 1-4799-TB IA06 IA To Reactor Building Isolation Vlv 1-4799-84 1A07 IA To Control Rod Drive Isolation Vlv 1-4799-115 IA08 DW Pneu Res Sup Bypass Vlv 1-4799-168 IA09 IA To FW Heater Level Control 5402 Valve 1-4799-21 IA10 IA To FW Heater Level Control 5401 Valve 1-4799-22 IAll Scram Air Header Leakage IA12 IA Header Leakage IA13 DW Pneumatic Header Leakage IA14 IA Unit 2 Service Air X-Tie Valve MC01 Outside Air Temperature MCO2 River Temperature MCO3 Circ Wtr Viv MO-1-4402A Local Manual Operation MC04 Circ Wtr Viv MO-1-4402B Local Manual Operation MC05 Circ Wtr Vlv MO-1-4402C Local Manual Operation MC06 Cire Wtr Viv MO-1-4402D Local Manual Operation MC07 Cire Wtr Vlv MO-1-4403A Local Manual Operation MC08 Cire Wtr Viv MO-1-4403B Local Manual Operation MC09 Circ Wtr Vlv MO-1-4403C Local Manual Operation MC10 Circ Wtr V1v MO-1-4403D Local Manual Operation MC11 Circ Wtr Viv Operation MC12 Deleted 37
. . _ - . ~ - ~ - - - _ _ - . _ _ - - . - . - - - . - - . .
QUAD CITIES SIMULATOR
- j. ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, KARCH, 1991 I APPENDIX 2 i
LIST OF REMOTE FUNCTIONS (RF's) i MC13 Water Bo'x-Vacuum Pump 1-4404 MC14 Steam Supply Isolation Valve 1-3003A To SJAE A MC15 Steam Supply Isolation Valve 1-3003D To SJAE D NM01 APRM Ch. 1, Gain Adjustment NM02 APRM Ch. 2, Gain Adjustment NM03 APRM Ch. 3, Gain Adjustment l NM04 APRM Ch. 4, Gain Adjustment NMOS APRM Ch. 5, Gain Adjustment NM06 APRM Ch. 6, Gain Adjustment OG01 Recombiner A Inlet Viv 1-5499-76 OG02 Recombiner B Inlet Viv 1-5499-75 And 1-5411A OG03 Setpoint For PC-3041-22A-(PCV-1-5425A1) OG04 Setpoint For PC-3041-22B (PCV-1-5425B1) OG05 .Setpoint For PC-5441-123A (PCV-1-5424A) 2 0G06 -Setpoint For PC-5441-123B-(PCV-1-5424B) OG07 Recombiner Bypass Viv 1-5499-71B OG08 ;Off Gas Drn Trap Inlet Viv 1-5499-283 OG09 Byps Viv 1-5499-71A/Adsorber Outlet V! / 115409-77 Train A Valves 1-5499-73A And 1-5499-74n O OG10
' OG11 Train B Valves-1-5499-73B And 1-5499-74B OG12 Deleted-
' OG13 OG Train A Discharge Isolation Valve 1-5499-72A OG14 OG Train B Discharge Isolation Valve 1-5499-72B 0015 OG Train A Inlet Valve 1-54118
. OG16 Drain Valve-AO-1-540BA OG17 Drain Valve AO-1-5408B-OG18 Bypass Valve Sparge Air-AO-1-4699-249
- 0G19 Bypass Valve Sparge Air AO-1-4699-250 PC01 SBGT Crosstie Valve 1/2-7509' PCO2 Cold-Valve: 8799-85 Reset PC03- Cold Valve- 8799-69 Reset PC04 Fuel Pool Gates PCOS FW To Skimmer Surge Tank Viv 1-1901-12 PC06' Fuel Pool Demin To CCST Viv 1-1901-58
- PC07- Fuel _ Pool Clg.Wtr Pump 1A_ Status PC08 Fuel Pool:Clg'Wtr Pump 1B_ Status PC09 Suppression Pool Conductivity Change Flag (Tie W/CU10)
PC10 Suppression Pool Conductivity Change (Tie W/CUO9) PC11- H2/02 Common Alarm Panel For 901-55 Ack PC12 -H2/02 Common Alarm Panel For 901-56 Ack-PC13 Primary Containment Vent Isolation Bypass (QCOP 1600-3)- PC14. A CAM Hydrogen Concentration Range Switch PC15 A CAM Oxygen Concentration Range Switch V 38 1 L
QUAD CITIES SIMULATOR 1,.bl/ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991
' APPENDIX 2 LIST OF REMOTE FUNCTIONS (RF's)
PC16 B CAM Hy'drogen Concentration Range Switch PC17 B CAM Oxygen Concentration Range Switch RC01 Manual Trip Level on Trip / Throttle Viv For RCIC RCO2 RCIC Fill Line Valve 1-1301-81 RCO3 Trip / Throttle Valve 1-1303-TTV RC04 RCIC Turb Exhaust steam Lino Valve 1-1301-64 RCOS RCIC Test Line Valve 1-1301-53 Motor RC06 RCIC Test Line Valve 1-1301-53 Manual Operation RC07 RCIC Steam Supply Isolation Valve Bypass (QCOP 201-10) RCOB RCIC Steam Supply Valve & Drain Isol Bypass (QCOP 201-10) RC09 RCIC Low Pressure Isolation Bypass (QCOP 1300-10) RC10 High Torus Level Transfer Bypass (QCOP 2300-9) RD01 CRD suction Filter 1-0301-126A/1-0301-1268 RD02 CRD Drive Water Filter 1-0302-4A/1-0302-4B RD03 Flow Control Station 1-0302-6A/1-0302-6B RD04 Charging Header Isolation valve 1-0301-25 RD05 Deleted RD06 Control Rod XX-YY Movement Inop ( ( RD07 RD08 Refueling Interlocks (901-28/281-APA) CRD Suction Filter Bypass 1-0301-163 RD09 CRD Unit 2 Cross Tie 1-0301-164A/B RD10 CRDH HCU over Piston Area Venting RD11 ARI Auto Operation Prevention (QCOP 28) RH01 CCST Suction Valve 1-1001-42A RH02 CCST Suction Valve 1-1001-42B RH03 CCST Suction Valve 1-1001-42C RH04 CCST Suction Valve 1-1001-42D RH05 Fuel Pool Cooling Assist Connection RH06 Discharge To Radwaste Valves 0-2001-85 Etc. RH07 Condensate Xfor Sys Manual Isolation Valve 1-1001-137A RH08 Condensate Xfer Sys Manual Isolation Valve 1-1001-1378 RH09 Condensate Xfer Sys Suction Valve 1-1001-134 RH10 RHR To Head Spray Removable Pipe RH11- Dsch To Cond Pump B Suction Valvo 1-2001-919B RH12 Osch To Cond Pump C Suction Valve 1-2001-919C RH13 Fire Pump Disch Hdr To RHR Valve 1-4199-127 RH14 SDC Outbd Isol Valve MO-1-1001-47 Bkr Status RP01 Removes All Shorting Links From Ch. A And Ch. B RP02 RPS Channel A Power Supply RP03 RPS Channel B Powcr Supply RPO4 Set Low Cond Vac Ris 590101A/D And Remove Fuses 590-7121/D g- RPOS MSIV Trip Signal Relay 590-102A (Fuse 590-702A) 39
t i QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O
- APPENDIX 2 LIST OF REMOTE FUNCTIONS (RF's)
RP06 MSIV Trip Signal Relay 590-102C (Fuse 590-702C) RP07 MSIV Trip Signal Relay 590-102E (Fuse 590-702E) RP08 MSIV Trip Signal Relay 590-102G (Fuse 590-7020) RP09 MSIV Trip Signal Relay 590-102B (Fuse 590-702B) RP10 MSIV Trip Signal Relay 590-102D (Fuse 590-702D) RP11 MSIV Trip Signal Relay 590-102F (Fuse 590-702F) RF12 MSIV Trip Signal Relay 590-102H (Fuse 590-702H) RP13 Load Rej Bypass Relays 590-123 A/D (Fuses 590-726A/D) RP14 RX Low Low Level Bypass Relays 595-100A & C RP15 RX Low Low Level Bypass Relays 595-100B & D RP16 Group 3 Low-Level Isolation Bypass (Jumper For Rly 595-124) RP17 Group 3 Low Level Isolation Bypass (Jumper For Rly 595-123) RP18 Group 2 Iso And RB Vent Iso Bypass (Jumper For Rly 595-133) RP19 Group 2 Iso And RB Vent Iso Bypass (Jumper For Rly 595-134) RP20 Pilot Scrm Solenoid Trip (Fuse 590-715A Removal) RP21 Pilot Scrm Solenoid Trip (Fuse 590-715A Removal) RP22 Pilot Scrm Solenoid Trip (Fuse 590-715C Removal) RP23 Pilot Scrm Solenoid Trip (Fuse 590-715D Removal) RP24 Pilot Scrm Solenoid Trip (Fuse 590-715E Removal) RP25 Pilot Scrm Solenoid Trip (Fuse 590-715F Removal)
/~' RP26 Pilot Serm Solenoid Trip (Fuse 590-715G Removal)
RP27 Pilot Scrm Solenoid Trip (Fuse 590-715H Removal) RP28 EPA Breaker-After MG Set B RP29 EPA Breaker After MG Set A RP30 EPA Breaker On MCC 15-2 To RPS Ch A And B RP31 Removes one Shorting Link From Ch a And One From Ch B RP32 RPS Auto. Scrams (ALL) Bypass (QCOP 28) RR01 Recir Pump A Generator Lockout Relay RR02 Recir Pump B Generator Lockout Relay RR03 Manual Scoop Tube A Operation RR04 Manual Scoop Tube B Operation RR05 Power To Scoop Tube A Switch RR06 Power To Scoop Tube B Switch RR07 Oil Pump C Trip For Recirc MG Set A RR08 Oil Pump D Trip For Recirc MG Set B RR09 Remove MCC 18/19-5 Compt B1 For Viv 1-202-4A RR10 Remove MCC 18/19-5 Compt El For Viv 1-202-4B RR11 A MG Emergency 011 Pump On/Off RR12 B MG Emergency 011 Pump On/Off j SLO 1 Test Tank Injection Lineup SWO1 RBCCW Heat Exchanger 1A In/Out Ot "ervice i SWO2 RBCCW Heat Exchanger 1B In/Out Of Service ' SWO3 RBCCW Heat Exchanger 1/2 In/Out Of Service 40
QUAD CITIES SIMULATOR i ANSI /ANS-3.5 CERTIFICATION REPORT l 1 INITIAL REPORT, KARCH, 1991
'f~
APPENDIX 2 LIST OF REMOTE FUNCTIONS (RF's) SWO4 TBCCW Heat Exchanger 1A In/Out Of-Service SWOS TBCCW Heat Exchanger 1B In/Out of Service SWO6 RBCCW Pump 1/2 Lineup Unit 1/ Unit 2 SWO7 Diesel Generator Cooling Water Pump 1/2 Power Supply SWOB Diesel Generator Cooling Water Pump 1 Power Supply SWO9 Diesel Generator Cooling Water Pump 1/2 Manual Control SW10 Diesel Generator Cooling Water Pump 1 Manual Control i SW11 Diesel Generator Cooling Water Pump Crosstic Valve 1-3399-89 SW12 Service Water To HPCI Room Cooler Valve 1-3399-562 SW13 TBCCW Expansion Tank LCV Dypass 1-3899-94 SW14 RBCCW Expansion Tank LCV Bypass 1-3799-51 SW15 Hydrogen Cooler Isolation Valve 1-3999-114 SW16 TBCCW Isolation Valve 1-3999-39 SW17 Turbine Lube oil Cooler Isolation Valvo 1-3999-25 SW18 MG Lube oil Cooler Isolation Valve 1-3999-56
- SW19 NG Lube Oil Cooler Isolation Valve 1-3999 SW20 RBCCW Isolation Valve 1-3999-69 SW21 RBCCW Isolation Valve 1-3999-72 SW22 RBCCW Isolation Valvo 1-3999-67
- SW23 TCV 1-3903 Set Point SW24 TCV 1-3904A,B Set Point O SW25 SW26 TCV 1-3901 Set Point Vivs 4A,185A Control by Handswitch/ Closed SW27 Vivs 186A,187A Control ByzHandswitch/ Closed SW28 Vivs 4B,185B Control By Handswitch/ Closed SW29 Vlvs 186B,187B Control By Handswitch/ Closed TC01 EHC Fluid' Pump 1A Test Pushbutton TCO2 EHC Fluid Pump 1B Test Pushbutton TCO3 Turbine Mechanical Manual Trip-TC04 E.G.C. Remote Load Reference Input TC05 E.G.C. Pulse Input TC06 Removes. Trip Condition Due To Loss Of 125V DC TC07 Bias on Pressure Circuit A/B
- TU0i Emergency. Bearing 011-Pup Pushbutton TUO2 Main Shaft-Suction-Pump Test Pushbutton TUO3 Turning Gear Oil' Pump Test Pushbutton TUO4 Turbine Supervisory Trip cut-out TU0S Turbine Lift PLmps A,B,C Test-Pushbutton
- TUO6- Turbine Lift Pumps D,E Test Pushbutton i
O u
. . - - ,.-...-----.......--.._,,..,m_.-,.m.,, ~. -._..s.-- - - . - . _ - - . . .. . - . . - , _ _ . . _ . . - - _ - . . _ ,
. _ . _ _.. _ -._ _ _ _ . .. -___..______._______-.__.._..-.___._..__.~..m___>___._
1 I QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991
-APPENDIX 3 LIST OF ACRONYMS /ADDREVIATIONS
- This Appendix lists common acronyms / abbreviations used at Quad cities Station and on the Quad cities Simulator project.
O O o
00AD CITIES SIMULATORION 1991 REPORT ANSI /ANS-3.5 CERTIFICATINITIAL REPORT, APPENDIX 3 ATIONS LIST OF ACRONYMS /ABBREVI LCR2LLML DIEELP119R. i hD11TS1kTlD11 Automatic Depressurizat on Acceptance Test Procedure AD Beginning of Cycle Storage Tank ATP BOC Beginning of LifeContaminated Condensate BOL CCST Reactor Core CR Core SprayReactor Water Cleanup [ CS CU/RWCU Direct Current in Diesel Generator DC Estimated Critical Posit o DG ECP Electrical Distribution l ED EG Electrical End of Cycle GeneratorEconomic Gen EGC EOC End of Life EOL Flow Control Line FCL Fire Protection ncy Plan FP Feedwater Generatina Station Emergetion G FW GSEP HC Hydrogen Liter ChemistryHigh Prensu HP Heat ExchangerHeating ventilation HX HV Hardware HW Instrument Air IA Initial Condition IC Kilovolts jection KV Licensee Event ReportLow Pressure C LER LPCI Main Condenser of Cycle MC Middle Middle of Life MOC MOL Main SteamMegawatt Electrical MS Neutron Monitoring MW/MWE On Demand NM OD Off Gas OG Out of Service OOS Public Address PA Primary ContainmentProcess Interface PC PIU 43
~.. . .. N.. -
. . - .. ._._ _ -.=.- . .- . . . _ - - . . _ .
QUAD CITIES SIMULATOR
- ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991
\
APPENDIX 3 LIST OF ACRONYMS / ABBREVIATIONS ACRONYM / ABBREVIATIMI DIFCRIPTION AD Automatic Depressurization ATP Acceptance Test Procedure , BOC Beginning of Cycle BOL Beginning of Life CCET Contaminated Condensate Storage Tank CR Reactor Core C3 Core Spray CU/RWCU Reactor Water Cleanup DC Direct Current DG Diesel Generator ECP Estimated Critical Position ED Electrical Distribution EG Electrical Generator EGC Economic Generation Control EOC End of Cycle EOL End of Life FCL Flow Control Line (~T FP Fire Prctection (_) FW Feedwater GSEP Generatina Station Emergency Plan HC Hydrogen Water Chemistry HP High Pressure Coolant Injection HX Heat Exchanger HV Heating Ventilation HW Hardware
-IA Instrument Air IC Initial Condition KV Kilovolts LER Licensee Event Report LPCI Low Pressure Coolant Injection MC Main Condenser MOC . Middle of Cycle MOL Middle of Life MS Main Steam MW/MWE Megawatt Electrical NM Neutron _ Monitoring OD .On Demand OG Off Gas OOS Out of Service PA Public Address PC Primary Containment Pld Process Interface Unit
(}'
\ 43 l
l l 1 L H
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT ILITIAL REPORT, KARCH, 1991 APPENDIX 3 LIST OF ACRONYMS / ABBREVIATIONS ACRONYM / ABBREVIATION DESCRIPTION PTAO Production Training Administrative Proc dure - >perations QC Quaw Cities QGP Quad Cities General Operating Procedures RC/RCIC Reac,*:or Core Isolation Cooling RD/CRD Control Rod Drive RH/RHR Residual Heat Removal RM Radiation Monitoring RP/RPS Reactor Protection RR Reactor Recirculation S/D Shutdown SCRE Shift Control Room Engineer SL/SBLC Standby Liquid Control Sys:em SW Service Wat#!r TBCCW Turbine Bull. ding Closed Cooling Water TC Turbine Cortrol TU Turbine O UF UV Under Frequency Under Voltrage WR Wide Range / Work Request YC Plant Procuss Computer XE Xenon XFMR Transformer s O 4.
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 APPENDIX 4 TRANSIENT REVIEW BOARD
- The baseline data used for the transient tests evaluation was the judgement of a panel of experts. This Appendix includes the makeup and qualifications of the transient review board.
The results of each transient test review can be found in Attachment 2.
- This review board also analyzed the Steady State Test results.
The results of these test reviews can be found in Attachment 2. 45
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 ('- APPENDIX 4 TRANSIENT REVIEW BOARD Members _Qwltlifications Chris Symonds Po-ition - Quad Cition Simulator L censed TR-1 thru TR-10 Operator Instructor SS-1 Background - SRO Certification - Quad Cities (3 yrs.)
- Simulater Instructor - LaSalle (4 yrs.)
- SRO Certification - LaSalle (3 yrs.)
- Navy - EWS (6 yrs.)
Jeff Kopact Position - Unit 2 Operating Engineer TR-1 thru TR-10 Background - SRO Licensed 1984 Quad Citie9 Tech Staff - Quad Cities (3 yrs.) operating - Quad Cities (4 yrs.)
- Maintenance Staff - Quad Cities (1 yr.)
- Tech Staf f Engineer - Quad Cities .
(4 yrt.) f] v - BSME University of Notre Dame 1977 Brian Strub Position - Tech Staff System Engineer TR-1 thru TR-10 Supervisor SS-1 Background - SRO Licensed 1984 Quad Cities
- Operating Engineer - Quad Cities (4 yrs.)
- Tech Staf f - Quad Cities (8 yrs. )
- BS Iowa State University 1975
- MS Iowa State University 1977 Mike Swegle Position - Quad Cities Licensed Operator TR-1 thru TR-10 Instructor SS-1 Background - SRO Certification - Quad Cities (4 yrs.)
- Licensed operator Instructor Quad Cities (2 yrs.)
- Non Licensed operator Instructor Qv d cities (2 yrs.)
- Radwaste Foreman - Quad Cities (2 yrs.)
- Non Licensed operator Quad Cities (2 yrs.)
46
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, HARCH, 1991 \- APPENDIX 4 TRANSIENT REVIEW BOARD Members Oualifications Tim Schares Position - Quad Cities operations Training TR-1 thru TR-10 Group Leader SS-1 Background - SRO Licensed - Quad Cities (4 yrs.)
- SRO Licensed Instructor - Quad Cities (4 yrs.)
- Maintenance Training Group Leader (1 yr.)
- Instructor General Training (1 yr.)
- Navy - RO, RT, EWS/EOOW (8 yrs.)
John Hoeller Position - Quad Cities Training Supervisor TR-1 thru TR-10 Background - SRO Licensed - Quad Citics SS-1 - Assistant Tech Staff Supervisor (2 yrs.)
- Shift Foreman - Quad Cities -3 (1 yr.)
y - Lead Nuclear Engineer - Quad Cities (2 yrs.)
- Technical Staff - Quad Cities (10 yrs.)
Roger Braddy_ Position - Quad Cities Simulator Fidelity / TR-1 thru TR-10 Certification Coordinator SS-1 Background - SRO Certification - Quad Cities (3 yrs.)
- PTD Principal Simulator Instructor (1.5 yrs.)
- License Training Staff - Quad Cities (4 yrs.)
- SRO Licensed Shif t Foreman - Quad Cities (1 yr.)
- Non-licensed Operator Training Quad Cities (2 yrs.)
- Navy - E00W/EWS (10 yrs.)
47
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O APPENDIX 5 ANSI /ANS-3.5-1985 CERTIFICATION REPORT CROSS REFERENCE MATRIX
- This Appendix is a cross reference of ANSI /ANS-3.5-1985 requirements and the location in this report of the applicable section(s) that satisfies each requirement.
O O 4.
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 APPENDIX 5 ANSI /ANS-3.5-1985 CERTIFICATION REPORT CROSS REFERENCE KATRIX ANSI /ANS-3.5-1985 LOCATION IN CERTIElCATION TEQHIRrJiENT REPORT SECT DESCRIPTION SECTION 3.1.1 Normal Plant Evolutions A.3.2, Att. 2 3.1.2 Plant Malfunctions A.1.3.2, A.3.4, Att. 7 3.2.1 Degree of Panel Simulation A.1.2.2, Att. 6 3.2.2 Controls on Panels A: 1,2.2 3.2.3 Control Room Environment A.1.2.1, A.1.2.4 3.3.1 Control Room Systems A.1.2.3 3.3.2 System Operation Outside Control Room A.1.3.3, App. 2 3.4.1 2nitial Conditions A.1.3.1, App. 1 3.4.2 Malfunctions A.1.3.2 3.4.3 Other Control Features A.1.3.4 3.4.4 Instructor Interface A.1.3.-3, App. 2 4.1 -Steady State Opei*ation A.3.2, Att. 2 4.2 Transient Operation A.1.3.2, A.3.2, A.3.3, Att. 2 4.3 Simulator Operating Limitt, A.3.4 4.4 Monitoring Capability Att. 2 5.1 Simulator Design Data A.2 5.2 Simulator Update Design Data A.1.5, A.4.2 5.3 S4'ulator Modifications A.1.5, A.4.2 1 49
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 - APPENDIX 5 ANSI /ANS-3.5-1985 CERTIFICATION REPORT CROSS REFERENCE MATRIX ANSI /ANS-3.5-1985 LOCATION IN CERTIFICATION REOUIREMENT REPORT SEqI DESCRIPTIO1{ SI&IlQ1{ 5.4.1 Simulator Performance Testing A.2, Att. 2 5.4.2 Simulator Operability Testing A.2, A.3.2, Att. 2 ILQIE ' APPENDIX A, GUIDE FOR DOCUMENTING SIMULATOR PERFORMANCE, WAS UTILIZED AS THE FORMAT FOR THIS REPORT. THEREFORE, APPENDIX A CROSS-REFERENCE MATRIX DATA UILL NOT BE LISTED. B.2.1 Steady State Performance A.3.2, Att. 2 /~'} '% / B.2.2 Transient Performance A.3.2, Att. 2 O 50 1
l QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O O APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE
- This Appendix lists the malfunctions that are being submitted for certification. Approximately 25% of those malfunctions will be tested each year.
Q U 51
QUAD CITIES SIMULATOR-ANSI /ANS-3.5 CERTIFICATION REPORT li'ITI AL REPORT, M ARCH, ' 1991 - O APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHPDU!I 4 ANNUAL TESTING PERIOD MALP MALFUNCTION 3/91- 3/92- 3/93- 3/94-HO.- DESCRIPTION , 3/92 3/93 3/94 3/95 AD01 Relief Valve Setpoint Drift X s AD02 Relief Valve _ ADS Solenoid-Fail X AD03 ADS 110 Second Timer Fails To Start- X 3 AD07 Relief Valve Sticks X CRO1 Fuel Element Failure X CR02 Gross. Fuel Element Failure X CSO1 Core Spray Pump Trip X CSO2 Core _ Spray Pump Reduced Capacity X 0503 Core Spray Injection Valve Fails
-To Auto Open: _
X CSO4_ Core Spray-Logic Fails To Initiate X CS07 Core SprayJInjection Valve Binding X () -CUO1 CUO3 RWCU Pump Trip RWCU System Leak At Regen Heat X Exchanger Inlet X DG01 Diesel Gen Trips-And Locks Out X DG02 Diesel Gen. Output Breaker Trip X DG03 Diesel Engine Fails To Start- X DG04 Diesel Engine Auto _ Start Failure X ED01 345 KV-Switchyard Breaker Trip X ED02 Loss Of Reserve Auxiliary Transformer X ED03 4.16 1. BUS Failure X
'ED04- 4.16 KV--Breaker Fails To Close X EDOS 480 VAC BUS Failure- X ED06 -480 VAC Breaker Fails To Close X ED07 480.VAC' BUS Tie-Breaker Trip X ED09 .120/240 VAC Instrument BUS Failure X ED10 120/240 VAC-Essential Service BUS Failure X ED12 250 VDC'MCC Failure X ED13- 125 VDC BUS Failure X ED14 48/24-VDC BUS Failure X O 52
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 lD \_/# APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE ANNUAL TESTING PERIOD MALF MALFUNCTION 3/91- 3/92- 1/93- 3/94-NO. DESCRIPTION 3j92 3/93 1/94_ 3 /_EE_ EG01 Main Generator Trip X EG02 Main Generator Lockout Relay Fails To Trip X EG04 Main Generator Stator Coolant Runback Failure X EGO 5 Main Generator Stator Coolant Pump Trip X FP01 Diesel Fire Pump Trip X FWO1 Reactor feed Pump Trip X FWO2 Standby Reactor Feed Pump Auto Start Failure X FWO3 Reactor Feed Pump Fails To Auto Trip X FWO4 Reactor Feed Pump Reduced gs Capacity X ( FWO6 Reactor Feed Pump Flow Transmitter Failure X FWO7 Feedwater Level Control Valve Failure X FWO8 Feedwater Level Centrol Valve Lock Up X FWO9 FW Line Rupture Inside The Drywell Before The Check Valve X FW10 FW Line Rupture Inside The Drywell After The Check Valve X FW11 FW Line Rupture Outside The Drywell In The Steam Tunnel X FW12 FW Line Rupture Outside Drywell At FW nog Valve Inlet X FW14 LP FW Heater Al Tube Rupture X FW15 LP FW Heater B Tube Rupture X FW16 HP FW Heater D Tube Rupture X FW17 Coi.densate/ Condensate Booster Pump Trip X FW18 Condensate Booster Pump Reduced Capacity X FW19 Condensate Pump Reduced Capacity X 53
QUAD CITIES 9IMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991
.N APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE ANNUAL TESTING PERIOD MALF MALFUNCTION 3/91- 3/92- 3/93- 3/94-NO. DESCRIPTION 3/92 3/93 3/94 3/95 FW21 Hotwell Makeup Control Valve Failure X FW22 Hotwell Reject Control Valve Failure X HP01 HPCI Turbino Trip X HP02 HPCI Turbine Fails To Auto Trip X HP03 HPCI Main Pump Reduced Capacity X HPO4 HPCI Minimum Flow Valve Fails To Auto Open X HP09 HPCI Flow Controller Failure X HP10 Inadvertent HPCI Initiation X HP11 HPCI Failure To Initiate X HP13 HPCI Steamline Rupture Inside The HPCI Room X HP14 Group Four Isolation Actuation X HP15 Group Four Isolation Fails s To Actuate X HP16 Safe Shutdown Pump Trip X HP17 HPCI Injection Valve Binding X HV01 Reactor Building Ventilation Fails To Auto Isolato X IA01 Instrument Air Compressor Trip X IA02 Reactor Building Instrument Air
- System Rupture X IA03 Service Air To Instrument Air Backup Failure X IA04 Turbine Building Instrument Air System Rupture X IA05 Scram Air Header Leak X IA07 Drywell Nitrogen Compressor Trip X IA08 Drywell Nitrogen System Leak Inside The Drywell X MC01 Circulating Water Pump Trip X MCO2 Circulating Water Pump Discharge Valve Fails To Open X l
l ['N, - 54 l
- _ , . .. - , _ - , . . - _ . . . , , _ . . . ~ . ~ .
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 (~ k- APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE ANNUAL TESTING PERIOD MALF MALFUNCTION 3/91- 3/92- 3/93- 3/94-NO. DESCRIPTION 3/92 3/93 3/94_ 1/3fg_ - MCO3 Circulating Water Pump Discharge Valve Fails To Closo X MC04 Main Condenscr Tube Sheet Blockage X MC07 Main Condenser Tube Leak X MCOP Main Condenser Air Inleakage X MC09 SJAE Regulator Failure X MC10 SJAE Suction Valve Fails Closed X MC11 SJAE Suction Valve Fails To Auto Close X MS01 Main Steam Isolation Valve C.csure X MSO2 Main Steam Isolation Valve Falls To Close X MS03 Main Steam Isolation Valve Slow Closure Time X MS05 Main Steamline Break Inside Drywell After Restrictor X O. MS06 MSO9 Relief Valve Seat Eroded Main Steamline Break In The Steam X Tunnel X MS10 Main Steam Leak In The Turbine Building X MS12 Loss Of Extraction Steam To LP FW Heater B X MS13 Loss of Extraction Steam To LP FW Heater C X MS14 Loss Of Extraction Steam To HP FW Heater D X MS16 Relief Valve Tailpipe Break In The Suppression Chamber X HM01 SRM Channel Failure X NM02 Flow Converter Failure X NM03 SRM Detector Stuck X NMOS IRM Channel Failure X NM06 IRM Channel Out Of Calibration X NM07 IRM Detector Stuck X NM08 APRM Channel Failure X NM10 RBM Channel Failure X O 55
1 QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT l INITIAL REPORT, KARCH, 1991 APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE ANNUAL TESTING PERIOD K .LP MALFUNCTION 3/91- 3/92- 3/93- 3/94-NO. DESCRIPTION 3/9.2 3/93 3/94 3/95___ NM14 LPRM Detector Failure X PC01 Drywell Cooler Blower Trip X PC04 Drywell Vacuum Breaker Fails Open X PC07 Suppression Pool Flange Leak X PCOB Standby Gas Treatment Fan Trip X PC09 Standby Gas Treatment Fan Falls To Auto Start X PC11 Standby Gas Treatment Flow Controller Failure X RC01 RCIC Turbine Mechanical Trip X RCO2 RCIC Turbine Electrical Trip X RC04 RCIC Turbine Failure To Auto Start X RC05 RCIC Pump Reduced Capacity X RC06 RCIC Flow Controller Failure X RC07 RCIC Injection Valve Fails To Auto {')s x, Open X RC10 RCIC Isolation Valve Binding X RC11 RCIC Steamline Rupture At Turbine Inlet X RC12 Group Five Isolation Actuation X RC13 Group Five Isolation Falls To Actuate X RC14 RCIC Injection Valve Binding X RD01 Control Rod Uncoupled X RD02 Control 9od Stuck X RD03 Control Rod Drift In X RD04 Control Rod Drift Out X RDOS Control Rod Scram X RD06 Control Rod Accumulator Trouble X RD07 CRD Hydraulic Pump Trip X RD08 CRD Hydraulic Pump Reduced Capacity X RD13 Scram Disch Volume Hydraulic Lock X RD22 Manual Alternate Rod Insert Circuit Failure X RD23 Scram Disch Volume Drain Valves Stick Open X v 56
QUAD CITIES. SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT. INITIALfREPORT, MARCH, 1991 APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE ANNUAL TESTING PERIOD. EMALF . MALFUNCTION 3/91- 3/92- 3/93- 3/94-
-NO. DESCRIPTION 3/92 3/93 3/94' 3/95 RH01 ;RHR Pump Trip- X RH02 RHR Pump Reduced Capacity X RH03- IUIR Inboard Injection Valve Fails To Auto Open X; RH06 RHR Logic Fails TofInitiate X RH071 RHR Injection Valve Binding X RH08' RHR Minimum Flow Valve Binding X RM01- Area Radiation Monitor Failure X RM02 Process Radiation Monitor Failure X RP02 Auto Scram Circuit Failure X RP03 Manual-Scram-Circuit Failure X RPO4 RPS MG Set Trip X RP05 Group.One Isolation-Actuation ~
X RP06 Group One Isolation Fails
-To Actuate X O RP07- Group Two Isolation Actuation RP08 Group Two' Isolation Fails X
To Actuate X RP09 Group Three Isolation Actuation X RP10 Group Three Isolation Fails To. Actuate X. RR01 Recirc Pump Drive Motor Breaker Trip X RR02 Recirc Pump Field Breaker Trip X
-RR04 Recirc Pump Reduced Capacity X RR06 Recirc Pump Inboard Seal Failure X RR07.:Recirc Pump Outboard Seal Failure X RR08 Master Recirc Flow Controller Failure X RR09 Recirc Pump _ Speed Signal Failure .X ERR 10 Recirc LoopfSuction Pipe Rupture X RR11-_Recirc Loop Discharge l Pipe Rupture X RR12 Reference Leg Pipe Rupture At RPVLNozzle X RR13 Variable, Leg-Pipe Rupture At RPV Nozzle X
, RR14 Rec'irc. Loop Flow: Transmitter Failure X 57 i l ^
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE ANNUAL TESTING PERIOD MALF MALFUNCTION 3/91- 3/92- 3/93- 3/94-NO. DESCRIPTION 3/92 3/93 3/94 3/95 RR15 FW Level Control Level Transmitter Failure X RR16 FW High Level Trip Level Instrument Failure X RR17 Analog Trip System Level Transmitter Failure X RR18 ECCS Level Instrument Failure X RR19 ATWS Level Transmitter Failure X RR20 Fuel Zone Level Transmitter Failure X RR21 ATWS Pressure Transmitter Failure X RR23 RX Level Press Compensator Press Transmitter Failure X RR25 RHR 100 psig Interlock Fails Low- X RR26 RHR 100 psig Interlock Fails High X SLO 1 SBLC Pump Trip X SLO 2 SBLC Pump Disch Line Relief Valve O Fails Open X r SWO1 Service Water Pump Trip X SWO3 Recirc MG Set Oil Cooler Service Water Flow Blockage X SWO4 RHR Service Water Pump Trip X SWO5 RHR S-tvice Water Pump Reduced Capacity X SWO6 RBCCW Pump Trip X SWO7 RBCCW Pump Reduced Capacity X SW11 TBCCW Pump Trip X SW12 TBCCW Pump Reduced Capacity X SW15 Diesel Generator Cooling Water Pump Trip X TC01 Main Turbine Trip X TCO2 Main Turbine Auto Trip Logic Fails To Actuate X TC05 EHC Pump Trip X l TC06 Main _ Turbine Stop Valve Falls Open X
- TC07' Main Turbine Stop Valve Fails i
Closed X l TC08 Main Turbine Control Valve Failure X i i l I)
\' 58 l
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, KARCH, 1991 APPENDIX 6 PROPOSED SIMULATOR MALFUNCTION TEST SCHEDULE ANNUAL TESTING PERIOD MALF MALFUNCTION 3/91- 3/92- 3/93- 3/94-NO. DESCRIPTION 3/12 3/93 3/94 3/95 TC09 Main Turbine Bypass Valve Failure X TC11 EHC Pressure Regulator Failure X TUO1 Main Turbine Journal Bearing High Temperature X TUO2 Main Turbine Journal Bearing High Vibration X TUO4 Main Turbine AC Oil Pump Trip X TU0S Main Turbine AC Oil Pump Falls To Auto Start X TUO6 Main Turbine DC 011 Pump Trip X TUO7 Main Turbine DC Oil Pump Falls To Auto Start X 59
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 x. '- ATTACHMENT 1 REG GUIDE 1.149 REQUIREMENTS FOR DUAL PIANT SIMULATION FACILITY Comparison of the Quad Cities Simulator to Quad Cities Unit 2. lJ N O 60 W7-ew v5s y e m y-- -- c e y
QUAD CITIES SIMULATOR:
-ANSI /ANS-3.5 CERTIFICATION REPORT- ;
INITIALJREPORT, MARCH, 1991 g '
\- .
Attachment i demonstrates that the Quad Cities-
*f Simulator meets the requirements and guidance of ANSI /ANS-3.5 l
-1985-for Quad Citiec Unit 2.
Tho' simulator' design' database is maintained from Quad. Cities Unit i data. No database is maintained for Quad Cities. Unit 2, however all deviation reports (DVR's), LER's'and modifications are reviewed by the Quad cities simulator Staf f. Quad Cities Unit'2-DVR's,and Quad Cities Unit 2 LER's'can be found in the General Files, Simulator (SIM) file. A summary of the 1989 and-1990 Quad Cities Unit 2 LER's that were determined to effect simulation'follows: LEB. DESCRIPTION COMMENTS 90-004 Loss of feed to 23-1 from LER tested satisfactorily. BUS 23.- LER added'to Malfunction DVR-04-02-90-007 Cause and Book. 90-005 GroupEII isolation,HRX Bldg' LER tested satisfactorily. vent-trip and auto start of LER added to Malfunction "B"7SBGTS. Cause and Effect Book. DVR-04-02-90-010 006 .RCIC inoperable. LER tested satisfactorily. $ DVR-04-02-90-023 LER added to Malfunction Cause and Effect-Book. 90-010- Unit Two RX scram due to LER tested satisfactorily, turbine trip from 2C LER added-to Malfunction moisture separator high Cause-and-Effect Book.
' level.
DVR-04-02-90-053 NOTE Quad Cities utilizes the same procedures-for operating both Units 1 and 2. A' copy of these procedures is kept on each unit. An analysis and summary of the differences between each-plant and the-Quad Cities Simulator including f acility design, oystems relevant to control room personnel, control room design, _ and instrument / control location are- presented in~ this section of the report.
-61
-QUAD CITIES SIMULATOR ANSI /ANS-3.5' CERTIFICATION REPORTE INITIAL REPORT,:KARCH, 1991 .g General comments:
- 1. Many recorders on the simulator are Yokogawa's, while
' the-plant uses the obsolete General Electric type. To
~
avoid repetition and unless otherwise noted the differences between the two are listed below:
- a. Yokogawa recorders have a digital display along with the analog display, while the General Electric recorders have the analog' display only.
Modification number MC-4-1-90-123.
- b. Yokogawa recorders have a digital bar along the-meter face while the General Electric recorders have a colored arrow head (color matches ink color). Modification number MC-4-1-90-123.
- c. Yokogawa recorders ink colors are red and green while the General Electric recorder ink colors are red and black. Modification number MC-4-1-90-123.
NOTE Modification MC-4-1-90-12371s an on-going ,
-s .
modification to replace reference plant > recorders with Yokogawa's.-The reference plant modification is scheduled to be completed in two yeare.
- 2. Panel" inserts (drop in panels) on the simulator are put together almost exclusively with phillips-head-screws, while the; panels in'the plant are held together almost exclusively with standard head screws.
- 3. Many panelssin the plant:have-plates mounted =on them with recorders or controls mounted on them. The
-simulator did=not model all of these plates.
4 4.1 Unit 2 control. boards are arranged-in.a mirror image
-patternato Unit 1 control boards. This may initially appear as a najor operational impact except that the control boards are laid out left-to-right the same on both' units. There are a few' exceptions to this rule with the 901(2)-5 be.ing the most obvious.
J 62
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 O k/ Differences between the Quad Cities simulator and the Quad. Cities Units 1 and 2 control room are:- Unit 1 Mnit 2 Simulator
- 1. The 1/2 diesel The 1/2 diesel Simulator agrees with generator can be generator can be Unit 1.
started from panel controlled from 901-8 only, panel 902-8.
- 2. Unit i has level Unit 2 does not have Simulator agrees with indicators for indications for Unit 1.
contaminated contaminated condensate storage condensate storage tanks. tanks.
- 3. Unit 1 pushbutton is RCIC turbine reset Simulator agrees with located on panel pushbutton on panel Unit 1.
901-4 vertical center 902-4 is lower on portion of the panel. the vertical panel than Unit 1.
- 4. Temperature Temperature Simulator agrees with indicator does not indicator 1/2-914, Unit 1.
!(,}/
exist on Unit 1. river temperature exists on panel 902-19.
- 5. This equipment does Fire system typer Simulator agrees with not exist on Unit 1. and security Unit 1.
computer typer are located at the end of the Unit 2 typer table.
- 6. Unit 1 has Unit 2 has Simulator agrees with indication for both indication for a Unit 1.
off gas drain line single off gas drain isolation 5408A and line isolation valve 5408B valves. (5408).
- 7. Unit 1 A Core Spray Unit 2 "A" and "B" Simulator agrees with l testable check valve Core Spray testable Unit 1.
L has three indicating check valves have l lights The "B" Core two indicating i Spray testable check lights. has two indicating lights. l (' ' 63 l l l
QUAD CITIES SIMULATOR-ANSI /ANS-3.5. CERTIFICATION REPORT
-INITIAL REPORT, MARCH, 1991- 1
- 8. Phone-radio is not- GSEP voice-d'spatch Simulator agrees with present on Unit.1. radio-la 'c0ated on Unit 1. H 7 the center unit two wing.
Simulator agrees 1with I ! 9) .PPC points for met- PPC points for met tower wind speed and -tower wind speed and Unit 1. wind direction not wind direction can available, be obtained from Unit 2_onli.
- 10. Plant emergency Plant emergency Simulator agrees with a siren panel is siren panel does not -Unit 1.
physically located exist on Unit 2. on Unit 1.
- 11. '901-8 panel extra 902-8 panel is- Simulator-agrees with space is taken up in physically about one Unit 1.-
meter spacing, foot narrower than-the-901-8 panel.
- 12. Cabinet does not- A lockable file Simulator agrees with !
exist on Unit 1. cabinet, containing Unit 1. emergency equipment such as electrical O -jumpers and keys, is located behind the Unit 2 typer-table. 13.- 901-55 and 901 902-55 and 902-56 -Simulator agrees with panel stand alone. panel are an Unit 1. extension of the common panel-row. The differences listed above #1 through #13 -are not considered significant with little or nofimpact on training, and are not scheduled-for correction. 64
QUAD-CITIES' SIMULATOR d ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT,-MARCH, 1991 i O- LThe{following annunciator-tile descriptions differ from
- Unit .1 to Unit 2- but -do- not have an impact .on training. TM - !
simulator annunciator tile descriptions agree with Unit 1. ;
- 9 01 ( 2 ) -3 . 'A-16 Unit-1~ PRIM CONT HIGH PRESSURE Unit 2 TIP BALL VLV OPEN/ GROUP 2 SIGNAL i 901(2)-3 C-1 i
--Unit 1 NEW FUEL STG HI RADIATION Unit 2- SPARE ,
-901(2)-3 E-1 '
Unit 1 RADWASTE-BLDG HI RADIATION Unit 2 AREA MONITOR'DOWNSCALE
-901(2)-3'F-1 JUnit 1 ARE MONITOR DOWNSCALE.
--Unit 2: FILTER HOUSE HI RADIATION l 901(2)-3'F-7
~
Unit 1 CONTROL ROOM HI RADIATION Unite 2 SPARE i () 901(2)-3 F-8 Unit.1 Unit 2 TIP BALL VLV OPEN GRP 2 SIG SPARE i
'901(2)-3 F-14.
Unit 1 SPARE Unit 2 HPCI LO FLOW AND MGU NOT AT HSS 901(2)-3_G-7. Unit l' RHR' PUMP AREA CLR FAN TRIP . . Unit-;L RHR ROOM CLR TROUBLE
-901(2)-3-H-7
- Unit-1 RHR' PUMP AREA HIGH TEMP j Unit-2 'RHRJPUMP AREA HI TEMP-901(2)-41A-12.
Unit 1 RWCU LEAK DETECTION "A":HIGH TEMP , Unit-2 SPARE
,901(2)-4 A-18 Unit 1- SPARE Unit 2 'COND BACKWASH TANK 2 HIGH LEVEL r LO e5 i-
QUAD CITIES SIMULATOR.
- ANSI /ANS-3.5 CERTIFICATION' REPORT INITIAL REPORT, KARCH, 1991 O '901(2)-4-B Unit 1 TURB' AIR CO MONITOR UNIT 1/2
- Unit 2 SPARE 901(2)-4"C-3
- . Unit-1 RECIRC PUMP A HI' VIBRATION Unit 2 LRECIRC PUMP A-HIOH VIBRATION 901(2)-4 C-22 Unit 1 FUEL POOL' FILTER DEMIN A LOW FLOW Unit 2 FUEL POOL DEMIN FILTER A LOW FLOW
-l 901(2)-4 C-23 Unit 1 FUEL POOL FILTER DEMIN A HIGH D/P
. Unit 2 . FUEL POOL FILTER-DEMIN A HIGH DP 901(2)-4.D-5, Unit:1 SPARE-Unit 2- "B" RECIRC MG SET. FIELD BRKR OPEN 901(2)A4'D-19
-Unit-1 .0FF GAS' FILTER. BLDG VENT CAM
~!
Unit'2 SPARE
- 901(2)-4 D-22 ff)')
1
%. . Unit:1- FUEL POOL FILTER DEMIN B LOW FLOW Unit 2- FUEL POOL'DEMIN FILTER'B-LOW FLOW 901(2)-4 D-23 .
Unit 1 FUEL 1 POOL FILTER DEMIN B HIGH D/P' Unit 2 FUEL POOL FILTER =DEMIN B HIGH DP-
- 9 01 ( 2 ) E
- Unit ~1= 'B RECIRC MG SET FIELD BREAKER OPEN' Unit 2: SPARE 901(2)-4EE Unit.1 SPARE Unit 2 PRIM CONT HI PRESSURE 9 01 ( 2 ) -41 H-3 _ _ _ _ _ _ _ _ _
Unit 1 .A-RECIRC MG SET FIELD-BREAKER OPEN Unit 2- SPARE 901(2)-4.H-17 Unit li-SPARE Unit 2 ' VALVE LEAK DETECTOR SYS HIGH-. TEMP o- 66
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, HARCH, 1991 r . \/ 901(2)-4 H-21 Unit 1 RADWASTE ALARM PWR FAIL ! Unit 2 SPARE 901(2)-5 D-4 Unit 1 ATWS CHANNEL A OR B TROUBLE Unit 2 REFUEL BRIDGE ROD BLOCK 901(2)-5 D-12 Unit 1 ALARM POTENTIAL FAILURE Unit 2 ALARM POTENTIAL F-23 FAILURE 901(2)-5 F-3 Unit 1 REFUEL BRIDGE ROD BLOCK Unit 2 SPARE 901(2)-5 H-2 Unit 1 SPARE Unit 2 ATWS CHANNEL A OR S TROUBLE 901(2)-6 G-4 Unit 1 REC STG BLDG TROUBLE Unit 2 SPARE 901(2)-7 A-10 Q(_/ Unit 1 Unit 2 STEAM SEAL BYPASS LINE HIGH PRESSURE BYPASS TO STEAM SEAL HIGH PRESS 901(2)-7 C-1 Unit 1 CONDENSER FLOW REVERSING VLVS ON LOCAL CONTROL Unit 2 SPARE I 901(2)-7 C-2 Unit 1 CONDENSER FLOW REVERSING 2ND HALF INCOMPLETE Unit 2 SPARE 901(2)-7 C-13
*Jnit 1 OFF GAS IIIGH FLOW Unit 2 SJAE TO OFF GAS HIGH FLOW 901(2)-7 D-11 Unit.1 H2 SUPPL 7 LINE HIGH FLOW Unit 2 HYDROGEN SUPPLY LINE HIGH FLOW 901(2)-7 D-12 l Unit 1 CLAND STEAM CON DRN HDR 1B LOW LEVEL l Unit 2 GLAND STEAM CON DRN HDR 2B LOW LEVEL 67
~ _ _- _ . _ . . . . - _ _ . _ -_ . . . _ _ _ _ _ _ . . . _ . . . . _ . . .
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT,' MARCH, 1991 D ' 901(2)-7~E-6 Unit 1 EHC FLUID PUMP AUTO START Unit 2- EHC FLUID PMP AUTO START 901(2)-7'E-8 ' Unit 1~- TURBINE OIL STORAGE ROOM FIRE-
-Unit 2 SPARE 901(2)-7 E-14 Unit 1 MEZZ' AREA FIRE Unit 2 BOOSTER AIR EJECT 9R 2 A STEAM LOW PRESS 901(2)-7 F-2 Unit'1 COND FLOW REV1VLV CONT PWR FAILURE Unit 2 COND FLOW REV VLV CONT PWR FAIL
- 901(2)-7 F-8
-Unit 1 TURBINE OIL STORAGE-ROOM WTR-VLVS CLOSED Unit 2 SPARE 901(2)-7 F-13 Unit l' SPARE
-Unit 2 .SJAE LIQUID DRAIN 2B HIGH LEVEL A 901(2)-7.F-14
'is,/' _ Unit ^1- MEZZ AREA FIRE PROT VLV CLOSED -
Unit-2 BOOSTER AIR EJECTOR 2B STEAM LOW PRESS 901(2)-7 G-15 Unit 1 BOOSTER AIR EJECTOR 1A STEAM LO PRESS Unit 2 SPARE 901(2)-7 G-16 Unit 1--DIESEL 1/2 DAY TANKzRM FIRE Unit 2 -SPARE 901-(2)-7'H-1 , Unit 1 - WAREHOUSE SPRINKLER SYSTEM' ALARM Unit.2 .COND FLOW REV VLVS LOCAL CONT 901(2)-7.H-2 Unit 1 ' SPARE Unit 2 COND FLOW REV 2ND HALF INCOMPLETE-901(2)-7. H-13 Unit 1 SPARE Unit.2 SJAE LIQUID DRAIN 2B LOW LEVEL i O 68 L +
. . . - . . , w , , - , - . , , - - ,
- , , . . . - - - - + , , , , . ,,, , , - - , - ~ , , , . _ . . . .
. - ,,.n ,
QUAD CITIES SIMULATOR ANSI /ANS-3,5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 i
'/ '- 901(2)-7 H-15 Unit 1 DILUTION STEAM TO B OFF GAS TRAIN LOW PRESS Unit 2 SPARE 901(2)-7 H-16 Unit 1 DIESEL 1/2 DAY TANK RM FIRE PROT VLV CLOSED Unit 2 SPARE 901(2)-8 A-4 Unit 1 DIESEL GEN 1/2 TROUBLE Unit 2 SPARE 901(2)-8 B-4 Unit 1 DIESEL GEN 1/2 AUTO START OR AUTO START BLOCK Unit 2 SPARE 901(2)-8 C-4 Unit 1 DIESEL GEN 1/2 FAIL TO START Unit 2 SPARE j l
901(2)-8 C-8 Unit 1 DIESEL GEN 1 STORAGE TANK LOW LEVEL l Unit 2 125V BATTERY CHARGER 2A TRIP /~ 901(2)-8 D-4 (,,N/ Unit 1 DIESEL GEN 1/2 NEUT VOLT Unit 2 SPARE 901(2)-S D-8 Unit 1 125V BATTERY CHARGER 1A TRIP Unit 2 COMPUTER UPS OR HVAC TROUBLE 901(2)-8 E-4 Unit 1 DIESEL GEN 1/2 OVERLOAD Unit 2 SPARE 901(2)-8 E-5 Unit 1 4KV BUS 13-1 VOLTAGE DEGRADED Unit 2 CABLE TUNNEL FIRE PROT WTR VALVE CLOSED 901(2)-8 E-10 Unit 1 COMPUTER TROUBLE Unit 2 COMPUTER TEMPERATURE 901(2)-8 F-4 Unit 1 DIESEL GEN 1/2 LOW FREQUENCY Unit 2 SPARE s/ 69
I QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 901(2)-8 P-9 Unit 1 250V BAT CHARGER 1/2 TRIP Unit 2 SPARE 901(2)-6 G-4 Unit 1 DIESEL GEN 1/2 DAY TANK LEVEL HI/ LOW Unit 2 4KV BUS 23-1 VOLTAGE DEGRADED 901(2)-8 G-S Unit 1 DIESEL GEN 1/2 RELAY TRIP ~ Unit 2 SPARE 901(2)-8 G-12 Unit 1 4KV BUS 14-1 VOLTAGE DEGRADED Unit 2 SPARE 901(2)-8 H-4 Unit 1 SPARE Unit 2 4KV BUS 24-1 VOLTAGE DEGRADED 901(2)-8 H-5 Unit 1 DIESEL GEN 1/2 HIGH TEMP Unit 2 SPARE
/" ' 901(2)-54 D-3 Unit 1 FILTER BLDG INST AIR PRESS LOW Unit 2 SPARE i
70
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 ht xf The operational characteristics of Quad Cities Unit 2 compared to the simulator are considered equivalent. Therefore, since the station and simulator response are so similar, Unit 2 specific simulator training is not conducted. The major difference between the simulator and Quad Cities Unit 2 that affect simulator training is: Simulator 1101t;_2
- 1. Electrical distribution 1. Electrical distribution system and unit components system and unit components are labeled Unit 1. are labeled as Unit 2.
This difference is not considered to have a significant impact on simulator training. Quad Cities Unit 1 and Unit 2 Technical Specifications are similar. Only Quad Cities Unit 1 Technical Specifications are utilized during simulator training. Quad Cities Station control room operators hold one rx license which allows them to operate both Units 1 and 2. The minor dif ferences that exist between Quad Cities Unit 2 and the simulator do not detract f rom training. In addition, these differences do not impact on the ability to perform normal plant evolutions in ANSI /ANS-3.5-1985, section 3.1.1 or respond to the malfunctions in section 3.1.2. The tasks related to these differences are minor in nature and are handled administrative 1y. ( '- 71
QUAD CITIES SIMULATOR ANSI /ANS-3.5 CERTIFICATION REPORT INITIAL REPORT, MARCH, 1991 ATTACHMENT 2 STEADY STATE / NORMAL OPERATIONS / REAL TIME / TRANSIENT TEST RESULTS
- This Attachment contains tests used to verify simulator response resulting from operator action, no operator action, improper operator action, automatic plant controls and inherent operating characteristics.
O 9 22
Simulator dugo Omes-Tost Proceduro Cover Sheet Test Number 74-/d u n-/o ss , PTAO-105T1 Om Description Date Performed 5-8-9/ j99l & &GW Mim TK-/ dru R 'lQ % -l Discrepancies section of Test Discrepancy Corrected ite m # Comments Requiring Report # (initials) Retest and Date O V __ Teet Results 4 /ceertuce criteria Sc ~ [ 1. Test Completed Satisfactorily all +ests med. fusient es u (se^ t; f e, 2. After correction of the above discrepancies, test
,j f,y . results are satisfactoy. Retest is NOT necessary.
7, "Estent dv(e* Sv/. 3. Tests results UNSATISFACTORY. Retest the above alte correction of above discrepancies. I I Retest Complete Date Test Complete - Date 3 Y'9 / l SFCC Acceptance _. p // Date F Cf / Simulator Supervis Ac ptanc A- Date _3'-7-P/ c.s.co n . m s u.o
l ew- QUAD CITIES SIMULATOR (s.-) STAEDY STATE TEST REVIEW SS*1 TEST #/ TITLE: DATE: Feb 13, 199h
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
A'. Actual plant data EVENT: Plant S/D 11/12/90 for OlRll
- b. Analytical or design data DATA:
- c. Data from similar plant PLANT:
[. Panel of experts (br,st estimate) (9 COMMENTS: () d. Data taken from einnt erecess comenter durine *hn nhuranen conducted on 11/12/40. We noted a discrepanev on plant feed flow which caused simulator data to fall outside ANS 3.5 tolerance. Submitted data to plant experts for resolution. Resolution: Based upon review by plant Thermal Engineer, feed water flow
- .vezel inaccuracies caused feed flow discrepancies. Simulator dora.S' data is considered ep n-: for plant conditions.
"Q /*4J "//
- 4. m KINDY DVORAK QUAD CITIES THER>tAl. ENGINEER
.O 1
l l l QUAD CITIES SIMULATOR l (c STEADY STATE TEST REVIEW
- 3. Compar'09n Results Simulator. capability to reproduce the defined evolution:
(circle one) EPTA
- b. UNACCEPTABLE l 4. Review-goardSignatures(differingopi cns m st be documented) kN zM W 4t _
.]{a$K1 N $ W</ / mas S ge n .r -
O c Skk/L u COMMENTS: ("c O 1 l 1 l l l l 1
)
l
'U 3 l
QUAD CITIES SIMULATOR f] (j STEADY STATE TEST REVIEW
- 2. Data Comparison Summary PPC POINT COMMENTS RESOLUTION Read consistantly high Feed water flow nozzels F122 - FW flow A - for all power levels munnncrea en ha i nauw ,
Read consistantly high Feed water flow nozzels F123 - FW flow B efor all power levels suspected to be in error. 0100 - RX level Constant during thutdown none Expected for C155 - Total Steam Flow power conditionn none v E equuur. E
/ \'
2
Test Number:_SS-1 Revision Number / Dato 2 0,1/14 /jLL Frequency _ Annual {} V QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST A. OBJECTIVES The purpose of this procedure is:
- 1. To verify that the simulator's computed values for 100%
are stable and will not vary by more than 1 2% of the initial values over a 60 minuto period.
- 2. To verify the simulator computed values of critical values f of critical paramotors shall agroo within i 2% of the Quad Cities plant's critical paramotors as required by ANSI /ANS
-3.5-1985, " Nuclear Power Plant Simulator's for Use in Operator Training".
- 3. To verify the simulator computed values of critical values of critical paramotors shall agroo within 12% of the Quad Cities plant's critical paramotors and shall not detract from training.
O B. -REFERENCES (/
- 1. ANSI / ANS 3.5-1985, Nuclear Power flant Simulator's for Use in Operator Training.
- 2. Rog Guido 1.149, Nuclear Power Plant Simulation Facilities for Uso in Operator License Examinations.
C. INITIAL CONDITIONS
- 1. The plant is at steady stato power, .EOL, equilibrium Xonon.
D. DATA COLLECTION Monitor the following plant process computer points: NOUN.[MiiE PPC POIRI
- 1. APRM Channel 1 B164
- 2. APRM Channel 2 B165
- 3. APRM Channel 3 B166
- 4. APRM Channel 4 B167
- 5. APRM Channel 5 B168
- 6. APRM Channel 6 B169
- 7. Total Reactor Recirc Flow C127 1
Test Number:-SS-1
~
' Revision Number / Date : 0.1/14 /21 Frequency: Annual QUAD CITIES' SIMULATOR STEADY STATE PERFORMANCE TEST NOUN NAME PPC POINT
-8. Total Jet Pump Flow C128
- 9. Reactor Dome Pressure C109
- 10. Reactor-Water Level C100
- 11. Total Steam Flow C155 5- 12. Total Feedwater Flow F122/F123
- 13. Generator Grcss Load G128-
- 14. Turbine Thtottle Pressure T100
- 15. Turbine Chest Pressure T101
- 16. Turbine 1st Stage Shell Press T106
- 17. FW Temp A F150
- 18. FW Temp B F151 19._ Cleanup Flow C121
' 2 0. Cleanup Flow C122 2,. RWCU: Inlet Temperature- C123
- 22. RWCU Return Temperature C124
- 23. CRD Flow C160
(( a. s ,)
- 24. HP Turbine Exhaust Pressure
- 25. LP Turbine Inlet Press T102 T103
- 26. Condenser 1A Pressure F118 27.-Condenser 1B Pressure F119
- 28. CondenserJ1C Pressure F120
- 29. 101 Drain Temperature F160-
- 30. -1D2 Drain Temperature F161-
- 31. 1D3. Drain Temperatura :F162
- 32. 1C1 Drain Temperature -F163
- 33. 1C2 Drain: Temperature F164
- 34. 1C3 Drain Temperature F165
- 35. 1B1 Drain Temperature F166
- 36. 182_ Drain Temperature. F167
- 37. 1B3 Drain Temperature F168 Numbers 1. tnrough 16. are critical parameters,.17. through L3 7 . are non-critical parameters.
I 1 _____.__._________.____m______.._ _ _ _ _ _ _ _ . _ . . . .
Test Numbert_SD-1 Rtsvision Number / Date : L_1111/11 Frequencyt_ Annual __ O QUAD CITIES SIMULATOR i STEADY STATE PERFORMANCE TEST E. TEST INSTRUCTION l l 1. Initialize at approximately 100% Steady State (75% Steady State, 50% Steady State, 40% Steady State or 25% Steady State), EoL, Equilibrium Xenon, all systems in automatic Control.
- 2. Ensure stable plant conditions.
- 3. Enter the data collection points.
- 4. Run for a minimum of 3600 seconds with no operator action for the 100% stability test. Run for a minimum of 180 A
seconds with no operator action for the 25%, 40%, 50%, 75% and 100% steady state tests.
- 5. Repeat the test for 1004 Steady State, 75% Steady State, 50% Steady State, 40% Steady State and 25% Steady State conditions.
F. ACCEPTANCE CRITERIA
- 1. The simulator computed full power, steady state values shall not change (drift) by more than 2% over a sixty minute period from the initial value and shall not detract from training.
- 2. The simulator computed steady state initial values shall not deviate from the Quad cities plant's measured values by more than !2% for critical parameters or 110% for non
-critical parameters and shall not detract from training.
- 3. Simulator steady test results will be compared with actual plant data taken while shutting down the plant. The review will be performed by a panel of experts, their review shall be documented.
- 4. Steady state tests for 25%, 40%, 50% and 75% power contain a " REQUIRED ACCURACY" column. This column in a plus/minus critical /non-critical parameter accuracy including instrument error.
O 3
}
1 Toct 14umbar SS-1 Revision 14umbe r / Date L.111412.1 Frequency: Annual g) 1._ QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST G. DOCUMENTATION
- 1. Retain the following documentations a: This procedure,
- b. All computer printoutP.
- c. All Data Sumnary Sheets,
- d. Test Cover Shoot.
H. DATA
SUMMARY
SHEETS Attached are Steady State Perfortnance Test Data Summary Sheets for the following conditions:
- 1. 100% power stability test
- 2. 100% power
- 3. 75% power
- 4. 50% power
- 5. 40% power
(N) i s_ 6. 25% power i 4 1
[ Todt Numbart SS-1 __ Revision Number / Date : 0,1/14 / 91 4 fr6quency t , Annual.,, .
- a. .
QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST 4 Data Summary Sheet 100% Power 60 Minute stability Test CRITICAL INITIAL LOW HIGH PERCENT PARAMATER VALUE VALUE VALUE DEVIATION APRM CH 1 99.52% power 99.5 99.79 .27 APRM CH.2 99.51% power 99.49 99.79 .28 APRM CH 3 98.83% power 98.81 99.51 .68 APRM CH 4 100.4% power 100.38 100.7 .29-APRM~CH-5 100.494 power 100.47 100.8 .30- - APRM CH 6 100.48%= power 100.25 100.55 .23 () TOTALLRECIRC FLOW 32.28 m#/hr 32.27 32.28 .03 , TOTAL JET PUMP-FLOW 97.53 m#/hr 97.51 97.54 .021 REACTOR PRESSURE 1005.57 psig- l1005.57 1006.04 .047 REACTOR-LEVEL '30.39 inches 30.39 30.41 .066 ( REACTOR STEAM FLOW 9.7 m#/hr ' 9. 7 9.725 .26 i TOTAL FEED FLOW 9.68 m#/br 9.672 9.696 .16 4 GENERATOR LOAD 823.09 mweL -823.08~ 825.11 .25 TURB THROTTLE PRESS 951.1;psig * *
- TURB CHEST. PRESS 924.99 psig 924.92 925.11 .013 1ST: STAGE PRESS 884.599 psig 884.599 886.54 .22 .J i
O 5 r
. .._, - , - , . . . _ . . . _ _ , _ - . , ..__.,_.._.2,___ _ . . _ . _ ~ . _ . _ . . _ . . ~ . . . - _ . . . _ . _ , , . , _ . . - ..-
Tost Numbart_SS-1 Revision Number /Dato 0,1/14 /91 Frequency Annual O QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 100% Power 60 Minute Stability Test NON-CRITICAL INITIAL LOW HIGH PERCENT PARAMATER VALUE VALUE VALUE DEVIATION FW TEMPERATURE A 338.68 degt 338.65 338.8 .035 FW TEMPERATURE B 338.34 degf 338.31 338.46 .035 RWCU FLOU A .0626 m#/hr .0626 .06261 .016 RWCU FLOW B .0601 m#/hr .060097 .060103 .005 RWCU INLET TEMP 519.25 degf 519.25 519.27 .004 RWCU OUTLET TEMP 452.5; degf 452.5 452.54 .007 CRD FLOW .0285 m#/hr .02847 .02852 .11 HP TURB-EXH PRESS 219.71 psig 219,65 220.35 .29 LP TURB INLET PRESS 215.94 psig 215.94 216.51 .26 COND 1A PRESS 1.341 in HGA 1.337 1.342 .30 COND 1B' PRESS 1.662 in HGA 1.658 1.663 .24 COND IC PRESS 2.11 in HGA 2.107 2.112 .14 101 DRN TEMP 322.87 degt 322.85 322.99 .037 102 DRN TEMP 322.87 degf 322.85 322.99 .037 1D3_DRN TEMP 322.87 degf 322.84 322.99 .037 6
Test Numbert_SS-1 Revision Number /Date: 0.1/14121 Trequencyt Annual O V QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 100% Power 60 Minute Stability Test , NON-CRITICAL INITIAL LOW HIGH PERCENT PARAMATER VALUE VALUE VALUE DEVIATION 1C1 DRN TEMP 244.16 degt 24A.156 244.36 .082 1C2 DRN TEMP 244.82 dogf 244.816 45.02 .082 1C3 DRN TEMP 244.6 dogf 244.599 244.794 .079 1B1 DRN TEMP 173.39 dogf 173.31 173.41 .012 182 DRN TEMP 174.13 degf 173.05 174.15 .011 183 DRN TEMP 173.87 degf 173.79 173.89 .012
- Turbine throttle pressure (PPC point T100) did not print out high and low values over the 60 minute test. Initial and final values were available for review, this point is considered acceptable.
7
1 1 Tost Numbori SS-1 _ l Revision Number /Date: 0,1/14 / 91 ; Frequency:_ Annual ; p [V) QUAD CITIES SIMULATOR l STEADY STATE PERFORMANCE TEST Data Summary Sheet 100% Power Steady State Test CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY APRM CH 1 15.0% power 97.5 95.4 2.1 APRM CH 2 15.0% power 96.9 94.1 2.8 APRM CH 3 15.9% power 96.4 98.1 1.7 APRM CH 4 15.0% power 96.6 95.4 1.2 APRM CH 5 15.0% power 97.0 97.2 0.2 APRM CH 6 15.0% power 97.6 96.4 1.2 (^T (_) TOTAL RR FLOW 21.52425 m#/hr 34.0 33.1 0.9 TOTAL JET PUMP FLOW 15.0 m#/hr 100.0 100.2 0.2 REACTOR PRESSURE 136.0 psig 999.7 997.6 2.1 REACTOR LEVEL 11.8 inches 29.5 30.7 1.2 REACTOR STEAM FLOW 1 42 m#/hr 9.225 9.271 .046 TOTAL FEED FLOW .30 m#/hr 9.44 9.26 .18 GENERATOR LOAD 31.5 mwe 802.58 790.4 12.18 TURB THROTTLE PRESS 130.0 psig 942.6 949.7 7.1 STEAM CHEST PRESS 130.0 poig 927.1 927.3 0.2 1ST STAGE PRESS 30.0 psig 872.6 849.2 23.4 l s_ ,
. .. .-. - . . . . - . . - . . . . - - . . . . - - - . - . . . ~ .- . - . - . . - . - - - . - . - . _ .
Tact Numbers SS-1 Rovision Number / Date : 0,1/14 / 91 Frequency: Annual O QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 100% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY ! FW TEMPERATURE A 15.0 degt 335.9 336.5 0.6 J' . FW TEMPERATURE B 15.0 degf 335.8 336.1 0.3
- RWCU-FLOW A 1 007875 m#/hr .0596 0.589 .0007
- RWCU FLOW B .007875 m#/hr .0564 0.584 .0020 RWCU. INLET TEMP 164.5 degf $21.6 519.5 2.1 RWCU OUTLET TEMP' 64.5 degf 434.0 432.7 1.3 i CRD. FLOW- i.0055 m#/hr .0312 .0299 .0013 HP TURB EXH PRESS _ 142.0 psig 211.0 209.1 1.9 i LP.TURB! INLET PRESS 142.0 psig 202.5 205.5 - 3.0 i COND-1A PRESS i.525 in HGA 1.8965 1.3716 .5249 COND 1B PRESS 1 525 in HGA 2.0436 1.6793 .3643 COND 1C~ PRESS 14525 in HGA 2.3951 2.1094 .2857 1D1 DRN. TEMP 143.0 degf 315.8 321.7 5.9 '
1D2 ?RN TEMP 143.0 dogf - 313.7 321.7 8.0 s 1D3 DRN_ TEMP. 143.0 dagf 315.7- 321.7' 6.0 i O e 5 an: 'v.
,. - s , - , , , - , . . , - - - , . , , y ,,,,,w.sr, , , .,,r, ,-v.,.-~,w,.,.,,-e.s .-,-+-+,e,,.m.-m,,-,mem+m.,- .-n.~.,v,.,-,m..-,.,-r.y.-me-- y ,
Toot Numbart SS-1 I Reviolon Numbor/Dato 0,1/14 /91 Frequency: Annual 'O O QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 100% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY 1C1 DRN TEMP 143.0 degf 240.0 244.6 4.6 1C2 DRN TEMP 143.0 degf 239.0 244.9 5.9 1C3 DRN TEMP 143.0 degt 243.6 244.9 1.3 1B1 DRN TEMP 43.0 degf 00S 171.8 ---- 1B2 DRN TEMP 143.0 degf 175.8 172.5 3.3 1B3 DRN TEMP 143.0 degf 177.0 172.3 4.7 ii v
l Tost Numbori_SS-1 _ Revision Number /Date 04 1/14/91 Trequencyt. Annual (~') \/ l l QUAD CITIES SIMULATOR ; STEADY STATE I PERFORMANCE TEST l i I Data Summary Sheet ! 75% Power Steady State Test ! I CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY APRM CH 1 15.0% power 81.3 78.8 2.5 APRM CH 2 35.0% pownr 76.8 75.5 1.3 APRM CH 3 25.0% power 74.4 78.5 4.1 APRM CH 4 15.0% power 76.0 75.8 0.2 APRM CH 5 15.0% power 73.4 78.3 4.9 APRM CH 6 15.0% power 83.4 79.0 4.4 TOTAL RR FLOW 11.52425 m#/hr 30.73 31.00 .27 TOTAL JET PUMP FLOW 15.0 m#/hr 91.8 96.7 4.9 REACTOR PRESSURE 136.0 psig 978.6 971.8 6.8 REACTOR LEVEL 11.8 inches 30.73 31.00 .27 REACTOR STEAM FLOW 1 42 m#/hr 7.47 7.37 .10 TOTAL FEED FLOW 1 30 m#/hr 7.79 7.36 .43 GENERATOR LOAD 131.5 mwe 669.38 641.30 28.08 TURB THROTTLE PRESS 130.0 psig 939.8 943.9 4.1 STEAM CHEST PRESS 130.0 psig 930.0 918.6 11.4 IST STAGE PRESS 130.0 psig 716.1 688.1 28.0 11
Toot Numbert_fS-1 Revision Number /Date 0,1/14 /91 Frequency Annual l O QUAD CITIES SIMULATOR STEADY STATE
. PERFORMANCE TEST Data Summary Sheet 75% Power Steady State Test i
NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF 1 PARAMATER ACCURACY ~ FW TEMPERATURE A 115.0 degt 325.2 323.3 2.9
'FW TEMPERATURE-B 115.0 degf 325.1 322.9 2.2 RWCU FLOW A 1 007875 m#/hr .0611 0.587 -.0024 RWCV-FLOW B. .~007875-m#/hr .0569 0.587 . 0018 ,.
RWCU INLET TEMP ~ 64.5 degf- 520.1 518.8 1.3
.RWCU OUTLET TEMP 164.5 degf- 430.3 430.7 '0.4
-CRD FLOW i.0055 m#/hr .0312. .0302 -.001 HP TURB-EXH~ PRESS i42.0 psig 171.4 162.1 9.3 LP TURB INLET _ PRESS 142.0 psig- 167.6 159.1 8.5 l-COND.1A PRESS 1 525 in HGA 1.6439 -1.2149 .4290 ;
COND 1B-PRESS' i.525.in.HGA 1.7511 '1.4697 .2814 ,
'COND IC. PRESS 1 525 in.HGA .1.9759 1.8261 .1498 101 DRN TEMP 143.0 degt 305.3 311.4 6.1 1D2 DRN-TEMP 143.0 degt 303.3 311.4 8.1 103 DRN; TEMP __
143.0 degt 305.9 311.4 5.5 1 I t i O , 12
..-n.__:.,_..._.~.,L,... ._.r.--_,, ., ., ,,_ _,,.__.,,..s,..... _ , . _ _ -___.,_.-..,_.,,_..,_m.__._..,___....,_,,-..__,-..u;..,...,-_.,
Toot 14umb3rs SS-1 Rovicion Number /Dato 0. 1/14/,n Frequency: Annual 4 QUAD CITIES SIMULATOR STEADY STATE 5 PERFORMANCE TEST
/
Data Summary Sheet 75% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY 1C1 DRN TEMP 143.0 degf 232.0 235.4 3.4 1C2 DRN TEMP 143.0 degf 230.0 235.7 5.7 1C3 DRN TEMP 143.0 degf 236.1 235.9 0.2 101 DRN TEMP 143.0 degt 00S 163.3 ---- 2B2 DRN TEMP 143.0 degf 169.7- 163.9 5.8 1B3 DRN TEMP 143.0 degt 170.6 164.0 6.6 O O 13
Toot Numbort SS-1 Revision Number /Date : 0,1/14 / 91 Frequency: Annual QUAD CITIES SIMULATOR STEADY STATE PERFORKANCE TEST Data Summary Sheet 50% Power Steady State Test CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY APRM CH 1 15.0% power 50.6 48.3 2.3 APRM CH 2 15.0% power 51.7 48.3 3.4 APRM CH 3 15.0% power 50.2 48.1 2.1 APRM CH 4 15.0% power 50.2 47.2 3.0 APRM CH 5 15.0% power 49.7 49.3 0.4 APRM CH 6 15.0% power 50.3 50.4 0.1 g. ( TOTAL RR FLOW 11.52425 m#/hr 18.5 18.2 0.2 TOTAL JET PUMP FLOW 15.0 m#/hr 59.0 60.6 1.6 REACTOR PRESSURE 136.0 psig 944.6 947.2 2.6 REACTOR LEVEL 1.8 inches 30.1 30.8 0.7 REACTOR STEAN FLOW 1 42 m#/hr 4.46 4.63 .17 TOTAL FEED FLOW .30 n#/hr 4.49 4.62 .03 GENERATOR LOAD 131.5 mwe 401.0 404.4 3.4 TURB THROTTLE PRESS 130.0 psig 931.3 935.3 4.0 STEAM CHEST PRESS 130.0 psig 928.6 918.4 10.2 IST STAGE PRESS 30.0 psig 420.7 415.8 4.9 [ \_/ 14
Test Numbert_SS-1 Revision Number /Date 0.1/14/91 Frequency _ Annual O
\_/
QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 50% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY , FW TEMPERATURE A 115.0 degf 295.0 297.3 1.3 FW TEMPERATURE B 15.0 degt 295.0 297.1 2.1 RWCU FLOW A 1 007975 m#/hr .0632 0.577 .0055 RWCU FLOW B 1 00787b m#/hr .0608 0.577 .0031 RWCU INLET TEMP 164.5 degf 513.5 516.6 3.1 RWCU OUTLET TEMP 164.5 degf 423.5 428.8 5.3
<~ __
k_) CRD FLOW 1 0055 m//hr .0312 .0301 .0011 HP TURB EXH PRESS 142,0 psig 95.9 94.2 1.7 LP TURB INLET PRESS 142.0 psig 93.9 92.3 1.6 j COND 1A PRESS 1 525 in NGA 1.3870 0.9696 .4174 COND 1B PRESS 1 525 in HGA 1.4338 1.1426 .2912 COND 1C PRESS 1 525 in HGA 1.5493 1.3823 .1670 AMhMBt( SD 1D1 DRN TEMP 143.0 deqf 276.4 289.2 12.8 102 DRN TEMP 143.0 dogf 274.7 289.2 14.5 1D3 DRN TEMP 143.0 dogf 276.2 289.2 13.0 15
. - .. _ . _ ~ . - . - . __ . - .- . . .-
Toot Numbort._SS-1 Roviolon Numbor/ Dato 0, 1/14/91 Frequency: Annual C) O l QUAD CITIES SIMULATOR l STEADY STATE l PERFORMANCE TEST Data Summary Sheet 50% Power Steady State Test I NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF - PARAMA7ER ACCURACY 1C1 DRN TEMP 143.0 degt 208.4 216.7 8.3 1C2 DRN TEMP 143.0 degt 206.5 217.0 0.5 1C3 DRN TEMP 143.0 degf 211.5 217.3 5.8 1B1 ORN TEMP 143.0 degf OOS 148.9 ---- 1B2 DRN TEttP 143.0 dogf 151.5 149.5 2.0 143 DRN TEMP 143.0 degt 151.6 149.7 1.9 16
Toct Numbort S3-1 Revision Number /Date 0.1/14 /91 Frequency Annual .e QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 40% Power Steady State Test CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY
'APRM CH 1 15.0%' power 39.7 38.3 1.4 f APRM CH 2 5.0% power 41.0 38.1 1.9 APRM CH 3 15.0%. power 39.3 38.3 1.0 APRM CH 4- 15.0% power 39.7 37.8 1.9
~APRM JH 5 - 15.0% power 39.5 39.2 0.3 APRM CH 6 15.0% power 39.8 39.9 0.1 TOTAL RR= FLOW 11.52425 m#/hr 10.8 12.04 1.24 TOTAL JET PUMP FLOW 15.0 m#/hr 39.6 42.1 2.5 REACTOR PRESSURE 136.0 psig- 935.8 940.3 4.5 REACTOR LEVEL 11.8 inches 30.0 30.7 0.7 REACTOR STEAM FLOW' i.42 m#/hr 3.34 3.59 .25 TOTAL FEED; FLOW .30'm#/hr 3.7759 3.8410 .0651 GENERATOR LOAD' 31.5~mwe 310.5 317.8 7.3 TURB: THROTTLE PRESS 130.O psig 928.2 932.3 5.1 STEAM-CHEST PRESS 130.0 psig 927.5 922.3 5.2=
1 IST STAGE PRESS 130.0 psig 320.0 335.5 S.5
- 17 l
I .
Toot Numbort SS-1 Revision Number / Date t o ,1/14 / 91 Frequency Annual L/ QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Suminary Sheet 40% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY FW TEMPERATURE A 15.0 degt 281.2 280.4 0.8 FW TEMPERATURE B 115.0 degf 281.1 280.2 0.9 RWCU FLOW A 1 007875 n#/hr .0648 0.576 .0072 RWCU FLOW B 1 007875 m#/hr .0600 0.576 .0024 RWCU INLET TEMP 164.5 degf 508.0 514.5 6.5 RWCU OUTLET TEMP 164.5 degf 419.0 426.9 7.9 /~ (_j} CRD FLOW 1 0055 m#/hr .0313 .0301 .0012 HP TURB EXH PRESS 142.0 psig 71.3 70.7 0.6 LP TURB INLET PRESS 142.0 psig 70.0 68.8 1.2 COND 1A PRESS 1 525 in HGA 1.3401 0.9821 .3580 COND 1B PRESS 1 525 in HGA 1.3605 1.1197 .3508 COND 1C PRESS 1 525 in HGA 1.4369 1.3120 .1249 1D1 DRN TEMP 143.0 degf 260.2 281.6 21.4 1D2 DRN TEMP 143.0 degf 258.7 281.6 22.9 1D3 ORN TEMP 143.0 degf 260.1 181.6 21.5 /Q
/ 1B
Toot Numbert SS-L Rovision Numbor/Dato 0,1/14 /91 Frequencyi Annual O QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 40% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY 1C1 DPJ4 TEMP 143.0 degf 197.6 206.5 8.9 1C2 DPJ1 TEMP 143.0 degf 195.3 206.9 11.6 1C3 DRN TEMP 143.0 degf 200.0 207.2 7.2 181 DRN TEMP 143.0 degf OOS 142.3 ---- 182 DRN TEMP 143.0 degt 142.4 142.9 0.5 1B3 DRN TEMP 143.0 degf 142.4 143.4 1.0 l I-l l I O 19
Tcst Numbor: SS-1 Rovision Numbor/Dato 0,1/14 /91 Frequency: Annual r~g
)
QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 25% Power Steady State Test CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY APRM CH 1 15.0% power 26.8 26.1 0.7 APRM CH 2 5.0% power 27.8 25.6 2.2 APRM CH 3 15.0% power 27.2 25.3 1.9 APRM CH 4 5.0% power 25.5 25.1 0.4 APRM CH 5 15.0% power 27.7 26.3 1.4 APRM CH 6 5.0% power 29.3 27.1 2.2 rs - () TOTAL RR FLOW 11.52425 m#/hr 10.7 10.6 0.1 TOTAL JET PUMP FLOW 15.0 m#/hr 38.65 35.20 3.45 REACTOR PRESSURE 136.0 poig 927.9 933.6 5.7 REACTOR LEVEL 1.8 inches 30.1 30.7 0.6 REACTOR STEAM FLOW i.42 m//hr 2.294 2.410 .116 TOTAL FEED FLOW i.30 m#/hr 2.3582 2.3820 .0238 GENERATOR LOAD i31.5 mwe 205.0 210.7 5.7 TURB THROTTLE PRESS 130.0 psig 925.0 928.7 3.7 STEAM CHEST PRESS 130.0 psig 925.6 923.7 1.9 IST STAGE PRESS 130.0 psig 210.0 238.1 28.1 20
Toot Numbart_SS-1 Revision Number / Date 101 1/14191 Trequency _ Annual (~) U QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 25% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY FW TEMPERATURE A 115.0 degt 257.7 260.3 2.6 PW TEMPERATURE B 115.0 degf 257.7 260.1 2.4 RWCU FLOW A 1 007875 m#/hr .064 .057 .007 RWCU FLOW B 1 007875 m#/hr .0600 .0576 .0024 RWCU INLET TEMP 164.5 degf 512.1 515.9 3.8 RWCU OUTLET TEMP 164.5 dogf 422.6 420.3 5.7 CRD FLOW 1 0055 m#/hr .0314 .0301 .0013 HP TURB EXH. PRESS 142.0 psig 43.3 41.7 1.6 LP TURB INLET PRESS 142.0 psig 42.3 40.2 2.1 COND 1A PRESS 1 525 in HGA 1.3744 1.0292 .3452 COND 1B PRESS 1 525 in HGA 1.3674 1.'255 .2419 COND 10 PRESS 1 525 in HGA 1.4165 1.2602 .1563 1D1 DRN TEMP 143.0 degf 237.2 257.7 20.5 1D2 DRN-TEMP 43.0 degt 236.2 257.7 21.5 103 DRN TEMP 143.0 dogf 237.2 257.7 20.5 t 21 _ _ _ . _ _ _ _ . _ _ _ ,. _ __ . . ~ _ _ . _ , _ _
Test Numbort SS-1._ ,,_ Roviolon Numbor/Dato 0,1/14 /91 Frequency: Annual O V-QUAD CITIES SIMULATOR STEADY STATE PERFORMANCE TEST Data Summary Sheet 25% Power Steady State Test NON-CRITICAL REQUIRED PLANT VALUE SIM VALUE DIFF PARAMATER ACCURACY 1C1 DRN TEMP 143.0 degt 176.7 189.2 12.5 1C2 DRN TEMP 143.0 degf 176.4 189.6 13.2 1C3 DRN TEMP 143.0 degf 179.0 189.9 10.9 181 DRN TEMP 143.0 degf OOS 128.9 ---- 182 DRN TEMP 143.0 dogf 127.0 129.5 2.5 1B3 DRN TEMP 143.0 degt 127.0 130.3 3.3 O O 22
. __ . . ._ _ _ _ _ _ _ . ~_ _ _ . _ _
o OUAO TIT!ES $!MULATOP. ! TPAN3IENT *EST FIV!EW G TFx;s:ENT TEs: v/T:TLE: ;1L a R e~ c.h Tt.1 ., . @l) TATE: 2*/3'9/
- 1. Baseline data utilized for test comparison in Or:er of preference (circle appropriate choices)
- a. Actual plant transient dat2 EVENT: _
- b. Analytical or design data TATA:
- c. Transient data from similar plant PLANT:
- d. Panel of experts (best estimate)
CCMMENTS: (^)s (O A d- A h s% J& b e w. Lk A.- S,e ~ + .a les a
@ FO "4' A udse i " % su k o ~ A p p ~ ALo h
- V o h 9
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- a 20 % i s mamaal
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- 1,. 4 6k 5
gs OUAD CIT ES S!MULATOR i TRA!JSIE!iT TEST FIVIEW
- 2. Data C mparison Summary VARIABLE CC!O!E!1T S RESOLUT!0!1
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----y--, , , - ,,-w,, -- . , , , _ _ , - - - - - . , , - , .
- OUAD C:T'ES SIMULATOR
((w TPM15:ENT TEST REVIEW
- 3. Comparison Results '
Simulator capability to reproduce the defined transient: (circle one)
- a. ACCEPTABLE
- b. UNACCEPTABLE
- 4. Review Board Signatures (dif fering opinions must be documented) kfAf ? (; 'N.y-
)!rh= 5A A_ '
( .1%" L.(; W ( :.Lg!. %+' v d COMMENTS: v gumagen ene,meepee4P N
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.__ _._ _ . _._ _-~. _ __. _ _. _ _ .-._ _.__ _ _-__. __ - _
Toat Numbert TR-1 Rev. Number /Date: 0, 01/14/91 Frequencyt_ Annual (
\
QUAD CITIES SIMULATOR TRANSIENT TEST MANUAL REACTOR TRIP I. OBJECTIVES The purpose of this procedure is tot
- 1. Test the simulator response to a Manual Reactor Trip as required by ANSI /ANS-3.5-1985.
- 2. Verify the ability of the primary and secondary plant automatic control systems to sustain a trip from 100 percent power and to bring the plant to stable conditions following the *-ansient.
II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149: Nuclear Power Plant Simulation i Facilities for Use in Operator License Examinations.
III. INITIAL CONDITIONS
- 1. The plant is operating at normal steady state, full power conditions.
- 2. Control rod drive system is operable, and capable of bringing the reactor to a hot shutdown condition.
- 3. FW Reg Valve A is in MANUAL, approximately 40% open.
V. DATA COLLECTION
- 1. Setup the ZETA plotter to graph the following variables:
- a. Reactor Power (% Neutron Flux)............NMAPRMFX
- b. Total Steam Flow.............-.............MSFSTM
- c. Total Feedwater Flow......................RRFFW
- d. Reactor Pressure..........................RRPRV
- e. _W ide Range Reactor Water Level............RRLWR
- f. Narrow Range Reactor Water Level . . . . . . . . . . RRLNR
- g. Generator Gross Electrical Power..........EGWMGEN l
- h. Turbine Steam Flow........................MSFHPIN
- 1. Total Core Flow...........................RRFRXT
- j. Recirc Pump A Loop Flow...................RRFJPAT
- k. Recirc Pump B Loop Flow...................RRFJPBT
(~)
\- 1 l
l l l
l l Test Number: TR-1 Rev. Number /Date: 0, 01/14791 Frequency _ Annual f~ QUAD CITIES SIMULATOR TRANSIENT TEST I l KANUAL REACTOR TRIP I l V. TEST INSTRUCTIONS
- 1. Ensure the plant meets the initial conditions as specified in Section III.
- 2. Enter the data collection points from section IV.
- 3. Initiate a reactor trip by depressing the manual scram pushbuttons on panel 901-5.
- 4. Allow the simulator to run until stable plant conditions are established.
- 5. Graph the variables listed under Section IV.
VI. ACCEPTANCE CRITERIA The following acceptance criteria are to be used to determine successful test completion:
) 1. All control rods fully inserted.
- 2. Reactor recirculation pumps have run back to minimum.
- 3. SRM and IRM detectors fully inserted automatically.
- 4. Turbine and generator have tripped.
- 5. Auxiliary power has transferred to the reserve auxiliary transformer.
- 6. Reactor water level decreases to less than the Group II Isolation setpoint.
- 7. The observable change in the parameters correspond in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of nature.
- 8. The simulator shall not fail ta cause an alarm or
- _ automatic action if the reference plant would have caused l an-alarm or automatic action, and conversely, the l
simulator shall not cause an alarm or automatic action if l the reference plant would not cause an alarm or automatic action. 7s
\J 2
Test Numbsrt TR-1 Rev. Number /Datet_0, 01/14/91_ Frequency: Annual FO
\l QUAD CITIES SIMULATOR TRANSIENT TEST HANUAL REACTOR TRIP
- 9. The graphs are similar to the baseline graphs, or if the baseline data used was the judgement of a panel of exporta. their review shall be documented.
"II. LIST OF FIGURES
- 1. Reactor Power (% Neutron Flux)
- 2. Total Steam Flow W
- 3. Total Feedwater Flow 2
- 4. Reactor Pressure
- 5. Wide Range Reactor Water Level
- 6. Narrow Range Reactor Water Level
- 7. Generator Cross Electrical Power
- 8. Turbine Steam Flow
- 9. Total Core Flow
- 10. Recirc Pump A Loop Flow
- 11. Recirc Pump B Loop Flow O
P.
O MANUAL R[ ACTOR TRIP. REACTOR POM R
% REACTOR POWER 1 DIVISION = 10,41 SECONDS 12"~
I i l i i l l I I I I I l l i l
~
d 100- - 75 _
/~~N U _
]
50 - -
; 25 -
I i 1d l ! I I ! I I I I I ! ! 0 5 - 10 15 20 TIME NMAPRWX(1) APRM FLUX LEVELS p
MANUAL REACTOR TRIP, TOT AL STE AM FLOW 6 X10 LBS/IIR 1 DIVISION = 10.41 SECONOS 10.8 ; ; j j j j j j j j ; j j n=_--. - 8.64 _ _
~ ~
6.48 - - 4.32 _ 2.16 - - 1 I I I l l I I I i 1 l l l l l 0 5 10 15 20 % TIME MSFSTM TOTAL STEAM FROM RX 8 -_ _-_
O t w MANU AL RE ACTOR TRIP, TOT AL FEED FLOW 6 X10 LBS/HR 1 OIVISION = 10.41 SECONOS 11.88 ' i l l I I l l l l l l l l l l i 9.50 7.13 , () v - + 4.?S ,, _ 2.38 __
= =.
0 - 10 15 20 TIME HRFFW TOTAL FEEDWATER FLOW
\
N-]
1: 1 ~- MANUAL. REACTORiTRIP. REACTOR PRESSURE PSIA 1 DIVISION = 10.41 SECONOS UU
- I I I I I i l I I I I I l- 1 i i 1200 _
" ~
9P1 = 0.. 600 - - 4 .- 300 -- - -
-l l .I l I l l I l- I l l I l I _
0- 5' to 15 20 TIME RRPRV _RX VESSEL 00ME PR ABS 01.UTEt O
/ h
'Q MANUAL RE ACTOR TRIP, 2 REACTOR LEVEL INC:.ES 1 OIVISION = 10.41 SECONOS
+60 l l ~l I pi I i i i i i i i i
-20 _
~~
-100 -
C\ V . ; l
-180 _. _
-260 _. _
y
-340 I I k , l l i I I l l 1 ! I i l l C 5 , 10 15 20 T INI, RRLM RX WTR LVL, WIDE RANGE
()%
\._
- . . - . .. .... . - . - . . . - . - _ . - ..-..~. -- . . . . - . - . - - . . . . .
l O l MANUAL REACTOR TRIP, NR REACTOR LEVEL INCHES-1-DIVISION = 10.41 SECONOS i
+60 '
l I I l l- 1 1 I I l I 1 i i i -
+36 .
+12 - -
O . - l.:
- 1. ;
-36 -. -- -
- -60' 'l l l I ,
I I l -l ~l i I I I l- I l- d 0- -5'.- 10 15- 20-l, TIME-i
.RRLNR NARROW RANGE LVL Oi
-. , , . . . . . , . - . ~ . , - , ,. ._,, . , . ,, -, -
. _ _ . _ ~ _ _ _ _ _ . . _
i a i MANUAL RE ACTOR TRIP, GENERATOR LOAD' ! MEGAWATTS -i
.I'OIVISION =
10.41 SECONOS I I I I I I I I I I i I .- j i j i < i i 1- -
~800 1-4
.l
'600 .
O - . { 4 400 " a i
-200 .
i I l l l- 1l i I 1- I 1 l l l 1 1 -f 0 '. 5'. 10~ -15 20
- T IME-i EGWGEN MG OUTPUT REAL POW R
..---. _:_-....:~._..--._..-,.-..u._._ -
- . . - . _ _ _ _ . , - - . . _ . . ~ . . _ _ . _ _ . _ , . . _ . - -
(" ( MANUAL REACTOR TRIP. TURBINE STE AM FLOW 6 X10 LBS/11R 1 DIVISION = 10.41 SECONOS 11.88 - 1 I I I I l l 1 I I I I I l l I 9.50 - -
\
7.13 - - 4.75 - - 2.38 l l l- l l l I I I I I I I l l I O 5 , 10 15 20 TIME MSFHPIN HP TURB INLET FLOW f'T-o
;i i
MANUAL REACTOR TRIP. CORE FLOW 6 X10 LBS/IIR 1 OIVISION = 10.41 SECONOS 124.92 _
+
1 l- l l l l l I l .I l l l l l l f
- W 99.94 -
[
.74.95 -O . -
49.97 - - 1
^ 24.98 - -
! I f I I I l- ! I I l i l i I I 0 5 '. 10 15- 20 TIME RRfRXT- CORE TOTAL INLET FLOW
. n U
,_,r, r -,-, , - - - s y-., , - - - . - . ~ - -
. l s i i
~
1 MANUAt. REACTOR TRIP, L OOP A FL OW 6 X10 LBS/HR 1 DIVISION = 10,41 SECONDS r 64.8
.I l- 1 l l l l I I l- 1 I I i j i )
54.0 - 43.2 -- - 10 . _ 32.4 - - i 21.6 - - ; l 10.8 I I 'I I I I I 'I I I I I I I I I 0- 5 '. to- 15 :20-TIME RRFJPAT: TOTAL JP FLOW LOOP A u
.O
=
1 MANUAL ~-REACTOR TRIP, L OOP 8 FL OW 6 X10 LBS/flR 1 DIVISION = 10.41 SECONOS , 64.8 -- 1 I I l I I I I I I I I I I i i q 54.0 - T - 43.2
,j% - - ,
V j "32.4 - -
,21.6: _ . --
. . 4
[. ' 10.8 -l I t- l l I I l- l -l I I I I I I
-0 5- '. 10 15 20 TIME i.
te 3RFJP8T- TOTAL - JP FLOW. LOOP 8 l O. '
4 OUAD CITIES SIMULATOR /7 ' i TPANS!ENT TEST REVIEW uJ TPANSIENT TEST #/T:T.E: T :, 30 Att A.c, F e elj d u Ps - g ., '[$'h DATE: 2 /3 -9/
.. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- a. Actual plant transient data EVENT:
- b. Analytical or design data OATA:
- c. Transient data from similar plant PLANT: _
- d. Panel of experts (best estimate)
COMMENTS: m) 0 wk~V l> b p. [ e. k w J~ e_ e sp &s Wf C. L ? heS P O v13 C :
/. k u p. fe Ywn Y N v.s hO c2.// O hit C v lI e m H ,
Q Y 63 WYC l Vi { d? 3 V\ $yb 0.Vld $ $ ACht ,Cc $ A , H Sc.L . W l
+ -
l l Ci l '%,) I j
r
-QUAD CITIES SIMULATOR ARA!1SIEt4T TEST REVIEW
- 2. Data Comparison Summary
' VARIABLE COMMEt4TS RESOLUTIOt1
- / . Re u La - Pew G3 t'.s A. : s % c Le voi) .' t. See 6vioW L L l . s s, L S o b e ,/, % .
s D h d.<sl:dah: T p f
~
4 O OI*% 2.Tofd A f/ b6 Oh' s A GLa a a. sse G E< o u
% f. f. ~ h O k R- v pu i.s TJ 7 k,L 9 n al fhe, ! ? -(b.o r- A A. sed 3.7:u c_t en rs us < ~m -< .c s.3ze se ~
sd r-a a egez wre ct e
/
- 5
'. b ' LO vt ' R tc t L. g / ,_.s cl a e tel L. ak ~o d 4 SE 1 6E< c << e
*~ls C f.o
~
f-(a O
~
I. ($x LeaJ (B LL d...s o m I. d o w l vo A,se f 'S Et 6sch
- o. y '
- f 607. alk- s A C/.a s 4. /s L.<(-ac.
t . Ca < e CL li) ? ? 4 321 GEcow
- s. L s., A n u D ??
2Es o t-.c<. ri o "S :
- 1. % i n 'o $a.$ - D, e we r de c r e.a c o *5
- olwe No reScY Ccx' 1i n IL+ nh evollnn (n en. <ca4; vh h. 7% &n is- e -
w a 4- i ,. An1 nlI u.o o w er o c c i lls h E w A', i lo um di u i e t k v J -41.e c o e e. : re swI-l-s *v .&oa kof -euee do n 4 %n-S /h a.dWi+<0 n Jo inc<c$s d c re o i n ien 4 &mper~k< <e s .
-(conwer on ned P~3e)
QUAD CITIES $!MULATOR TRANSIENT TEST REVIEW
- 3. -Comparison Results Simulator capability to reproduce the defined transient:
-(circle one)
- h. ACCEPTABL h ;
- b. UNACCEPTABLE
- 4. Review Board Signatures (differing opi ions must be documented)
J3Wle $ wmuA , Mi L6 OY7 MAL
-(_aQ G' u L%A4
/ g' "O
~'
g ~ my Q L COMMENTS: 215 0 ' "'T # # ^'# A. ne M s4&-14 s bem Crow ee.v a ve enh - f!w
~-
fo HPd_T aad' /2CK +a < A i e, e s . i ni A del Se.eJ Qu w re-pr es ec hs 4twkm reach < .Cecd vo u m,as ,a. m J' h skh oress. i h~,*eokuius sy s Lems HPcz s.Aacic. - 4 swilu level seade s e/enki Jc. o e:f otovL c vt pH e . IV does no-f && <respo n f $ r ?ow e / i b s bw ed a n4 e . d4a.., < c ns+ n eeJN. J J
- 5. S w loacfD/uG4eouL lo & . A - h mk ba s h is0 -
twd e/omi %u.nh ec.e twive u 6%+<h h R e. Los.s O d Y. $ eCcon / VIC v'C4 S e.S . / < /b >*b v"' bOv'*? ke h lO . v Plo+ rs nr v<e sens ike ,' hah Jwn o n ~ 6 wsw V s -
- < c.c.
&. do<e. Stow a.CfackJ % '&' tof m o looo cea vihAi&<< .
Th ub < s n o t sa e n on \Jh']e y" -w h lo ff h>'em a if 0 md'e qs es < e. v e <., e #cw . 3 i 1
-.- =. . . . - . . _ , - . , . . -. - . . .
Test Number: TR-2 Rev. Number /Date:-0. 01/14/91 Frequency: Annual QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS TRIP OF ALL MAIN FEEDWATER PUMPS I. OBJECTIVES The purpose.of this procedure is to:
- 1. Test the simulator response to a simultaneous Trip of All Main Feedwater Pumps as required by ANSI /ANS-3.5-1985.
- 2. Assure the simulator's High Pressure Injection Systems
.(HPCI & RCIC) functions properly to restore reactor water level after a-reactor trip.
II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Piant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149: Nuclear _ Power Plant Simulation Facilities for.Use in Operator License Examinations.
III.' INITIAL CONDITIONS C' .
- 1. The plant is operating at normal steady state, full power conditions.
2 '. High Pressure Injection Systems _ (HPCI & RCIC) are operable and capable of performing their intended-function. IV . - DATA COLLECTION
- 1. ' Setup the ZETA plotter to graph the following variables:-
a'. - Reactor Power , (% Neutron- Flux) . . . . . . . . . . . . . . .NMAPRMFX
- b. . Total Steam Flow.............................MSFSTM
- c. Total Feedwater F1ow.........................RRFFW
- d. Reactor Pressure.............................RRPRV e., Wide Range Reactor Water Level...............RRLWR
- f. Narrow Range Reactor Water.. Level.............RRLhR l
- g. Generator-Gross Electrical-Power..............EGWMGEN l
- h. Turbine Steam Flow............................MSFHPIN l 1.. Total Core Flow............................-..RRFRXT
- j. Recirc Pump A Loop Flow..............'........RRFJPAT
- k. Recirc Pump - B Loop Flow. . . . . . . . . . . . . . . . . . . . . . RRFJPBT
- 1. ReactorLWater Level, Bottom - Top of Vessel..RRLWR O 1 j
i 1
i Toot Numbers-TR Rev. Numbar/Date: 0, 01/14/91 { Frequency: Annual
~(" . !
"% QUAD CITIES SIMULATOR TRANSIENT TEST
-SIMULTANEOUS TRIP OF ALL KAIN FEEDWATER PUMPS V. TESTEINSTRUCTIONS .
I
-1. Ensure the' plant meets the initial conditions as specified 4 in Section III.
- 2. Enter the-data collection points-from Section IV.
- 3. Trip all main feedwater pumps by simultaneously inserting malfunctions FWO1A, FWC1B and FWO1C. (Reactor Feed Pump Trip)
- 4. Allow the simulator to run until stable plant conditions are established.
- 5. Graph the-variables listed under Section IV.
VI. ACCEPTANCE CRITERIA The following' acceptance criteria are to.be used to determine successful test completion:-
- 1. High pressure injection systems initiate on low low reactor water level, and restores reactor water level to art appropriate level.
2.--Drywell pressure remains-fairly constant. l
-3.
.HPCI-and RCIC initiate:and inject to the reactor vessel.
- 4. Reactor _ pressure does_not increase to SP.V_setpoint.
- 5. -The observable change in the parameters correspond in direction-to those' expected from a,best' estimate for the simulated transient ~and do not violate the physical laws E of. nature, l.
l 6.- The simulator shall not. fail to cause an alarm or L automatic action if the reference plant would have caused b an alarm or automatic action, and conversely, the simulator shall not cause an alarm or automatir action-if ' the reference plant would not cause an alarm or automatic action. LO 2 L o 1
I Test Number: TR-2 Rev. Number /Date: 0, 01/14/91___ Frequency: Annual r~N
's- QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS TRIP OF ALL MAIN FEEDWATER PUMPS
- 7. The graphs are sinilar to the baseline graphs, or if the baseline data used was the judgement of a panel of experts, their review shall be documented.
VII. LIST OF FIGURES
- 1. Reactor Power (% Neutron Flux)
- 2. Total Steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressure
- 5. Wide Range Reactor Water Level
- 6. Narrow Range Reactor Water Leve]
- 7. Generator Gross Electrical Power
- 8. Turbine Steam Flow
- 9. Total Core Flow
- 10. Recire Pump A Loop Flow
- 11. Recirc Pump B Loop Flow
- 12. Reactor Water Level, Bottom - Top of Vessel b) v l
l \ (s (- l 3 L
. . - . . . ..~ -- - . -. _-.- .-. - . . - - . . . . . .O- \g.
TRIP Of ALL RFP, REACTOR POM R
% REACTOR POWER 1 DIVISION =- 13.85 SECONDS 125 l l l l l l l l l l l l l l l l 100 75 - -
50 - - 25 -- - l l L-1 I I I I l- 1 I I I I I I . 0 5 10 15 20 TIME
. NMAPRWX(1) APRM FLUX LEVELS Q
TRIP OF ALL RFP, TOTAL STE AM FLOW 6 X10 LBS/ha 1 OIVISION-= 13.85 SECONDS 10.8 I I I I I I I I 1. I I I I 1 I I 8,64 - _ 6.48 - - O _
\ .
4.32 - _ M
!2.16 - -
l- l l l t- 1 I I I l 1 -. I 1 -l' I i 1-0 5 10 15 20 TIME WSFSTM TOTAL STEAM FROM RX
- O
- . . - . . _ . . .- . . . - . - . . . - .. ... -.....-. . _. _ - -... - - ~.
TRIP 0F ALL! RFP, TOTAL FEED FLOW 6 X10 -LBS/HR 1-DIVISION-= .13. 85 SECONOS
-:11.88
.I -l -l= l l l l 1 I I I I I I I I
.9.50 - 1 -
7.13 -- -
- 4.75- -- -
!2. 3 8' -
i
-- I I 1- e4 I I I 'I l' I -l- I l 1- I
-O' 10 15 20
- T I ME .
R RF F W-- TOTAL.FEEDWATER FLOW. -
!O
s,-
)
TRIP OF ALL RFP, REACTOR PRESSURE PSIA 1 OIVISION = 13.85 SECONOS I UU l l I I I l I I I I I I I I I I 1200 - 900 __ ?"'s v _ _ 600 - -
. _ l 300 - -
l I I I I I I I I I I i 1 I I I l ; O 5 10 15 20 TIME RRPRV RX VESSEL DOME PR ABSOLUTE j r3 %/ l
., . _ . _ ._ . . _ . _ . . . _ _ . _ . _ _ . _ . . _ . _ _ . . . . . . _ . . . _ . _ .. - . . _ . . . - _. ~ _ _ . _ _ _ _ _
r lQ W
^
t- TRIP ' OF ' ALL RFP, WR REACTOR LEVEL INCHES 1.0IVISION =- 13,85 SECONDS-
-+60 l- 1 I I I i 1 I I I I 1 I I I l
- N /s .
i
-20 -. _
i 100 __ 1.-
-. -180 .
i 260 -~ - l.) -340 I I l~ l I l I I I I l 'l I I l l 0 '5 10 15 20-
' TIME
- RRLM RX MR LVL, WIDE RANGE Lp.
a
. . - - . . - . - . - _ - . . . . ~ _ ~ . - - . - - - . . . . ._
i TRIP OF ALL RFP, NR REACTOR LEVEL INCilES~ 1-DIVISION = 13.85 GECONOS 60 I I I I I I I I I I I I I I -1 1 ( 48 - 36 - O' - 24 12 - - I .I I I l- 1 I -1 1 I I I I I i 1 0 5 10 15 20 TIME. RRLNR NARROW RANGE' LVL , 1 O-l l 1 ,
-. -~ . .~ -.- -.---......_- - . - . . . - = . - . . - . . - - - . - . . _ - . .
TRIP OF ALL RFP, GENERATOR LOAD MEGAWATTS 1 DIVISION = 13l85 SECONDS
-1,000 I I I I I I I I I I I I .I I I l-p 800 .
b$ m 600 - - 400 - - 200 . 1 I -l l I I I I I I 'l I- 1 I I l-0 5 10 15 20 TIME EGWGEN MG OUTPUT REAL POE R . l l O
O TRIP OF LL RFP, TURBINE STEAM FLOW 6 X10 g3gj,33 1 DIVISION = 13,85 SECONOS 11.88 l -l i l l I I I I I I I I I I I 9.50 g -
~4.75 -- -
2~.38 - - 1 I I I I I I I l- I l l I -l 1 l-0 5 10 15 20 TIME MSFH?IN HP TURB INLET FLOW-O
'l
}
l O TRIP-OF ALL RFP, CORE FLOW X106 LBS/HR-1 DIVISION = 13.65-SECONOS 124'.92
- 1. I ;l i I I I -l I l- 1 I I I I i
-99.94 - -
i 74.95 - - . ! O _ _
'49.97- - -
24.98 = W .M l I l' -l- I- I l- 1 I -l i I 'l 'l 1- I
.i' 0 5. 10 15 -20 TIM
~RRTRXT CORE-TOTAL INLET FLOW RO l
l-i l
- .. -. . . . . . . . . . - . - - - ... = .. - . .. . . _ .
TRIP Of A(L RFP, LOOP A FL OW 6 X10 LBS/11R - 1 DIVISION = 13,85 SECONOS 64.8 l- l l l l l l l l l l l 1 -l I l 54.0 - -
-43.2- .
f
' 3 2 ~. 4'-
21.6- . 4
-10.8 I' I I I I I I I I I I I I I I I -;
0 5 10 15 20 TIE
-RRFJPAT TOTAL JP FLOW LOOP A O
,t i
i TRIP OF ALL RFP, LOOP B FLOW 0 X10 LBS/UR 1 DIVISION = 13,85 SECONDS 64.8 - 1 I I I 1 I I I I I i l I I l I 54.0 - - 5 43.2 - - O' ...
;32.4 - -
21.6 -- - 10.8- I I I I I I l' I I I I I' I I - Ld
'O' 5 10 15 20 TIME
, AFJPBT TOTAL JP FLOW LOOP B l O
- u. . --. _ _ _ __ . .. -
O TRIP-0F ALL RFP INCllES 1 DIVISION = 11.52 SECONDS
+3' I I l- 1 I I I I l l I I I I I l
)
+177- -
(
-163 - -
-333- - -
)-
-503 l' I I I I I I I I I I I I I I I 0 -5 to 15 20 TIE s
RRLRW RX WATER LEVEL INCH
QUAD CITIES SIMULATOR TRANSIENT TEST FIVIEW TPANSIENT TEST #/ TITLE: d e s a c. af .hll/k h $6 % Eselt4 w L1/ge.s, / DATE: J.- 12 'l I
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- a. Actual plant transient data EVENT:
- b. Analytical or design data DATA: [
- c. Transient data from similar plant PLANT:
/
[ Panel of experts (best estimate) (~ % - COMMENTS:
/O u wd.- a. s e e. Ig ww ca ew .' L v .' % 't
/
Ia LI v e(s. At i / v i 23 uemas aJ s e fssows e -
/ &mme/ 6 valid a-/ a i n eo<yu<nbel Q ?o a ceeola- c e a < i Lui-u to - 4s + rea .
, l/~
(a O
%J 7
p) q QUAD CITIES SIMULATOR TP,A!JS!ENT TEST REVII.*
- 2. Data Comparison Summary VARIABLE C0!'MENTS RESOLUTICN 3
s
/. 2u eb Pw .- W du.s 'f
- L e_mLS 0
t / . S .t r d e c v w
,_ $ ll t_]+ C V t ti_$_g N n ti % 4 L0
/b 3 A ' QI &LC 0- y__L . . ..f c 4 t~* A fU U $ YON
^
- y. .Gn i adL da w .le lle ~ ut i2 s_fu.) v s see atuo w bJ wu p lLt TvA stu
^ Ol n -y m . 6 0 V
/ //14'rr1 p u w e r-bis n. CosAsci.Ies e d](Ly Jte55nre s 3(l' Mc.
nw yessa,e mf.Lic.;e,a 4 of r e-edwo l y l'.ycmM e ) mur > e o in s s lhe m's e v4Mc n wr 4n t o k do nann eodar th v
. }YlCff << % f _.,12 0 Lv J V
- Yl1 l'*> /vba] M iX 91*54 CQG* r i Y Ve' t' v ** 4 fS .
J V
A , k' O~' $ dst- .S ('t.' & r f *3 f I f C-h' C) /} 'l c'< l VI & s 's A lb f O >1 4ht v
e)Mv e .cLauf' n e c ird assoc *t N cf hlIH i
t)ku e f I h /t E es hw. A/o e/_i. u-n.,j :x fo *iece le i d'6de h n o/4niessa <e s,o i 4 e hu>U f n b e li e ; <.5 % _
),e dafu r e s,<. /1' o-f L. P h enk. .Cin sh am .t s e ,
J v c sa.-l} 0-{ fit.r Va.rpt ef cd e er ens e in 3f%a
~
f) v _ V 4.5$ CC l'd
- T$1 ( b 'fJO t< $d- bf_
t s%y1 *T Orwgg O i h } d'('cLk1W5 m ~:
CUAD CIT!ES S!MULATOR o TRAtJSIE!!T TEST REVIEW
- 3. Comparison Results simulator capability to reprcduce the defined transient:
(circle one)
. ACCEPTAB
- b. UtJACCEPTABLE
- 4. Review Board Signatures (dif fering opt ' Ore must be cocumented) bky f 1_.~~
- rd< h /
Y
/ (,. A)
sd , Lo _ 04 u- /% . _C . ,, ,-' 44 _ W V l} j~
// p COMME!JTS :
a T
. \
3
E ] Test Number _1E -l___
- Rev. Number /Date
- _Qa_D 1/14131_
1 Frequency: _ Annual QUAD CITIES SIMULATOR TRANSIEllT TEST 1 SIMULTA!1EOUS CLOSURE OF ALL HAIN STEAM ISOLATION VALVES J I. OBJECTIVES The purpose of this procedure is to test the simulator response to a Simultaneous Closure of All Main Steam Isolation . Valves as required by ANSI /ANS-3.5-1985. II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149 Nuclear Power Plant Simulation Facilities for Use in Operator License Examinations.
III. INITIAL CONDITIONS
- 1. The plant is operating at normal steady state, full power conditions.
I () IV.
- 2. The Main Steam Isolation Valves are open.
DATA COLLECTION
- 1. Setup the ZETA plotter to graph the following variables
- a. Reactor Power (% Neutron Flux) . . . . . . . . . . . . . . .NMAPRMFX
- b. Total Steam Flow.............................MSFSTM
- c. Total Feedwater Flow.........................RRFFW
- d. Reactor Pressure.............................RRPRV
- e. Wide Range Reactor Water Level...............RRLWR
- f. Harrow Range Reactor Water Level . . . . . . . . . . . . . RRLNR
- g. Generator Gross Electrical Power.............EGWMGEN
- h. _ Turbine Steam Flow...........................MSFHPIN
- 1. Total Core F1ow..............................RRFRXT
- j. Recirc-Pump A Loop Flow......................RRPJPAT
- k. Recirc Pump B Loop Flow. . . . . . . . . . . . . . . . . . . . . . RRFJPBT
- 1. Reactor Water Level, Bottom - Top of Vessel..RRLRW l 1 l
Test Numbert _IR-3 Rev. Number /Date: 0, 0 1 /_1 1 4 1 L rrequencyt Annuni O QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS CLOSURE OF ALL MAIN STEAM ISOLATION VALVES V. TEST INSTRUCTIONS
- 1. Ensure the plant meets the initial conditio vi as specified in Section III.
- 2. Enter the data collection points from section IV.
- 3. Close all MSIV's by simultaneously inserting malfunctions RP05A and RP05B. (Group I Isolation Actuation)
- 4. Allow the simulator to run until stable plant conditions are established.
- 5. Graph the variables listed under Section IV.
VI. ACCEPTANCE CRITERIA The following acceptance criteria are to be used to determine () successful test completion:
- 1. The Main Steam Isolation valves close in 23 but sS seconds.
- 2. The reactor scram occurs from Main Steam Isolation Valve position.
- 3. Reactor pressure increases to SRV setpoint.
- 4. Reactor water level decreases to approximately 0 inches.
- 5. Orywell pressure remains fairly constant.
- 6. SRV's cycle to ~91 ease decay heat.
- 7. The Main Steam Isolation valves and their bypasses remained closed throughout the transient.
- 8. The observable change in the parameters correspond in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of nature.
O 2
- - . . _ . - . - - - . . - _ _ _ - - - . - . - . - ~ - - - - - . . . - . . ~ - . . - -
Test Numbert _,TR-3 .
- Rev. Number /Date _ _0 , 01223]11.
Frequency: _ Annual O QUAD CITIES SIMULATOR TRANSIENT TEST
- SIMULTANEOUS CLOSURE OF ALL MAIN STEAM ISOLATION VALVES I
- 9. The simulator shall not fail to cause an alarm or automatic action if the reference plant would have caused an alarm or automatic action, and conversely, the simulator shall not cause an alarm or automatic action if the reference plant would not cause an alarm or automatic action. l l
- 10. The grrph? are similar to the baseline graphs, or if the I baseline data used was the judgement of a panel of experts, their review shall be documented.
VII. LIST OF FIGURES
- 1. Reactor Power (% Neutron Flux)
- 2. Total Steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressure S. Wide Range Reactor Water Level
- 6. Narrow Range Reactor Water-Level Os 7. Generator Gross Electrical Power
- 8. Turbine Steam Flow
- 9. Total Core Flow
- 10. Recirc Pump A Loop Flow
- 11. Recire Pump B Loop Flow
- 12. Reactor Water Level, Bottom - Top of Vessel 3
( CLOSURE OF ALL MSIV'S, REACTOR POKR
% REACTOR POWER l 1 DIVISION = 11.31 SECONOS 125 I l l I I l l l l l l l l l l l .
1 l 4 pmm ......I s 75 N - - 50 - - 25 __ _ I < --- l l l l l l l l l l I I I I O S 10 15 20 TIME NMAPRMFX(1) APRM FLUX LEVELS
Iv CLOSURE OF ALL MSIV's, TOT AL STE AM FLOW I l 6 x10 LBS/IIR 1 DIVISION = 11.S1 SECONOS l 10.8 ! I i i l l I I I I I I I I I I l ; i j l 8.64 - - 6.48 _ _ t 4.32 - - 2.16 - - l l il I l l I I I I l l l l l 1 0 5 10 15 20 TIME MSFSTM TOTAL STEAM FROM RX
1 1 I 1 l N U CLOSURE OF ALL MSIV'S, TOT AL FEED FLOW 6 X10 LBS/11R 1 DIVISION = 11.31 SECONDS 11.88 I I I I I I I l l l 1 l i I l I } 9.50 - - 7.13 - - () - - 4.75 2.38 - - l l l l t ! I I I l l l l l l l l 0 5 10 15 20 TIME 3RFFw TOTAL FEEDWATER FLOW /T V
(
'n CLOSURE OF ALL MSIV'S, REACTOR PRESSUhi Peta 1 OIVI*IOP - 11.31 SECONOS I I I I I I I I I I I I I I i ~l
{~I L - 1200 - 900 - - [v . - 600 - - 300 - - I I l l l l l 1 1 I I I I I I l 0 5 10 15 20 TIME RRPRV RX VESSEL DOME PR ABSOLUTE
- fh, <J
CL OSURE OF ALL MSI'"9, W REACTOR LEVEL INCilES 1 DIVISION = 11,31 SECONDS
+60 I I l & -l l l l i i i i i F 'l I
-20 - -
100 - -
-180 - - -260 - -
I I
-340 I I I I I I I I I I I I I I O 5 10 15 20 TIME l RRL WR RX WTR LVL, WIDE R ANGE l
.O V 1 1
4 M t x l CL OSURE OF ALL MSIV'S, NR REACTOR LEVEL INCL!ES l 1 DIVISION = 11.31 SECONDS l 60 1_,g_,
; ; ; ; ; ; ; ; ; -T 1
48 - - 36 - - m ~ 24 - - 12 - t - I J l i I I I I I I I I I I I I O 5 10 15 20 TIME RRLNR NARROW RANGE LVL t)
C' CLOSURE OF ALL MSIV'S, GENERATOR LOAD MEGAWATTS 1 DIVISION = 11.31 SECONOS 1, 00
, , , , , l l l l l i 800 -
600 - 400 - 200 - - I I I I I I I I ! I I I I I I I 0 5 10 15 20 TIME EG%NGEN MG OUTPUT REAL POWER
G
\,j CLOSURE OF ALL MSIV' S, TURBINE STE AM FLOW 6 gggj,gg x10 1 DIVISION = 11.31 SECONOS
~
l l i I I I I I I l l l l 1 l 1 9.50 - - 7.13 - ( - - 4.75 - - 2.38 - - l I l i l l i I l l I I l l l 0 5 10 15 20 TIME MSFHPIN HP TUR8 INLET = uGW D O i
l O CLOSURE OF ALL WSIV'S, CORE FLOW 6 X10 LBS/flR 1 DIVISION = 11.31 SECONOS 124.92 l l l l l l l l l l l I l l l l 99.94 - [ ; g 74.95 1 O . . L E
'49.97 - -
24.98 - - 1 I I I I I -l l I I I I I I I I o 5 to 15 20 TIME RRFRXT- CORE TOTAL INLET FLOW -
O CLOSURE or ALL Ms!V'S, LOOP A FLOW a F X10 LBS/HR 1 DIVISION = 11.31 SECONOS 64.8 I l l l l l l l l l I I I I I I 54.0 - - [ ,, 43.2 - - 32.4 - N , 21.6 - 10.8 I l I l l I- l l I I I I I I I I
- 0 S 10 15- 2 0 --
TIE RRFJ P AT;- TOT AL J P FL OW L OOP A O
O ! CLOSURE OF ALL MCIV'S, L OOP B FL OW
'l 6
X10 gggjgg
-1 DIVISION =
- 11.31 SECONDS 64.8 I I I l l l l l l l l l l I I I l
54.0 - < 43.2 - - -i i O - -
-'32.4L 21.6- - -
f
-10,3 l l- -l I l l- I l l l l- l' -l l l l 0 -5 10 15 20 TIE RRFJPST- -
TOTAL JP FLOW LOOP B - O
ClotVRE OF ALL WSIV'S INCL!ES 1 DIVISION = 12.08 SECONOS
+347 I I I l l l l l l l l l l l l l
+177 - -
+7 - -
O -
-163 - - -333 - - ~503 I I I l l I I I I I I I I I I l 0 5 10 15 20 TIE MRLRW RX WATER LEVEL INCH O
QUAD CITIES SIMULATOR TRA!1SIEtJT TEST REVIEW TRAt16IE!1T TEST #/ TITLE: Ir f e[ 2 h el,,2ec a d dl % Ps Nl) DATE: d - 13 9 I
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- a. Actual plant transient data EVE!JT:
- b. Analytical or design data DATA:
-c. Transient data from similar plant PLA11T:
h Panel of experts (best estimate) COMMEt1TS:
@ M o M T.
*eebe
@ 1 i
1 . _ _ _ - _ _ - _ - - - - - - - - . - - - - _ - - - -
. - - . - . . - . ~ .
QUAD CITIES SIMULATOR ; TRA!JSIE!.'T TEST REVIEW
- 2. Data Comparisen Summary VARIABLE COMME!JTS RESOLUTIC!J I. /esr Cleas $ ,_L-Ln kv(ne,, b1((
N- +%- I $re --het_+a . ._
- b. !$6 @ S .
2 % so t nr o o rv -
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v w aYh.DVM4f3 YO O _ s **)
~
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& & 144vCChfv15ht'G) b yh ht+ 4 /ug) 2.5 1 /$ !Og y
wJH & A raj.v~ 4(m wd o vessen+ e y v <
. d<iv'es 00:*4 } $4 C (A ($ V$ Y?2 8 f d tad _ __f b y16 f (h VA _ $&ft f p d
._ b6 hk oum os -
lYio .s,./ do<2m4g/& v. v a a I l l l r U .- , , - - - - . . . - . . - - , , , , . . . , _ , - . , ~ , - _ - , . 4,,...,,,--,_,.~e,~...mv..~,,_.._.= , , , ,,-,,,_..--m...-..._,,,
. ,--.7.-,--,..._tr_..... .. -
QUAD CITIES SIMULATOR f\ TPA!JSIE!;T TEST REVIEW
- 3. Comparison Results Simulator capability to reproduce the defined transient:
(circle one)
. ACCEPTABLE
- b. UtJACCEPTABLE
/ -
- 4. Review Board Signatures (differing cpiri ne must be documented)
_ , f f bli? " - .
. l(f,fQ, '
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"J v '
r ,, , COMMEtJTS:
\
W M t
, Test Numbert TR-4 .. Rev. Number /Date s A 9111A/91 Frequency _ Annual b o QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS TRIP OF ALL REACTOR RECIRCULATION PUMPS I. OBJECTIVES The purpose of this procedure is to test the simulator response to a simultaneous Trip of All Reactor Recirculation Pumps as required by ANSI /ANS-3.5-1985. II. REFERENCES
- 1. ANSI /ANS-3.5-1985 Nuclear Power Plant Simulators for in Operator Training. -
- 2. Reg. Guide 1.149: Nuclear Power Plant Simulation Facilities for Use in Operator License Examinations.
III. INITIAL CONDITIONS
- 1. The plant is operating at normal steady state, full powe4 a conditions.
IV. DATA COLLECTION 1
- 1. Setup the ZETA plotter to graph the following varia?>1eet
- a. Reactor Power (% Neutron Flux) . . . . . . . . . . . . NMAPRMPX
- b. Total Steam Flow..........................MSFSTM
- c. Total Feedwater Flow......................RRFFW
- d. Reactor Pressure..........................RRPRV
- e. Narrow Range Reactor Water Lovel..........RRLNR
- f. Total Core Flow...........................RRTRXT
- g. Recirc Pump A Loop Flow...................RRFJPAT
- h. Recirc Pump B Loop Flow...................RRFJPDT
- i. Jet Pump #1 F1ow..........................RRFJP(1)
- j. Jet Pump #6 Flow..........................RRFJP(6)
- k. Jet Pump #11 F1ow.........................RRFJP(11)
- 1. Jet Pump #16 Plow.........................RRFJP(16) 1
I . Test Number: _TR-4 , _ _ _ l Rev. Number /Date _Q.t._QlilillL { Frequency _ Annual ] QUAD CITIES SIMULATOR TRANSIENT TEST 1 d SIMULTANEOUS TRIP OF ALL REACTOR RECIRCULATION PUMPF V. TEST INSTRUCTIONS
- 1. Ensure the plant meets the initial conmitions as specified in Section III.
i 2. Enter the data collection points from Section IV.
- 3. Trip both Reactor Recirculation Pumps by simultaneously inserting malf unctions RR02A and RR02B. (Recric Pump Field
- Breaker Trip)
- 4. Allow the simulator to run until stable plant conditions are established.
- 5. Graph the variables listed under Section IV.
j VI. ACCEPTANCE CRITERIA The following acceptance criteria are to be used to determine ( successful test completion:
- 1. Both reactor recirculation pumps trip.
- 2. Reactor recirculation loop flows decrease to natural circulation value.
- 3. Turbine generator and reactor feed pump trips occur due to level swell. -
- 4. Reactor pressure decreases slightly.
- 5. Drywell pressure remains fairly constant .
- 6. The observable change in the parameters correspond in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of nature.
, 7. The simulator shall not fail to cause an alarm or automatic action if the reference plant would have caused : an alarm or automatic action, and conversely, the simulator shall not cause an alarm or automatic action if the reference plant would not cause an alarm or automatic action.
Test Number TR-4 Rev. Number / Dates 0. 01/14/91 Frequency: Annual n
~-
i QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS TRIP OF ALL REACTOR RECIRCULATION PUMPS
- 8. The graphs are similar to the baseline graphs, or if the baseline data used was the judgement of a panel of
- experts, their review shall be documented.
VII. LIST OF FIGURES
- 1. Reactor Power (% Neutron Flux)
- 2. Total Steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressure
- 5. Harrow Range Reactor Water Level
- 6. Total Core Flow
- 7. Recirc Pump A Loop Flow
- 8. Recirc Pump B Loop Flow
- 9. Jet Pump #1 Flow
- 10. Jet Pump #6 Flow
- 11. Jet Pump #11 Flow
- 12. Jet Pump #16 Plow O
O 2
(~x Y .] TRIP OF SOTH REACTOR RECIRC PUMPS
% REACTOR POWER 1 DIVISION = 16,74 SECONDS I 125 I I I I I I I I I I I l l l t I 100 - -
q 75 - LJ , l 50 - - 25 -- -- l 1 I I I I I I I I I i i I ! l I l 0 5 10- 15 20 TIME NMAPRHFX APRM FLUX LEVELS
-L(3)
-...-- . . . . . . . . . . . . . . - - ~ . . - . ~ . - . . . - ~ . ~ . . . . - - - . _
1 9 O , l l TRIP OF BOTH REACTOR RECIRC PUMPS
'X10 0 LBS/llR 1 DIVISION = 16.74 SECONDS 10.8 o I I I l- 1 I I I I I I I I I I I 8.64 - -
6.48-.- 4.32 '
- n _
2.16- : - he l I l I l -l I l I I I I i--i i - ! 0- '5~ ?io 15- 20 i TIME 1
-MSFSTM TOTAL STEAM FROM RX
, O
1 l I (~ L l TRIP OF DOTH REACTOR RECIRC PUHPS 6 X10 LDS/11R 1 OIVISION = 18,74 SECONOS l l I I I I i l l I I l I R I j 9.50 -1 -
. J s 7.13 - -
(h 4.75 _ 2.38 - - l l l l l l l ? 1 ! l l 1,_ l II_i _ l l 0 5 10 15 20 , TIME l RRFFW TOTAL. FEE 0 WATER Ft.0W 1
. - . _ _ _ _ _ _ - - . - - _ . _ - . _ . . .~~ . . . _ _ . . _ _ _ . . . _ _ _ _ _ _ . - _ _ _ . . _ _ _ . - _ _ _ _ _ . _ .
TRIP OF BOTH REACTOR RECIRC PUMPS PSIA 1 DIVISION = 18.74 SECONOS
'~ T I I')
l I I I l I l I l~ l i ll 1200 - - (
~
900 - V 9 600 - - 300 - -
. ~
l l l l l f I I_ l I i ! <, I- 1 L -l 0 5 10 15 20 TIME RRPRV RX VESSEL DOME PR ABSOLUTE r"% l %
O l TRIP OF BOTH RE ACTOR RECIRC PUMP's INCt!I:!: 1 DI'ItION = 18.74 SECONDS 60 j p.7 ; j , , , , , 7;- ; 1 l
.g 36 - .
2Ai - - l 12 - - I l l- - l_ J l l I kl l l I i l l I 0 !- 10 15 20
'l ?ML RRLhR NARROW RANGE LVL 9
+ -
-D V.
TRIP OF . BOTH RE ACTOR RECIRC PUMPS x10 6 LBS/ilR 1 DIVISION = 18.74 SECONDS 124.92
-l l l i l i l i i i l i 9 ~
99.94 74.95 _ - f' 1 49.97. - _ 24.98 - - l l I l l 1 1 I l -l I 1 l l 1 -l 0 5 10 15 20 TIME RRFFXT CORE TOTAL INLET FLOW o 6, - __ m-_ma _ _ _ . - _ _ - _ _ _ _ _ _ .
O TRIP OF BOTH REACTOR RECIRC PUMPS 6 x10 LBS/IIR 1 DIVISION = 18.74 SECONOS
'8 I I I I I I I I I i l l l l I I 54.0 - -
~
9 43.2 - - 32.4 - g
- I _
21.6 - - 10.8 I I I I I I I I I I I I I I l 0 5 to 15 20 TIHE RRFJPAT TOT AL J P FL OW L OOP A O
J l 15 N e I TRIP ' 0F-- BOTH RE ACTOR RECIRC PUMPS 6 gggj,gg X10
-1 DIVISION = 18.74 SECONOS 64.8 I I I l l I I I I I I I -l I- 1 I 54.0 -]
43.2 - - 32.4- - --
-21.6
.to,e i I I I l- -l I- 'I l- 'l- I -- l- l- - l- I -l 0- 5' 1 0 '15 20
. TIME
'RRfJPBT. TOTAL JP FLOW LOOP 0 0
O TRIP OF BOTH REACTOR RECIRC PUMPS' r
-t 6
X10 LBS/HR 1 DIVISION = 18,74 SECONDS . I I I I I I I I I I I I I I I I I 4.32 3.24 - - t 2.16 - - 1 1.08 - 1 h
. Y _
l 1 1 I I 'l i I I I I I l l I 0 5 10 15 20 TIME i
-RRFJP1 LOOP A INDV JP #1 FLOW O
e -, ,, -m-+q- c ws
i TRIP OF BOTH REACTOR RECIRC PUMPS l 6 X10 LBS/flR 1 DIVISION = 18.74 SECONOS 5.4 I I I I I l l I I I I I I I I I 4.32 l 3.24 - - v . . 2.16 - - l 1 08- -'- - I I I I I I I I I -l l I I i -l 0 5 10 15 20 TIME RRFJP6 LOOP A INDV JP #6 FLOW [ .
. _ - - - . ~ . - . - . . . - .-_ . .
TRIP OF'BOTH REACTOR RECIRC PUMPS 6 X10 LBS/ilR 1 DIVISION = 18.74 SECONDS 7.2 I I I I I I I I I I I I I I I I 5.76 - - J 4.32 - - 2.88 - - 1.44 - 1 I I I I I I I I I I I I I I l-0 5 10 15 20 TIME RRFJP11 LOOP -8 INOV JP # 11 FLOW lk. L
. . . - . . . - . - . . - - . - _- - - - -..- =.-- - - -. .
1 A_ j \) j l TRIP OF BOTH REACTOR RECIRC PUMPS 6 X10 LBS/IIR 1 DIVISION = 18,74 SECONOS 7.2 , , , _, , ; , 5.76 - J 4.32 - - O . - - 2.88 - - { 1.44- - l l- 1 I I I I I I I I l- 1 I I I O .5 10 15. 20 TIME i RRFJP16 LOOP 8 INOV JP f16 FLOW
QUAD CITIES SIMULATOR b) NJ TRANSIENT TEST REVIEW TL-5) TRANSIENT TEST #/ TITLE: Li f a J. S Sk 7 /+ fe,d bc tredd/m g_p DATE: J-lb-hl
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- a. Actual plant transient data EVENT:
- b. Analytical or design data DATA:
- c. Transient data from similar plant PLANT:
- d. Panel of experts (best estimate)
/3 COMMENTS: O /D Sko s la$ r e v > w a-e k s c$ p {n b bcd ew. e6 5'./3c>or1.5C-s
> . Fiskt thwat 46 na.s w < f fc <
~
s , ,n n( aA-1 n sc/e f - M o V ,
l l
,g.
QUAD CITIES S!MULATOR (j. TRANSIENT TEST REVIEW
- 2. Data Comparison Summary VARIABLE COMMENTS RESOLUTICU l.4MA *:lve (5)LJk g
m A 1sw e-v i n ( / l.t.- S L e)~ {$r /. O?L ClC W S c~ w ajL. L/M ln ble. s 2 . _Lu , 8 Clw v. ~ tt A % Lnkd loy B. 2 . s e e I> eloa ess o c w-ri o s.) l
- l. 6 tu ? f Y l ?> c' 6t.//u h St t.<.. t' Y) / $4 C r fs< "i C /is (* <> v L hlc-s<)
s d c2 tt S e < E I) e i e C r est s e in r tr yt n o er e. l'cctvc O u r V1 O Q U J '
$0C& a N~$4t'% d2Ch/b)m' fo ot S &c rf f y ? O { Cc I V1 n lS l *? *
(% )) '
- We va n f<semse bnf ets-i/ }x t'h W 00 we< 1 n e re ws. e AAA(f b[t>tu / H C y Cic S C #3 (. 5 t7f0f C) C' d. C.& 4' . .$u $
&c C C tY & rt N l O P d vst S o et o k H2 &t?Vt..cN 'L4syt/vsIS v-Y/s/lI't G L_$I d #Gis 3 Pf fQ r O b lc'-syr *$ s h7 d C f a - -
<<'?O t&Y Vid I~ ]2 & Y f.. D y z)& / u e 2 h e i
A iO l'] A V!1 C (, </ u? $ / Vf (3y' r p/ (L.yy k by 4.$ )) e e Q t*' c? Y Y cc hec $< v , s.
cy QUAD CITIES SIMULATOR TRANSIENT TEST REVIEW -(w]
- 3. Comparison Results Simulator capability to reproduce the defined transient:
(circle one) kCCEPTAB
- b. UNACCEPTABLE
- 4. Review Board Signatures (dif fering opinions must be documented) f)$Y]f f rY~
ANIA ?W<ft /2tt J (M1 LL %2kr f lh' _ Y v COMMENTS: 10 \s' / \ V' 3
Test Number: TR-5 Rev. Number /Date: 0. 01/14/91 Frequency: Annual C\ U QUAD CITIES SIMULATOR TRANSIENT TEST TRIP OF A SINGLE REACTOR RECIRCULATION PUMP I. OBJECTIVES The purpose of this procedure is to test the simulator response to a Trip of any single Reactor Recirculation Pump as required by ANSI /ANS-3.5-1985. II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149: Nuclear Power Plant Simulation Facilities for Use in Operator License Examinations.
III. INITIAL CONDITIONS
- 1. The plant is operating at normal steady state, full power conditions.
.O
(_)\ IV. DATA COLLECTION
- 1. Setup the ZETA plotter to graph the following variables:
- a. Reactor Power (% Neutron Flux) . . . . . . . . . . . .NMAPRMFX
- b. Total Steam Flow..........................MSFSTM
- c. Total Feedwater Flow......................RRFFW
- d. Reactor Pressure..........................RRPRV
- e. Narrow Range Reactor Water Level..........RRLNR
- f. Total Core Flow...........................RRFRXT
- g. Recirc Pump A Loop Flow...................RRFJPAT
- h. _Recirc Pump B Loop Flow...................RRFJPBT
- i. Jet Pump #1 Flow..........................RRFJP(1)
- j. Jet Pump #6 Flow..........................RRFJP(6)
- k. Jet Pump #11 Flow.........................RRFJP(11)
- 1. Jet Pump #16 Flow.........................RRFJP(16) 1
. _ _ . . _ , . . . _ _ - m . ~._ _._ . . . . __ _ _ _ . . _ . _ _ - . . . . . - , . . _ . . . - . . ..-m .
~
Test Number: TR-5 , Rev.; Number /Date: 0, 01/14/91 Frequency: Annual
;t QUAD _ CITIES SIMULATOR' TRANSIENT TEST TRIP OF A SINGLE REACTOR RECIRCULATION PUMP
-V.- TEST INSTRUCTIONS-1 ~. Ensure the plant meets the initial conditions as specified in Section III.
2.- Enter the data collection points from Section IV.
- 3. Trip _1A Reactor Recirculation Pump by inserting malfunction RR02A. (Recirc Pump Field Breaker-Trip)
- 4. . Allow the simulator to run until stable plant conditionsi are established.
5.- Graph the variables listed under-Section IV. VI. ACCEPTANCE. CRITERIA The following acceptance criteria are to-be used to determine successful test completion:-
)
- 1. Only the 1A Reactor Recirculation Pump trips.
- 2. Reactor water level increases approximately'5 inches.
- 3. Reactor-pressure remains fairly constant.
4.; -Reactor powerfdecreases to-approximatelyf75%.-
- 5. The' observable change in the parameters correspond-in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of. nature.
- 6. The simulator shall:not fail to cause an alarm or-automatic action;if the reference plant would-have caused an alarm-or automatic action, and conversely, the simulator shall not cause an alarm or automatic action if-the reference plant.would not cause an alarm or automatic action.
- 7. The1 graphs are similar to the baseline-graphs, or if the baseline' data used was the judgement of a panel of experts, their review shall be documented.
2
Test Number
- _TR-5 Rev. Number ) ate : 0, 01/14/91 Frequency: Annual
(' q)-n QUAD CITIES SIMULATOR TRANSIENT TEST TRIP OF A SINGLE REACTOR RECIRCULATION PUMP VII. LIST OF FIGURES
- 1. Reactor Power (% Neutron Flux)
- 2. Total Steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressure 5._ Narrow Range Reactor Water Level
- 6. Total Core Flow
- 7. Recirc Pump A Loop Flow
- 8. Recirc Pump B Loop Flow
- 9. Jet Pump #1 Flow
- 10. Jet Pump #6 Flow
- 11. Jet Pump #11 Flow
- 12. Jet Pump #16 Flow C
L.)\ () 3
TRIP 0F SINGLE REACTOR RECIRC PUW
% REACTOR POWER 1 DIVISION = 13.07 SECONOS 125 I I I I I I I I I I I I I I I I 100 -
75 - - O 50 - - 25 - - I l l l- 1 I I I I i 1 'l l I I I 0 5 to 15 20 TIE NMAPRW X APRM FLUX LEVELS LO
- 1 l
1
O TRIP 0F SINGLE REACTOR RECIRC PUW 6 x10 333j,33 1 DIVISION = 13.07 SECONOS I '8 ~ I I I I ! I I I I I I I I I I I 8.64 - - 6.48 - - V 4.32 - - 2.16 - -
- ~
l l' I l_ l l I I I I I I I I I I o 5 to 15 20 TIE MSFSTM TOTAL STEAM FROM RX O
. - . _ . . . . _ - . - - . - . - . ~ . . - - _ _ . . . . _ ,
4 O TRIP 0F SINGLE REACTOR RECIRC PO W x10 6 gggj,gg 1 DIVISION = 13.07 SECONOS 11.88 I -l i I I I I I I I I I I I I I 9.50 - T - 7.13 -
. . 4 O os - -
2.38- - - I I l l l I l- 1 I I l l l l l' I o 5 to 15 20 TIE
- RRFFW TOTAL FEE 0 WATER FLOW-O i
~O TRIP OF SINGLE REACTOR RECIRC PUW - PSIA 1 D'. VISION = 13.07 SECON06 I I I I I I I I I I I I I I I I 1200 - - 900 . 300 - - I I ! I I I I I I I I I I I I I o 5 10 .to 20 TIE RRPRV RX VESSEL DOE PR - ABSOLUTE O
TRIP OF SINGLE REACTOR RECIRC PUW INCillCS 1 DIVISION = 13.07 SECONDS 60 l I I I I I I I I I I I I I I I 48 - - N 36 - -
. m 24 ,,_
12 - - l i i I I I I I I I I I I I I I 0 5 to 15 20 TIE RRLNR NARROW RANGE LVI. O
. - .. . - . . -. . _ _. - ~. . . - - . . . - . _ . _ _ . _ . .
I TRIP 0F REACTOR RECIRC POW 0 X10 LBS/IIR 1 DIVISION = 13.07 SECONOS 124.92 l l l l l l l l l l l l l l l l 99.94 - - 74.95 49.97 - - 24.98 - - I I I I I I I I I I I I I I I I 0 5 10 15 20 TIE RRFRXT CORE TOTAL INLET FLOW Oi
I A-V TRIP OF SINGLE REACTOR RECIRC POW 6 x10 Lggjgg 1 DIVISION = 13.07 SECONOS I I I I l l l l l l l l l l l 1
-+48.24 -
+31.68
+15.12 --
-1.44 ~. -
-18.00 l I I I I I I I I I I I I I -l l' 0- 5 10 15 20 TIIE RRFJPAT TOTAL JP FLOW LOOP A NOTE: THIS VARIABLE SHOWS REVERSE FLOW AS BEING NEGATIVE O
TRIP OF- SINGLE REACTOR RECIRC PUW x10 6 LBS/IIR' 1 DIVISION = 13.07 SECONOS 79.2 I I I I I I I I I I I l l l l l 63.36 - .-
-47.52 - -
31.68 - - 15.84 -- - l -l l l 'l l l l l l l l l 1 I I 0 5 10 15 20 $ TIE . RRFJP8T TOT AL J P FL OW L OOP B r3-V
i O TRIP 0F SINGLE REACTOR RECIRC PUW 6 X10 gggjggg 1 0! VISION = 13.07 SECONOS
-l l I I l l l l l l l l l l l l 4.32 - -
3.24 - - 4
\
1,08 - - I I I I I I l l I I I I I I I I 0 5 10 15 20 TIE RRFJP1 L OOP A INOV J P f 1 FL OW ' O
-. - - - - - . . . - . - . ~ _ . . - . _ . . _ . - . _ . - _ - . - _ . _ - - ., O' TRIP 0F SINGLE REACTOR RECIRC PUW l 6 X10 LBS/ilR ; 1 DIVISION = 13.07 SECONOS '
^
l i I I I I I I l l I I I I I I 4.32 -- - 3.24 - - o 2.1e - - -
\
~
1.08- - - 1 I I I I I I I I l l l l l l 1 0 5 10. 15 20 TIE RRFJP6 LOOP A INOV JP #6 FLOW O
i 1 I 1 O TRIP 0F SINGLE REACTOR RECIRC PUW 6 x10 gggjgg 1 DIVISION = 13.07 SECONOS 7.92 I I I I I I I I I I I I I I I I 6.34 - - 4.75 - -
-3.17 - -
1.58 - - I I I I I l I l I I I I l l l I 0 5 10 15 20 TIE - RRFJP11 LOOP B INOV JP #11 FLOW l l O l u
.+
TRIP OF SINGLE REACTOR RECIRC PUW 6 X10 LBS/ilR 1 DIVISION = 13.07 SECONOS 7.2 , , 5.76 - - 4.32 -- - I 2.88 - - 1.44 1 I I I I I I I I I I I I I I I 0 5 10 15 20 ilE RRFJP16 LOOP 8 INOV JP f16 FLOW O
. .~ - ,
QUAD CITIES SIMULAT0h
-("n
) TRANSIENT TEST REVIEW (fkth TRANSIEllT TEST #/ TITLE: ik u C rl ,y */~ c ,, ,[b 1 a d eg.s s e 2 e y, l. ,
r s DATE: ,2 - /J - 9 1
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- a. Actual plant transient data EVENT:
- b. Analytical oc design data DATA: _
- c. Transient data from similar plant PLANT: --
- d. Panel of experts (best estimate)
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e, QUAD CITIES SIMULATOR
'( TRANSIENT TEST REVIEW 2, Data Comparison Su.r. mary VARIALLE C0w1ENTS RESOLUT tN
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QUAD C'tTIdS H MULATOR TPANSTF.NT TEST IVIEW J. C ct.p a ri s o's- Results Siinulaw" C 7 pat;i. lit y t o reproduce the defir.ed transient: , (circio ot.er
- a. ACCEPTA. BLE-
- b. UNACCEPTABLE s
4, Review Boa rd Signatures (dif f ering opinior.s must be ecumented; ,
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- 3
Toct 14 umber _ Tit- 6 _ _ . Rev. Number /Dato s .0, 01/11/1L Frequencyt _Aninul _ 3 (V QUAD CITIES LIMULATOR TRANSIEllT TEST MAIN TURBI!4E TRIP (MAXIMUM POWER LEVEL W}lICil DOES NOT RESULT IN A REACTOR TRIP) I. OBJECTIVES The purpose of this procedure is to tout the simulator response to a Main Turbine Trip (maximum power level which does not result in a reactor trip) as required by A!1SI/A!1S
-3.5-1985, II. REFERE!1CES
- 1. ANSI /ANS-3.5-1985 11uclear Power Plant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149: liuclear Power Plant Simulation ,
Facilities for Use in Operator License 2xaminations. III. INITIAL CO!4DITIO!1S r^\ (_) 1. The turbine is synchronized to the grid with the plant operating at steady state 540% power conditions. IV. DATA COLLECTION
- 1. Setup the ZETA plotter to graph the following variabics:
- a. Reactor Power (% Neutron Flux)............NHAPRMFX
- b. Total Steam F10w..........................MSFSTM -
- c. Total Feedwater Flow......................RRFFW -
- d. Reactor Pressure..........................RRPRV
- e. Wide Range Reactor Water Level............RRLWR
. f. Narrow Range Reactor Water Level..........RRLNR
- g. Generator Gross Electrical Power. . . . . . . . . . EGWMGEN
- h. Turbine Steam Flow........................MSFHPIN
- 1. Total Core Flow...........................RRFRXT
'j . Recirc Pump A Loop Flow...................RRFJPAT
- k. Recirc Pump B Loop Flow...................RRFJPDT o 1
l
Test Number: TR-6 Rev. Number /Date: 0, 01/14/91 Trequency: . Annual . QUAD CTTIES SIMULATOR TRANSIENT TEST MAIN TURBINE TRIP (MAXIMUM POWER LEVEL WHICH DOES NOT RESULT IN A REACTOR TRIP) V. TEST INSTRUCTIONF
- 1. Ensure the plant meets the initial conditions as specified in Section III.
- 2. Enter the data collection points from Section IV.
- 3. Trip the Main Turbine by inserting malfunction TC01. (Main P
Turbine Trip)
- 4. Allow the simulator to run unt'l stable plant conditions are established.
- 5. G=2ph the variables listed under Section IV.
VI. ACCEPTANCE CRITERIA The following acceptance criteria are to be used to determine successful test completion: C
- 1. The reactor does NOT trip.
- 2. The observable change in the parameters correspond in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of nature.
- 3. The simulator shall not fail to cause an alarm or automatic action if the reference plant would have caused an alarm or automatic action, and conversely, the simulator shall not cause an alarm or automatic action if the reference plant would not cause an alarm or automatic action.
- 4. The graphs are similar to the baseline graphs, or if the baseline data used was the judgement of a panel,of experts, their review shall be iocumented.
O 2
Test Number _IR-6 Rev. Number /Date: 0, 01/14/91. Frequency: _ Annual QUAD CITIES SIMULATOR TRANSIENT TEST MAIN TURDINE TRIP IMAXIMUM POWER LEVEL WHICH DOES NOT RESULT IN A RFJsCTOR TRIP) VII. LIST OF FIGURES
- 1. Reactor Power (% Neutron Flux)
- 2. Total Steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressure
- 5. Wide Range Reactor Water Level
- 6. Narrow Range Reactor Water Lovel
- 7. Generator Gross Electrical Power h-- 8. Turbine Steam Flow
- 9. Total CorH Flow
- 10. Recirc Pump A Loop Flow
- 11. Recirc Pump B Loop Flow ,-
O O 3
O MAIN TUROINE TRIP (MAX POMR - NO REACTOR TRIP)
% REACTOR POWER 1 DIVISION a 12.10 SECONOS 125 --
1 I I I I I I I I I I I I I I 1 100 - - 75 - - 50 - E 25 - 1 I I I I I l l l l l 1
-l l I I 0 5 10 15 20 TIE NWAPRWX(1) APRM FLUX LEVELS O
.-___. .--.- ._-_ .- - .-- -. - .-.- _....-.. ,- - . ~ . . - . . - . - - . - .
O MAIN-TURBINE TRIP (MAX POM R - NO REACTOR TRIP) l 6 X10 33g73;p 1 DIVISION = 12.10 SECONDS 10.8 i l l I I I I I I I I I I l l I I l l 8.64 - - O
. \
4.32 - - 1 - 2.16- - I 1 1 I I .I I I I I I I I I I I 0 5 -10 15 20 TIE MSFSTM TOTAL STEAM FROM RX O
O s MAIN TUR8INE TRIP (WAX POMR - NO REACTOR TRIP) 6 X10 LBS/HR 1 DIVISION = 12.10 SECONOS
'80 1 I I I I fI I I I I I I I I i 41 9.50 -. -
7.13 - - i 4.75 - - 2.29 - - l- 1 I I I I I I I I I I I I I I 0 5 10 15 20 TIME RRFFW TOTAL FEE 0 WATER FLOW O
.. ~ . . . . _ . . . . . - . - _ - . _ . - - . . - _ _ _ _ _ - - _ _ . . - - . . - . . . . . _ . _ _ . . .
a O MAIN TURBINE TRIP (MAX POMR - NO REACTOR TRIP) PSIA 1 DIVISION = 12.10 SECONOS 1500 l I I I I I I I I I I I I I I I 1200 - - 900 - - O . . 600 - 300 - - I I i 1 1 I I I I l- 1 I I I I I l 0 5 10 15 -20 TIE RRPRV RX VESSEL DOME PR ABSOLUTE-O
..,.,_.. ,, .~,-....- - - _ . ._....._.. .-._ , -_ . _ - . _ , ~ . , _ _ ~ . , . . , . . --
O MAIN TUR8INE TRIP (MAX POM R - NO REACTOR TRIP) q l l INCHES 1 DIVISION = 12.10 SECONDS
+60 I I I I I I I I I I I I l l l l
+36 -
+12
-12 - -
-36 -
~60 I l l I , .1 l I l I l l l l I I I 0 5 10 15 20 TIME RRLWt RX WTR LVL, WIDE RANGE O
4 MAIN TURt!NE TRIP (MAX POER - NO REACTOR TRIP) INC11ES 1 DIVISION = 12,10 SECONDS I I I i l l l l l l l l 1 I I i 48 - - 36 - - 24 - - 12 - - 4 -l i I -l I I I . I I I I I I I I I o 5 to 15 20
- TIE
- RRLNR NARROW RANGE LVL O
ee- =,-s- ,-+ ,y e .-,m.p,w,4wg-.g.. e. -,w~vw,- < * - - ~ ~ s rwr+ ~ +c-w m . v m-e m w+s-v r-,,v--*-~-ow- www=*~w- ,--r,enu
._ .-- . . . - ~ . - . _ ..-. - . -. -..... . - .. . - ._. . - . . . - .~ ._ . - -- -. .
i i I I i t O MAIN TURBINE TRIP (MAX POWR - NO REACTOR TRIP) > ! MEGAWATTS 1 1 DIVISION = 12.10 SECONOS 1,000 I I I I I I I I I I I I I I I I 800 - - 600 . - O . . 400 - - 200 - - It I I I I I ,1 I I I I I I I I I o- 5 to 15 20 TIE EGWGEN MG OUTPUT REAL POM R-O
i i l
- O i
I .i MAIN TUR9INE TRIP (MAX P0ER - NO REACTOR TRIP) 6 X10 gggj,gg 1 DIVISION = 12.10 SECONOS 11.88 _ 1 I I I I I I I I I,,I I I I I I ]- 9.50 - 4 7.13 - - O . . 4.75 - 4 2.30 - , 1 I I I I I I I i I i l l I I I 0- 5 to 15 20 TIE WSFHPIN HP TUR8 INLET FLOW-O
1
- O l
MAIN TURBINE TRIP (MAX POM R - NO REACTOR TRIP) 6 x10 LBS/11R ! 1 DIVISION = 12.10 SECONDS l 108 ; ; ; ; ; ; ; ; ; ; ; ; ; ; ; 86.4 - - 64.8 O . . 43.2 - - 21.6 I- 1 i 1 I I I I I I I I I I I I 0 5 10 15 20 TIE RRFRXT CORE TOTdL INLET FLOW O
I O MAIN TUR8INE TRIP (MAX POMR - NO REACTOR TRIP) 6 X10 LBS/11R 1 O! VISION = 12,10 SECONOS 64.8 , , , , , , ; ; , , ; ; ; i i i 54.0 - -
. e 43.2 - -
32.4 - - 21.6 - - 10.8 i L i l I I I I l l I I I I I I - 0 5 10 15 20 TIE ARFJPAT TOTAL JP FLOW LOOP A O
l i l O l l d MAIN TURRINE TRIP (MAX POER - NO REACTOR TRIP)- 1 0 X10 LDS/IIR 1 DIVISION = 12,10 SECONOS l 64.8 I I I I I I I I I I I I I I I l 54.0 - - 43.2 - - 32.4 - - 21.6 - - i 10.8 1 1 1 I I I I I ._ l l I I I I I 0 5 - 15 20 TIME l RRFJP8T TOTAL JP FLOW LOOP 8
- O
_ - . = _ _ - - = _ _ _ _ . . _ . ,I
- QUAD CITIES 1;MULATOR s
TPA!JSIENT TEST REVIEW TRANSIENT TEST #/ TITLE: _MAtimsm kc4 ( Pm # fd,+ -. i2 _ l~ i I
" ATE: J -/3 *)l
! 1. Baseline data utilized for test comparison in order of
- preference (circle appropriate choices)
I j a. Actual plant transient data ! EVENT: i' ! b. Analytical or design data DATA: l c. Transient data from similar plant i- ) PLANT: {.
- d. Panel of experts (best estimate)
COMMENTS: l Q (d Es e m. S k A a., "b. \ , a cQ %, m w wh a G Lul. - l 9 t N!c s v u n S e ;
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QUAD CITIES SIMULATOR TF.ANS!ENT TEST REVIEW
- 2. Data Comparison Summary VARIABLE COMMENTS RESOLUTION j . Te d 4 e i Cl> J +L. e. t% s k J- l- Se e l> elo w LJCL + F4/[
$ M e.$ % LI t R ic L. w r<. s's 2- S ex )= e (w
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bu _l3?m { 4dUfczv v_.o/of wffpr.s v 1?$b C0 r"Ye=6 e6 ml N a & vG>wr? d-( /H W/b *s h v . A/o Olt co s xs, wik ,,-e r <i wg i,c w n - % ,,,c :<a s 5 J he.e w-ne tht </d1 cf n cndiv e res ch di4- s.b,$b n noes v i .i U ??rO, N'/ f'2VGe% 2k k} o O r"dde < b oA lOdl'3 ft b C t/0 M ' a v( '5e \ . Tlw Attbw . h o u Vi C e { / nc+-t'6t 5 ec? u a-, JY Obn t < r i ? r / 5'
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p OUAD CITIES SIMULATOR ( _ TRANSIENT TEST REVIEW
- 3. Comparison Results hmulater capability to reproduce the defined transient:
(circle One)
-~
(a , ACCEPTABL L )
- b. UNACCEPTABLE
- 4. Review Board Signatures (dif fering opinions must be documented) bk i r~ /:h$'&
._ d;sh % S 4 % Q A r.:
. ! t. 0/ -.-
u /fQld
' O, ~
o CCMMENTS: o C _ J
f Test Number: TR-7 Rev. Number /Date: 0, 01/14/91 Frequency: _bnnual QUAD CITIES SIMULATOR TRANSIENT TEST l MAXIMUM RATE POWER RAMP I. OBJECTIVES The purpose of this procedure is to test the simulator response to a Maximum Rate Power Ramp as required by ANSI /ANS
-3.5-1985.
II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in operator Training.
- 2. Reg. Guide l'.149: Nuclear Power Plant Simulation i
Facilities for Use in Operator License Examinations. III. INITIAL CONDITIONS
- 1. The plant is operating at normal steady state, full power con.ditions.-
' IV . - DATA COLLECTION
- 1. Setup the ZETA plotter to graph the following. Variables
- a. Reactor Power (% Neutron Flux) . . . . . . . . . . . .NMAPRMFX
- b. Total Steam Flow....................s. ....MSFSTM
- c. Total Feedwater Flow..r...................RRFFW
- d. Reactor Pressure..........................RRPRV
- e. Wide Range Reactor Water Level........-....RRLWR 1
- f. Narrow Range Reactor Water Level..........RRLNR- ,
g.. Generator Gross Electrical Power..........EGWMGEN !
- h. Turbine Steam Flow........................MSFHPIN
- 1. Total Core Flow...........................RRFRXT.
.j. Recirc-Pump A Loop Flow...................RRFJPAT
- k. Recirc Pump B Loop Flow...................RRFJPBT O 1 1
Test Number! .TR-7 Rev. Number /Date: 0, 01/14/91 Frequency: Annual Ob QUAD CITIES SIMULA'20R TRANSIENT TEST MAXIMUM RATE POWER RAMP V. TEST INSTRUCTIONS
- 1. Ensure the plant meets the initial conditions as specified in Section III.
- 2. Enter the data collection points from Section IV.
- 3. Reduce power via master recirc flow control station to 75%
at the maximum rate.
- 4. Increase power via master recirc flow control station to 100% at the maximcm rate.
- 5. Graph the variabica listed under Section IV.
VI. ACCEPTANCE CRITERIA The following acceptance criteria are to be used to determine successful test completion: (O_s/ 1. Main turbine bypass valves shall NOT cycle.
- 2. The reactor and turbine shall NOT trip.
- 3. Manual intervention will not be required to bt'ing plant conditions to steady state. If manual intarvention is required, stabilize the plant, make the appropriate adjustments to the control systems, an3 reperform the test.
- 4. The observable change in the para **Psrs correspond in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of nature.
- 5. The simulator shall not fail to cause an alarm or automatic action if the reference plant would have caused an alarm or automatic action, and conversely, the simulator shall not cause an alarm or automatic action if the reference plant would not cause an alarm or automatic action.
l
- 4. The graphs are similar to the baseline graphs, or if the baseline data used was the judgement of a panel of l -s experts, their review shall be documented.
\_) 2
l - Toot Number TR-7 Rev. Number / Dates 0. 01/14/91 Frequency: J n n_u a l O QUAD CITIES SIMULATOR TRANSIENT TEST MAXIMUM RATE POWER RAMP .i VII. LIST OF FIGURES i
- 1. Reactor Power (.% Neutron Flux)
- 2. Total Steam Flow
- 3. Total.Feodwater Flow
- 4. Reactor Pressure
- 5. Wide Range Reactor Water Level
- 6. Narrow Range Reactor Water Level i 7. Generator Gross Electrical Power
- 8. Turbine Steam Flow
- 9. Total Core Flow
- 10. Recire Pump A Loop Flow
- 11. Recire Pump B Loop Flow-O r
O ,
-w.,. +u- -,-U--- , , , , - , . , , , , - , , + , - , .r,-- -
.,n -. -,,,, , , - - - g -
.,-,,,,,,_,,,,-,.wn,,-. n -,,--,c, , ,. . . . - , - . . . , , . , - 7 +
N i O l I MAXIMUM RATE POM R RAMP 1
% REACTOR POWF.R 1 DIVISION = 13,36 SECONOS 125 I I I I I I I I I I I I I I I l 100 -
f F.
-75 - -
\
50 - 25 - - 1
-l 'l I I I I I -1 i l- 1 I I I I l- I-0 5 10- 15- -20 L
1 . TIME t-l= L NWApnwx(1) APRM rtux trvrts O h l
I a i
- O 1
i MAXIMUN RATE Pod R RAMP 6 X10 LBS/flR 1 DIVISION = 13,36 SECONDS 10.8 ; g g ; ; 8.64 - -
. ~
6.48 - - d 4.32 - - 2.16 - -
. ~
l- Il l I I I I I I I I I I I l 0- 5 10 15 20 TIME WSFSTM TOTAL STEAM FROM RX O
.-l O WAXIMUM RATE POMR RAW 6 X10 LBS/HR-1 OIVISION = 13.38 SECONOS 11.88 I I I l- l I l l l l l l l l l 1 9.50 - 7.13 - - 4.75 - - 2.38 - 1 l l l -l i l l I I l _ l- l 'l I I I I 0 5 to 11 5 - 20-TIME RAFFW TOTAL FEEDWATEF. FLOW O-
O 1 MAXIMUM RATE POM R RAMP PSIA I DIVISION = 13,36 SECONOS l 1500 ' l l I I I I I I I l I I I I I I l l
. . l 1200 - -
m 900 - - 600 - - 300 - - 1 I" 1 I I I l -l l I I -l i I I I 0
.5 -10 15- 20-TIE RRPRV RX VESSEL DOME PR ABSOLUTE' O
I
-- , - . . _ _ _ _ . . _ _ . . . . . , . . _ . _ . . . - ~ . . ... _.-_,-. _ _., _ .....--,.. .-..... - -,. . ,
a O MAXIMUM RAfE POM R RAMP INCHES 1 DIVISION = 13.36 SECONDS l' I .I I I I I I I I I I l l l l 48 - - 36 - _ O 24 - - 12 - - I I I I I I I I l- I -l i I I I I_ 0 5- -10 15 20 TIME RRLwR RX MR LVL, WIDE RANGE < O
O MAXIMUM RATE POMR RAMP MEGAWATTS
.1 DIVISION = 13.36 SECONDS l l l l l l l l l l l 'l 'l .I l T'-
800 L ^ ~ ~ ' W .
" ~ ~
O . . 400 - -
\
200 - - I I1 I I I I I I I I
=
I I I I 0 5- 10 15 20 TIME
. E GWGEN MG' CUfPUT RE AL POWER i
O l
.-J.
t
- = . - - - . .
en O WAXIMUM RATE POER RAMP 6 X10 g337,33 1 DIVISION = 13.36 SECONDS 11.88 I I I I I I I I I I I I Tl l 1 9.50 _
$ W i
4.75 - 2.38 - 1 I I I I I 1 .1 1 I I I I I I I 0 5 10 15 20 TIME , MSFHPIN HP TUR8 INLET FLOW O
l O MAXIMUM RATE POE R RAMP 6 X10 gggj,gg i DIVISION = 13,36 SECONOS 108 I I I I I I I I I I I I I I I ~l 86.4 _
']
e .e _ _ 43.2 _ _ / 21.6 - I I I _l I I I I ,I I I l ; I I I I O 5 10 15 20 TIME RRFRXT CORE TOTAL INLET FLOW O 1
' 1
l-L e MAXIMUM RATE POER RAMP b 6 ' X10 LBS/IIR 1 DIVISION = 13.38 SECONOS 64;8 . 7 , , , , ,--, , , , , , , , l i 54.0' - 43.2 - - G V - _ 32.4 - -
- 21. f. -- -
10.8' I II I I I I I I I I I I ! I I 0 5 10 15 20 TIME RRFJPAT TOTAL JP FLOW LOOP - A 0 / 4
t MAXIMUM RATE POMR RAMP 6 X10 -LBS/IIR-1 DIVISION = 13.3? SECONOS 64.8 l- I l l l I I I I I I I I I I I I 54.0 - _ 43.2 - 32.4 - 21.6' - - 10.8- 1 I 1 I I l l l l l l l l l l l 0 5 10 15 20-TIE-lRRFJ PBT- TOTAL JP FLOW LOOP B O l
-. . . . ._ ~ . --. . - . . - . .
l i l QUAD CITIES SIMULATOR TRANSIENT TEST REVIEW TRANSIENT TEST #/ TITLE: M6y Sh e. L o c+ w .M. l .s s o f o f fl Ac f4ay, (I'3) , DATE: d-/ 3 -9 I
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- n. Actual plant transient data EVENT:
- b. Analytical or design data DATA:
- c. Transient data from similar plant PLANT:
- d. Panel ol' experts (best estimate)
COMMENTS: O) G //O A) L \ n V 1
1 l l l l
- c. QUAD CITIES SIMULATOR I ~) TPJd;S!ENT TEST REVIEW LJ
- 2. Data Comparison Summary VARIABLE COMMENTS RESOLUTION l' Ahn F/v y G k_ ok- (D Pe+ * + /, 3.* e M < w 0
3e v := b'^ - 1 N P<e s s E. s ;.>. % It e C s - 2 ati duow
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- 5. ? t A Im1 OL cle ; e s l e s <A s kJ . h e t a.L ST s f r cu u~
7,u(D mwsLR 4 e cLL 4 . L, e, J wL ts wf Jun at ? Aw a- : anemw Q acup h cA4e n c lad a-s l e s s (~) e o,,
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,._.s QUAD CITIES SIMULATOR I ) TRANSIENT ?EST REVIEW %J
- 3. Comparison Results simulator capability to reproduce the defined transient:
(circle one)
- a. ACCEPTABLE )
j' b, UNACCEPTABLE
- 4. Review Board Signatures (dif fering opinions must be documented) s
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Test Number: _TR-8 _ Rev. Number /Date: _0, 01/14/91 Frequency: Annual O QUAD CITIES SIMULATOR TRANSIENT TEST MAXIMUM SIZE REACTOR COOLANT SYSTEM RUPTURE COMBINED WITH LOSS OF OFF-SITE POWER I. OBJECTIVES The purpose of this procedure is to test the simulator response to a Maximum Size Reactor Coolant System Rupture
- combined with a Loss of Of f-Site Power as required by ANSI / ANS
-3.5-1985.
II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149: Nuclear Power Plant Simulation Facilities for Use in Operator License Examinations.
III.-INITIAL CONDITIONS
- 1. The' plant is operating at normal steady state, full power conditions.
O- IV. DATA COLLECTION
- 1. Setup the ZETA plotter to graph the following variables:
- a. Reactor Power (% Neutron Flux) . . . . . . . . . . . . . . .NMAPRMPX
- b. Total Steam Flow.............................MSFSTM
- c. Total Feedwater Flow....-.....................RRFFW
- d. Reactor-Pressure.............................RRPRV
- e. Wide Range Reactor Water-Level...............RRLWR
- f. Fuel' Zone Water Level........................RRLFZ
- g. Drywell Pressure.............................PCPDW
- h. Low Pressure Injection Flow - Loop A. . . . . . . . .RHFRR(1) 1 Low Pressure Injection Flow - Loop B. . . . . . . . .RHFRR(2) j Low Pressure Core Spray Flow - Loop A. . . . . . . .CSFRR(1) k Low Pressure Core Spray Flow - Loop B. . . . . . . .CSFRR(2)
- 1. Suppression Pool Temperature. . .-. . . . . . . . . . . . . . PCTAVGWL -
- m. Drywell Temperature . . . . . . . . . . . . . . . . . . . . . . . . . . PCTAVGDW n.- High Pressure Injection (HPCI) Flow. . . . -. . . . . . HPFINJ FW
- o. HighL Pressure Injection (RCIC) Flow. . . . . . . . . .RCFINJFW
.p . Reactor Water Level, Bottom - Top of Vessel..RRLRW O 1
. . . - . - - - _ . .. .- ~ . . . . . . . . .- . . . . - -
I Test Number:' TR-8 Rev.. Number /Date: 0, 01/14/912 Frequency: Annual- . O QUAD CITIES-SIMULATOR TRANSIENT TEST MAXIMUM SIZE REACTOR COOLANT SYSTEM RUPTURE COMBINED WITH LOSS-OF OFF-SITE POWER V. TRST INSTRUCTIONS
- 1. Encure the plant meets the initial conditions as specified in Section III.
- 2. Enter the data collection points from'Section-IV.
- 3. Run a DBA LOCA concurrent with a loss of offsite power by simultaneously inserting the following malfunctions:
- a. RR10A at 100% severity (Recirc Loop A Suction Rupture)
- b. EG01 (Main Generator Trip) c.- ED02 (Loss of Reserve Auxiliary Transformer)
- 4. Allow the simulator to run until_ stable plant conditions are established.
() 5. Graph the-variables listed under Section IV. VI .- ACCEPTANCE CRITERIA-The-following_ acceptance criteria are to be used to determine successful test completion:
- 1. BothLdiesel generators start and load their respective emergency BUS.
- 2. Jrywellfpressure increases, then decreases.
3 .: Drywell= temperature. increases.-
- 4. ' Suppression pool-pressure increases.
- 5. Suppression pool temperature increases.
6.
~
The observable change-in the parameters correspond in ., dirc., tion to those expected from a-best estimate for the- - simulated transient and do-not violate the physical laws-of nature. LOi 2 e i .
Test Number: TR-8 Rev. Number /Date: 0, 01/14/91 Frequency: Annual O Y- QUAD CITIES SIMULATOR TRANSIENT TEST MAXIMUM SIZE REACTOR COOLANT SYSTEM RUPTURE COMBINED WITH LOSS OF OFF-SITE POWER
- 7. The simulator shall not fail to cause an alarm or automatic action if the reference plant would have caused an alarm or automatic action, and conversely, the simulator shall not cause an alarm or automatic action if the reference plant would not cause an alarm or automatic action.
- 8. The graphs are similar to the baseline graphs, or if the baseline data used was the judgement of a panel of experts, their review shall be documented.
VII. LIST OF FIGURES
- 1. Reactor-Power (% Neutron' Flux)
- 2. Total Steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressure
- 5. Wide Rar.es Reactor Water Level
- 6. Fuel Zone Water Level
( 7. 8. Drywell Pressure Low Pressure Injection Flow - Loop A
- 9. Low Pressure Injection Flow - Loop B
- 10. Low Pressure Core Spray Flow - Loop A
- 11. Low Pressure Core Spray Flow - Loop B
- 12. Suppression Pool Temperature
- 13. Drywell Temperature
- 14. High Pressure Injection (HPCI) Flow
- 15. High Pressure Injection (RCIC) Flow
- 16. Reactor Water Level, Bottom - Top of Vessel 3
MAX LOCA WITH LOSS OF OFFSITE POMR
% RFACTOR POWER 1 DIVISION = 32.84 SECONOS 125 l l l l l l l l l l l l l l l l 100 - -
75 - - 25 - - I I I I I I I I I I I I I I I I 0 5 10 15 20 TIE - NMAPRWX APRM FLUX LEVELS l l l l
MAX LOCA WITH LOSS OF OFFSITE POER 6 x10 LPS/IIR 1 DIVISION = 32,84 SECONOS 10.8 I I I I l I l l l l l l l l l l 8.64 - 6.48 - 4.32 - - l 2.16 - 1 1 1: 10 l l I l i I -l l I l I i 1 0- 5 10 15~ 20. TIME i MSFSTM TOTAL STEAM FROM RX l O
j l MAX LOCA WITH LOSS OF OFFSITE POWR 6 X10 LBS/ilR 1-DIVISION = 32,84 SECONDS 11.88 I I I I I I I l l l l l l l l l 9.50 = 7.13 - - 4.75- - - 2.38 - J/ 1 l' ll I1 I l- 1 I I l I- 1 I I 0 5 10 15 -- 20-TIE RRFFW TOTAL FEE 0 WATER FLOW l. l-l l~ O
.1 MAX LOCA WITH LOSS -OF OFFSITE -POMR I
PSIA 1 DIVISION = 32.64 SECONDS 1500
-l l I I l l I I I I l l l l l 1 1200 - -
900 - - 600 - - 300 - - l l I l i i i l l l l l l l l l 0 5 10 15 20 TIE RRPRV RX VESSEL DOE PR ABSOLUTE O
- .. . . - . . . . . . . .- . . ~ . - .- . . . . - . . . - -. . - .-... .. .
1
- MAX LOCA WITH LOSS OF OFFSITE FOMR INCL!ES 1 DIVISION = 32,84 SECONDS
+60 l I I I I I I I I I I I I l I
+36
+12 _
e -12 - -
-36 - -
-60 NI ! l I I.UI 4 l- I I I I I I I 0 5 10 15 20 TIE RRLWt RX WTR LVL, WIDE. RANGE I
o
~ . . . . - _ - . . - -. . .. .-
1 d- MAX LOCA WITH LOSS OF OFFSITE POMR l INCHES 1~ DIVISION = 32,84 SECONDS
+60 l l
-20 -
-{ .
-100 - -
] -180 - I -
I
-260 - -
-340 l I I I I I I I I I l I l I I l 0 5 10 15 20 TIE RRLF2 FUEL 20NE LEVEL
-_ _- . - - - . . _ ~. . . - - . - -
MAX LOCA WITH LOSS OF OFFSITE POER PSIA 1 DIVISION = 32.84 SECONOS 75 I I I I l- l I I I l l l l l l l i 60 - 45 ( 30 .- 15 e -
-l l I I l I I I I I I l l l 1 I 0 5 to 15 20 TIE PCPDW DRYELL PRESSURE. .;
O
F P kl - MAX LOCA WITH LOSS OF OFFSITE POMR GPM 1 DIVISION = 32.84 SECONDS 16,536 l I I l I I I I I I I I I I I I 13,229 - - 9,922
} '6,614 - -
3,307 - - l- 1 I I I I I I I I I I I I I I I 0- 5 10 15' 20 TIE RHFRR(1) Flow To RR PW DSCH 1. l-O I'
. MAX LOCA WITH LOSS OF OFFSITE POMR GPM 1 DIVISION = 32,84 SECONDS 16,536 I I I I I I I I I I I I I I I l 13,229 - -
9,922 - - 6,614 - 3,307 _ I I I I I I l 1 -1 I I I I I I I 0 5 10 15 20 TIE . RHFRR(2) FLOW -T0 RR PW DSCH
MAX LOCA WITH LOSS OF OFFSITE POMR GPM 1 DIVISION = 32,84 SECCHOS l I I I I I I I I I I I I I I I 5752 - 4314 -
/
2876 - 1438 _ I I il I l- 1 I I I I I I I i_ 1 1 0 5 10 15 20 TIE CSFRit(1) CS TO CORE FLOW O i
. . - - - . . . - _ - - . . . - . . . - . _ . - . - . . - . - - ~ . .
) MAX LOCA WITH LOSS OF OFFSITE POER GPM 1 DIVISION = 32,84 SECONDS I I l I l l l l l l l 'l l l l [ 5752 - 4314 -
- 2876 - t 1438 - -
l l- 11 1 I I I I , I I I I I I I I i 0 5 10 15 20 CSFRR(2) CS TO CORE FLOW < 1 l
!O
MAX LOCA WITH LOSS OF OFFSITC POWR DEGP 1 DIVISION = 32.84 SECONOS I l l l l l l l l l l l l j ; ; 191- - .. . 162 - i l . 133-O 104- - - 75 dl l l l l l l -l l l l' l l l l 0 3 10 15 20 TI6E PCTAVGtt AVG. TEW, OF M. l 0
. - , . _ , , - . . - , . - . - - . . . . - . . . . . .~ +- .,
( MAX LOCA WITH LOSS 0F 0FFSITE POWER DEGP 1 DIVISION = 32.84 SECONDS 400 I I I I I I I I I I I I I I I I 340 _ 280 - 220 - 160 -
-100 l l l l l 1 l I l l l l l 1 l l 0 .5 10 15 20
. TIE PCTAVGOW AVG. TEW. OF OW O
r~ ()f MAX LOCA WITH LOSS OF 0FFSITE POER GPM 1 DIVISION = 32,84 SECONDS-6471 I I I I I I I I I I I I I I I 5177 - - 3883 - - N enum 1294 - I I I I I I I I I l' I I I I I I 0 .5 10 15 20 TIE HPFINJFW HPCI INJ FLOW To FW O
O =^x toc ^ wits toss or orrSItt eo< a GPM. 1 DIVISION = 32.84 SECONDS I I I I I I l l l l l l l l l l 575 - - 431 - - O 144 - - M . . I I I I I I I I I I I I I I I l 0 5 -10 15 20 TIE
- = .
RCFINJF W RC INJ FLOW TO FW L O..
1 I l MAX . LOCA WITH LOSS OF OFF SITE POWR INCilES 1 DIVISION = 32.84 SECONOS I I I I I I I I I I I I I I I I
'+177 - -
+7 -
] -163 - -
-333 - -
-503- 1 I I I I I l I I l- 1 I I I I I 0 5 10 15 20 TIE
-RRLRW RX WATER LEVEL INCH O
-.=- _ . _ - . -. . - . - _ .
QUAD CITIES SIMULATO'A TPANSIENT TEST REVIEW cws TRANSIENT TEST #/ TITLE: Na- > $7 1 r_ _ti .;q /m1 1 A C .< Sr,_~ /r.., 4'ph,, e DATE: A -/3_- 7 ,
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- a. Actual plant transient data EVENT:
- b. Analytical or design data DATA:
- c. Tran'sient data from similar plant PLANT: .
- d. Panel of experts (best estimate) r3 COMMENTS:
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- n. QUAD CITIES SIMULATOR
'(j TRANSIENT TEST REVIEW
- 2. Data Comparison Summary VARIABLE CCMMENTS RESOLUTION
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QUAD CITIES SIMULATOR TRANSIF.NT TEST REVIEW g 3. Comparison Results Simulater capability to reproduce the defined transient: (circle one)
- a. ACCEPTt
- b. UNACCEPTABLE i
- 4. Review Board Signaturec (c ' ff et il. , opinions mus3/be documente d)
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COMMENTS: me. 6 M"
. 54' O -
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Test Number: TR-9 Rev. Number /Date: 0, 01/14/91_ Frequency: Annual O QUAD CITIES SIMULATOR TRANSIENT TEST MAXIMUM SIZE UNISOLABLE MAIN STEAM LINE RUPTURE e I. OBJECTIVE 3 The purpose of this procedure is to test the simulator response to a Maximum Size Unisolable Main Steam Line Rupture as required by ANSI /ANS-3.5-1985. - II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149: Nuclear Power Plant Simulation Facilities for Use in Operator License Examinations.
III. INITIAL CONDITIONS
- 1. The plant is operating at normal steady state, full power conditions.
b(_/ IV. DATA COLLECTION
- 1. Setup the ZETA plotter to graph the following variablea:
- a. Reactor Power ( % Neutron Flux) . . . . . . . . . . . . . . .NMAPRMPX
- b. Total Steam Flow.............................MSFSTM
- c. Total Feedwater Flow.........................RRFFW
- d. Reactor Pressure.............................RRPRV
- e. Wide Range Reactor Water Level...............RRLWR
- f. Fuel Zone Water Level........................RRLFZ
- g. Drywell Pressure.............................PCPDW
- h. Low Pressure Injection Flow - Loop A. . . . . . . . .RHFRR(2)
- 1. Low Pressure Injection Flow - Loop B. . . . . . . . .RHFRR(2)
- j. Low Pressure Core Spray Flow - Loop A. . . . . . . .CSFRR(1)
X ., Low Pressure Core Spray Flow - Loop A. . . . . . . .CSFRR(1)
- 1. Suppression Pool Temperature. . . . . . . . . . . . . . . . . PCTAVGWL
- m. Drywell' Tempera ture . . . . . . . . . . . . . . . . . . . . . . . . . . PCTAVGDW
- n. High Pressure Injection (HPCI) Flow. . . . . . . . . .HPFINJFW
- o. High Pressure Injectica (RCIC) Flow..........RCFINJFW
- p. Reactor Water Level, Bottom - Top of Vessel..RRLRW V
?
1 l l
Test Number _TR-9 Rev. Number /Date s 0, 01/14/91. Frequency: . Annual
~4 QUAD CITIES SIMULATOR TRANSIENT TEST MAXIMUM SIZE UNISOLABLE MAIN STEAM LINE RUPTURE V. TEST TNSTRUCTIONS
- 1. Ensuro the plant meets the initial conditions as specified in Section III. .{
- 2. Enter the data collection points from Section IV.
3.- Initiate an unisolable main steam leak by inserting malfunction MSO4A at 100% severity (Main Steam Line Break Inside Drywell Before Flow Restrictor).
- 4. Allow the simulator to run until stable plant conditions k are estab132ned,
- 5. Graph the variables listed under section IV.
VI. ACCEPTANCE CRITERIA The following acceptance criteria are to be used to determine
\ successful test completiont
- 1. The observable change 11 the parameters correspond in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of nature.
- 2. The simulator shall not fail to cause an alarm or automatic action if the reference plant would have caused an a.iarm or automatic action, and conversely, the simulator shall not cauce an alarm or automatic action if_
the reference plant would not cause an alarm or automatic action.
- 3. The graphs are sim 'itr to the baseline grcphs, or if the baselina data used was the judgement of a panel of experts, their review shall be documented.
NOTE RCIC will not operate during this transient. This is due to RCIC steam supply coming from A Main Steam Line. O 2
Test IJumbert .TR-9 Rev. Ilumber/Dato1 _9, 01.fjAl.9.L Frequency: _bunnal - O QUAD CITIES SIMULATOR TRANSIEllT TES MAXIMUM SIZE Ul41SOLABLE MAI!1 STEAM LIl4E RUPfURE l VII. LIST OF 4 1rJRES
- 1. Reacter Power (t IJeutron Flux)
- 2. Total steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressuro
- 5. Wide Rango Reactor Water Level
- 6. Fuel Zone Water Lovel
- 7. Drywell Pressuro
- 8. Low Pressure Injection Flow - Loop A
- 9. Low Pretsure Injection Flow - Loop B
- 10. Low Pressure Core Spray Flow - Loop A
- 11. Low Pressure Core Spray Flow - Loop B
- 12. Sunprossion Pool Temperature
- 13. Dr/well Temperature
- 14. High Pressure Injectio' .HPCI) Flow
- 15. High Procsure Injection (RCIC) Flow
- 16. Reactor Water Level, Bottom - Top of Vessel O 3 l
MAX UNIS0LABLE MAIN STEAM LINC RUPTURE
% REACTOR POWER 1 DIVISION = 18,29 SECONDS 125 I I I I I I I I I I I I I I I l 100 9 -
)'.. 75 - - O 50 - - 1 25 - - L I I I i 1 1 1 1 1 I I I I I I 0 5 10 15 20 TIE NMAPRWX APRM FLUX LEVELS O
s i 4 l I MAX UNISCLABLE MAIN STEAM LINE RUPTURE s-4 x10 6 LBS/IIR 1 OIVISION = 18.29 SECONOS
- I I I I I I I I I I I I I I I l 18.72 -
14.04 , ,,, 1 E eu
- O e >e = -
4.68 - - I I I l %I I I I I I I I I I I j 0 5 to 15 20 TIE MSFSTM TOTAL STEAM FROM RX O
MAX UNISOL ABLE MAIN STEAM LINE RUPTURE 6 X10 LDS/HR 1 DIVISION = 18.29 SECONDS 11.88 I I I I I I I I I I l l l l l 1 9.50 q _ 1 2.13 _ q _ O ' - 3 ( l 2.,. _ ( , I IK I I I I I I I I I I I I 0 5 10 15 20 TIE RRFFW TOTAL FEEDWATER FLOW O
1 1 MAX UNIS0LABLE MAIN STEAM LINE RUPTURE l 1 PSIA 1 DIVISION = 18,29 SECONOS 1500 l I I I I I I I I I I I I I I I l 1200 - -
)
900 - 1 600 - - 300 - l 1 N O I I I I I i i i i i i i i l l' I o 5 to 15 20 TIE RRPRV RX VESSEL DOW PR ABSOLUTE lO l I u _. . . - _,. -
+ MAX UNIS0LASLE MAIN $ TEAM LINE RUPTURE s INCilES 1 DIVISION = 18,29 SECONOS
+60 '
I I I I I l l l l l l l l l l l
+36 - -
a
+12 -
-12 - -
-36 - -
f f . 1
-60 I WI I I I I I I I I I I I l 0 5 to 15 20 TIE KRLWt RX ' MR LYL, MDE RANGE l
O
MAX UNISQLASLE MAIN STCAW LINE RUPTURE INCL!ES 1 DIVISION = 18.29 SECONOS I I I I I I I I I I l l 1 I I l I
-100 - -
-180 - -
-260 - -
_340 l l l l 1 l l- I l l l l 1 I I I 0 5 10 15 20 TIE RRLF2 FUEL ZONE LEVEL O
KAX UNISOLASLE MAIN $TCAM LINC RUPTURE PSIA , 1 DIVISION = it.29 SECONOS l I I I I I I I I I I I I I I I 62 -
" ~ ~
{ _ _ 4 36 l 23 - _ 1 to I l l l l l l l l l l 1 1 I I I 0 5 10 15 20 TIE PCPDW DRYM LL PRESSURE . O
~ . MAX UNISQL AOLE MAIN STE AM LINE P,'J/TURE l l
GPM 1 DIVISION = 18.29 SECONOS l I I I I I l l l l l l l l l l
~ ^
13,229 - f 9,922 - 6,614 - - 3,307 I I l l )1 l l I I I I I I I I I ;
- 0 5 10 15 20 TIE RHFRR(1) FLOW TO RR PW DSCH L O.
i l - . . .- .. . . - . . .
i i l i l MAX UNISQLAttE MAIN $ TEAM LINE RUPTURE 4 GPM i 1 DIVISION = 10,29 SECONOS I I I I I I I I I l l l l l l l 4 i . . i-13,229 - ) 9,922 .. 9 ( f.,614 - - 3,307 - - 1 I I I I i l l I I I I I I I I I l 0 5 to 15 20 TIE RHFRR(2) FLOW TO RR PW DSCH r O
1 MAX UNISOLASLE MAIN STEAM LINE RUPTURE GPM , 1 DIVISION = 18,29 SECONOS 7190 l I I I I I I I I I I I I I I I 5752 - - i , 4314 - - 2876 - - l. 1438 - - f I I il l I l l l l l l l l l l I i 0 S- 10 15 20 TIE l t l-CSFRR(1) C8 TO CORE FLOW i l O t 1
F J
/
WAX UNISOL A8LE MAIN STEAM LINE RUPTURE GPM 1 DIVISION = 18.29 SECONDS 7190 I I l l l l l l l l l l l l l l 5752 - - 1 4314 MEE8 esse 1438 A l' I Il l I I I I l- -l l I I l l l _. 0 5 10 15 -20 TIE CSFRR(2) CS TO CORE FLOW : i l O 1 l i I l
i s .I MAX UNISOLASLE MAIN STEAM LINE RUPTURE i DEGP 1 DIVISION = 18,29 SECONOS 220 I I I I I I I I I I I I I I l l 191 - - , 162 133 - - 104 - - 75- 1 I I I I I I l 'l l I l l I I I 0 5 10 15 20 TIE PCTAVGE AVG, TEW, OF E O
= . . .. -- - - . . . . - . . . - - , . . . . ~ - . . . - - . ..- - . ...- _~ . - _ - _. - .
MAX UNISCL ASLE MAIN STEAM LINE RUPTURE DEGF 1 DIVISION = 18.29 SECONOS 400 l l l l l l l l l l l l l l l l 340 - 280 - -
- 220 - -
160 - - 100 I I I I I I I I I I I I I I I I 0 5 10 15 20 TIE PCTAVGDW AVG. TEr OF DW
1 l MAX UNISOL ASLE MAIN STEAW LINE RUPTURE s GPM 1 DIVISION = 18.29 SECONOS 6471 I I I I I I I I I I I I I I 1 I O W 5177 - - 3883 - - Muu. Samus 1294 - - I I I I I I I I I I I I I I I 0 5 10 15 20
- TIE HPFINJFW HPCI INJ FLOW TO FW i
t O
WAX UNIS0LABLE MAIN STEAM LINE RUPTURE GPM 1 DIVISION = 18,29 SECONOS l I I I I I I I I I I I I I I I 575 - - 431 - - 144 - - I I I I I I I I I I I I I I I I o 5 to 15 20 TILE , RCFINJFW RC INJ FLOW TO FW O l
l' WAX UNIS0LABLE MAIN STEAM LINE RUPTURE INCilES 1 DIVISION = 18,29 SECONOS
+347 I I I I l l l l l l l l l l
+177 - -
f .
+7 2 -
-163 - -
-333 - -
-503 I I I I I I I I I I I I I I I I 0 5 10 15 20 TIE RRLRW RX WATER LEVEL INCH O
.. - . - . - - . - . . - - ._ - -____ ___~ . . - - . ._ .
1 l QUAD C: IES SIMULATOR y TPANSIENT TEST REVIEW TPANSIENT TEST #/ TITLE: $ t ad4em m & c/,, m ,[ A.si n M Q-10)' siqL. ssway iyv~ W
- 1. Baseline data utilized for test comparison in order of preference (circle appropriate choices)
- a. Actual plant transient data EVENT: _
- b. Analytical or design data DATA:
- c. Transient data fro!. similar plant PLANT:
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gm QUAD CITIES SIMULATOR i TRA!!S!Ct1T TEST REVIEW L
- 2. Data Comparison Sum. mary VARIABI.E COMME!1TS RESOLUTI0tj
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i I I QUAD CITIES SIMULATOR 1 O TRA!JSIE!JT TEST REVIEW l 3. Comparison Results i Simulator espability to reproduce the defined transient: { (circle one)
- r -- - -~
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- b. UllACCEPTABLE 4
- 4. Review Board Signatures (dif fering opinions must be documented)
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_ = . - - . - . - . - . - - - . . - . _ _ _ Test Number: _TR-10 Rev. Number /Date: 0, 01/14/91_ Froquency: Annual O QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS CLOSURE OF ALL MAIN STEAM ISOLA ' ION VALVES COMBINED WITH SINGLE STUCK OPEN SAFETY /REL.EF VALVE (INHIBIT ACTUATION OF HIGH PRESSURE ECCS) I. OBJECTIVES The purpose of this procedure is to test the simulator response to a Simultaneous closure of All Main Steam Isoletion Valves combined with Single Stuck Open Safety / Relief Valve (inhibit actuation of high pressure ECCS) as required by ANSI /ANS-3.5-1985. II. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in Operator Training.
- 2. Reg. Guide 1.149: Nuclear Power Plant Simulation Facilities for Use in Operator License Examinations.
III. INITIAL CONDITIONS
- 1. The plant is operating at normal steady state, full power conditions.
IV. DATA COLLECTION'
- 1. Setup the ZETA plotter to graph the following variables:
- a. Reactor Power (% Neutron Flux) . . . . . . . . . . . . . . .NMAPRMFX
- b. Total Steam Flow........................... .MSFSTM
- c. Total Feedwater Flow.........................RRFFW
- d. Reactor Pressure.............................RRPRV
- e. Wide Range Reactor Water Level...............RRLWR
- f. Fuel Zone Water Level........................RRLFZ
- g. Drywell Pressure.............................PCPDW
- h. Low Pressure Injectior. Flow - Loop A. . . . . . . . .RHFRR(1)
- 1. Low Pressure Injection Flow - Loop B. . . . . . . . .RHFRR(2)
- j. Low Pressure Core Spray Flow - Loop A. . . . . . . .CSFRR(1)
- k. Low Pressure Core Spray Flow - Loop B. . . . . . . .CSFRR(2)
- 1. Suppression Pool Temperature. . . . . . . . . . . . . . . . . PCTAVGWL
- m. Drywe ll Tempera ture . . . . . . . . . . . . . . . . . . . . . . . . . . PCTAVGDW
- n. High Pressure Injection (HPCI) Flow. . . . . . . . . .HPFINJFW
- o. High Pressure Injection (RCIC) Flow. . . . . . . . . .RCFINJFW
- p. Reactor Water Level, Bottom - Top of Vessel..RRLRW l
4 Test Numbers TR-10 Rev. Number /Date: 0, 01/.14/91 Frequency: _ Annual A QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS CLOSURE OF ALL MAIN STEAM ISOLATION VALVES COMBINED WITH SINGLE STUCK OPEN SAFETY / RELIEF VALVE (INHIBIT ACTUATION OF HIGH PRESSURE ECCS) V. TEST INSTRUCTIONS
- 1. Ensure the plant meets the initial conditions as specified in Section III,
- 2. Enter the data collection points from section IV,
- 3. Insert malfunction AD07A at 100% severity, (Ralief Valve Sticks at 100% open) .
- 4. Insert malfunction HP01, (HPCI Turbine Trip).
- 5. Insert malfunction RC01, (RCIC Turbine Mechanical Trip).
- 6. Close all MSIV's by simultaneously inserting malfunctions RP05A and RP0uB, (Group I Isolation Actuation).
- 7. Allow the simulator to run until stable plant conditions O are established.
- 8. Graph the variables listed under Section IV.
VI. ACCEPTANCE CRITERIA Tuo following acceptance criteria are to be used to determine successful test completion:
- 1. Reactor water level decreases to Group II Isolation setpoint.
- 2. Reactor pressure increases to SRV setpoint.
- 3. Drywell pressure remains fairly constant.
- 4. Drywell temperature decreases.
- 5. Suppression pool temperature increases.
- 6. Suppression pool pressure increases.
O 2 _~
-~__. __--- __-_.- . .~._._. ._.__ _.._.__._. _.._.______ _.___
Test Numbert TR-10 Rev. Number /Date: 0, 01/14/91 Frequency: _11nnua.1 O QUAD CITIES SIMULATOR TRANSIENT TEST SIMULTANEOUS CLOSURE OF ALL MAIN STEAM ISOLATION VALVES , COMBINED WITH SINGLE STUCK OPEN SAFETY / RELIEF VALVE (INHIDIT ACTUATION OF HIGH PRESSURE ECCS)
- 7. The observable change in the parameters correspond in direction to those expected from a best estimate for the simulated transient and do not violate the physical laws of nature.
- 8. The simulator shall not fail to cause an alarm or automatic action if the reference plant would have caused an alarm or automatic action, and conversely, the simulator shall not cause an alarm or automatic action if the reference plant would not cause an alarm or automatic action.
- 9. The graphs are similar to the baseline graphs, or if the baseline data used was the judgement of a panel of experts, their review shall be documented.
VII. LIST OF FIGURES
- 1. Reactor Power (% Neutron Flux)
- 2. Total Steam Flow
- 3. Total Feedwater Flow
- 4. Reactor Pressure
- 5. Wide Range Reactor Water Level
- 6. Fuel Zone Water Level
- 7. Drywell Pressure
- 8. Low Pressure Injection Flow - Loop A
- 9. Low Pressure Injection Flow - Loop B
- 10. Low Pressure Core Spray Flow - Loop A
- 11. Low Pressure Core Spray Flow - Loop B
- 12. Suppression Pool Temperature
- 13. Drywell Temperature
- 14. Total High Pressure Injection (HPCI) Flow
- 15. Total High Pressure Injection (RCIC) Flow
- 16. Reactor Water Level, Bottom - Top of Vessel
-O 3 1
~ s O WSIV CLOSURE W/ STUCK OPEN SRV (NO HP ECCS)
% REACTOR POWER 1 DIVISION = 67.00 SECONOS 125 100 m. .
75 .. 50 -- ._ 25 -. __
'
m-{- % m AN O ^eeaoveo 1/00llh NOV 171969 Q.C.O.S.R.
QGP 1-1 Revision a5
- g. If First Stage Bowl Upper-Inner surface temperature is
< 250'F, the turbine shell must be warmed prior to rolling.
START shell warming as follows: (1) Record the First Stage Bowl temperature. Wh
-( 2 ) Verify that the load llmit 's off zero. [?
(3) Verify that the CHEST /SHELL warming demand me te r i s a t 01,. (4) RESET the turbine. M (5) Reset the turbine trip monitor panel at the f bottom of panel 901-31 (902-31). Verify that / all lights clear, except the power light. N NOTE If the turbine trips subsequent to this action: (1) Inspect the trip monitor panel, at panel 901-31 (902-31), to determine what caused the trip, before resetting the turbine. (2' Reset the turbine and clear all alarms at panel 901-31 (902-31) before proceeding again with the turbine start up. (6) OPEN the feedwater heaters (B, C, & 0) extraction valves. Verify that=the extraction bypass valves are closed when the extraction valves are open. NOTE If high heater level prevents opening at this time, attempt to open after unit is synchronized. (7) PRESS the CHEST /SHELL HARHING OFF button. (8) PRESS the CHEST /SHELL warming button. Verify thattheSHELLportionofthebuttonilluminatesI and the turbine control valves open.
<V CAUTION If tne turbine trips during shell warming, it may be necessary to range up the IRMs in order to avoid a high APPROVED l neutron flux scram. !
1/0011h NOV 171969 l Q.C.O.S.R. i
QGP l-1 Revision 45
.__ (9) PRESS the INCREASE button to admlt shell warming ;
steam. Limit the first stage shell pressure
- to 70 psig to prevent rolling the turbine off
?
the turning gear. Steam should be admitted slowly and steadily at first to avoid excessive vessel pressure transients. Monitor operating - parameters closely, e NOTE I It is important that the MSDT's APPROVEDi emergency drain valves are closed during SHELL warming. If these valves liOV 171989, are open, tureine will roll much easier and very poor SHELL warming occurs. Q.C.O.S.R.
-Also, during SHELL warming the above seat and below drains can-be-closed as an aid to better shell warming.
-Ca) If difficulty is encountered in keeping the turbine on turning gear during shell warming,
. maintain turbine RPM less than 100 RPM by stopping the_ turbine lift pumps. ,
(10) Continue--shell warming unti'l all of the following _ condi tions - e xi s t: (This will taxe approximately 3 hours of shell warming). gf.g i
^_./ (a) Shell expansion > 0.3 inches,
- 03 ' 8
-(b)- Olfferential expansion > 0.150. 8
'(c) First Stage' Bowl Upper-Inner surface ,
temperature >-250'F, (Record ' temperature.) N&k (11) To terminate shell warming. PRESS the OFF -
,f-button. Verify that the.0FF button illuminates Yerify that the control valves close. / 7 1 NOTE-With shell' warming on, 4 turbine startup rate cannot be selected,
- h. START chest warming as follows. If the shell was not_ required to be warmed, chest warming shall commence after the reactor-steam temperature is greater than steam chest inner-surface-temperature.
/*
(1) Verify that the turbine Is reset, p (2) PRESS the INCREASE button to admit chest g warming steam. 1/001Ih QGP l Revision 45 (3) Verify that the following chest warming limits are adhered to: Turbine ches t heat-up ra te < 100'F/hr. (a)
/ .)
(b) Steam Chest, INNER & OUTER surface differential temperature is less than 80*F. (c) Steam Chest outer surface temperature [1
> 460*F. / (e/
- 1. When their low pressure isolations clear, warm the HPCI and RCIC steam lines as follows:
(1) OPEN H0 2301-5; HPCI steam outboard Isolation valve. /l7 (2) Crack OPEN H0 2301-4; HPCI steam inboard s isolation. (7_ (3) When HPCI steam line pressure equals reactor vessel pressure, fully OPEN H0 2301-4. d (4) OPEN H0 1301-17; RCIC steam outboard f isolation. /7 (5) Crack OPEN H0 1301-16; RCIC steam inboard / isolation. /) (6) When RCIC steam line pressure equals reactor \ s vessel pressure, fully OPEN H0 1301-16. /'7 (7) Place RCIC and HPCI in standby operation in // accordance with QOP 1300-1 and QOP 2300-1 / 2'-
- j. At 100 psig reactor pressure, perform the following: l
~
(1) CLOSE the main steam line drain valve. H0 220-4. (2) CLOSE steam seal bypass feed VALVE S-2 If the regulator is able to maintain 4 psig to the seals. (3) OPEN power supply breaker to MO-1001-47 RHRS shutdown cooling suction outboard isolation valve, at 250 VOC reactor building MCC IB (28) compartment 502 (502) (j0CFR50 Appendix R). g Vv Y ff*' s APPROVEQ 1/001th (40V 171989 Q.C.O.S.R.
QGP l 1 Revision 45
- k. At.200 psig reactor pressure, start the off-gas system in accorcance with QOP 5400-1 ,/ 7.-
(1) Verify that the offgas radia'. ion indications . on the logarithmic recorder at 901-2 (902-2) are similar to indications on the 53AE < radiation monito,*s st 901-10 (902-10). (2) Verify that the off-gas radiation indications on the SJAE radiation monitors on 901-i0 (902-10) . panel are celow the upscale trip setoolnts. -- ), (3) Verify that no HI or HIGH-HIGH off-gas rad 1Mion[ alarms are sent on the 901-3 (902-3) panel. / l NOTE 1 The SJAE radiation monitors may still have a 00HNSCALE alarm up at this time.
- 1. Verify that the SJAE radiation monitors are operable (T,S. 3.2.H.)
- m. At 300 psig reactor pressure, START a reactor feed ,,,
pump in accordance with QOP 3200-2.
/?_
- n. When the steam jet air ajector is operating and the main condenser backpressure is less than 7 inches Hg.
(greater than 23 inches Hg. vacuum), verify that the mechanical vacuum pump AUT0 TRIPS. SHUT 00HN th) , mechanical vacuum pump in at;ordance withg g .,[7 ' QOP 5400-7. go
- o. For the B train of Unit On:, off-gas, valve in tne >
motive steam to the prie. dry air ejectors at 400 psig reactor pressure in accordance with QOP 5400-l. /V h
- p. Verify that the main generator voltage regulator is operational as follows:
(1) Verify that the GEN VOLTAGE CONTROL TRANSFER switch is in MAN. I (2) Place the MANUAL VOLTAGE ADJUST CONTROL switen to the RAISE position until the HIGH LIMIT light illuminates, then place the switch to LOWER until the LOW LIMIT . light illuminates. (3) Place the MAN VOLT ADJ CONT to RAISE until 1 the LOW LIMIT light extinguishes. / h APPROVED 1/00llh H0V 171989 Q.C.O.S.R.
l' QGP l-1 Revision 45 NOTE 4pggg g- - Step F.4.q. does not apply to the 8 train of Unit One. Step F.4.g. does g;j g' }, not apply if the recombiner was started with the SJAE's. Q.C.O.S.R* Q. At 700 psig reactor pressure, start a recombiner per QOP 5400-1 step F.ll. This will increase and stabilize the air ejector off-gas flow with the - addition of a booster air ejector. -
- r. Isolate sparge air to the off-gas train per QOP 5400-9. /
w " s. At 825 pstg reactor pressure, verify that Citannel A and Channel B HAIN STEAM LINE LOW PRESSURE alarms clear.
/k
/v
- t. STOP increasing the pressure regulator setpoint when its setpoint Indicates 920 psig,
- u. At 900 psig, verify that the operable recombiner i
is within the allowable band of the caseline plot
' of recombiner outlet temperature vs. reactor power. (T.S. 3.8.A.5)
- v. Continue to increase reactor power with control rod withdrawal. / i w.- STOP rejecting water from the reacter vessel in accordance with QCD 1200-7 when the Low Flow ,
Controller is able to maintain reactor vessel level. / '
- x. Notify Radiation Protection to determine if the water Chemistr.y control limits are met for power operat(ons (see QAP 300-22). N (1) Time Radiation Protection notified M .
M (2) Name of Radiation Protection personnel nottfled- A/ d _. ky} (3) Variance Request Report completed for any variance (see QAP 300-22). /g
- y. Transfer the reactor MODE swttch to RUN as follows:
(1) When 1-2 bypass vaives are open, calibrate the ) APRM's according to the following relationship: (a) Percent power - (40/9 x no. of bypass - valves cpen) + 1. (SER 27-88) 1/0Gilh ~ 9 _ _ _ _ _ _.__._.._._m - - -
\' 1 h i QGP l-1 Revision 4F (2) Verify on 901_-5(902-5) and 901-37(902-37) that M all APRMs are indicating between 4% and 12%. U (3) Verify that all APRM 00HNSCALE lights are not 111uminated.
-(4) Verify that the main condenser backeressure is less than 7 inches Hg, (greater than 23 inches Hg.
vacuum). (5) Verify that the CHANhEL A/B LOH VACUUM alarm 15 cleared. // A (6) Place 1 IRM/APRM recorder on each RPS channel to APR- ( (7) Place th.. reactor H00E swttch to RUN. (8) Place all IRM/APRM recorders to APRM. (9) Withdraw control rods to maintain the APRMs off downscale. P (10) The drywell is required to be inerted within 5 1: 24 hours after go'ng into the UN_mpse. f
~
(QOP 1600-5, QOP 1600-6,t{ P 1600-1 )#g# QOP 1600-20.)
-p V (11) A differential pressure of 1.20 psid or iv greater is to be-e:tablished between the drywell.'and suppresslon chamber within 24 hours after going into the RUN mode.
(COP 1600-14.-QOP 1600-15.) (12) -If-a drywell entry has been made, the drywell airlock must be leak rate tested within 24 hours after going into the RUN mode. (QTS 100-31')- M$
- z. ' Withdraw the IRM detector in accordance with QCP 700-2. Range down the IRMs as necnssary -to maintain them off downscale.
NOTE If 3" Hg or less backpressure is not attained prior-to opening the bypass i valves, a reactor scram may occur on low-vacuum when prent,r.ing to roll the turbine. aa. Continue to increase reactor power with control rod withdrawal until the proper numocr of turbine bypass valves are open for
-initta'l generator load, 1/001th NOV 171%9 C.C.O.S.R. i
(Gp 1 1 Sivision 4$ (1) " Cold and Warm Start-up" initial generator load recuires 1-2 turbine nypass valves open. g! (7) , t Start up" initial generator load requires 3-4
- -
- Ine bypass valves open.
) bb. Place the first main feedwater regulatin . Ive on
/'
the line in accordance with QOP 600-2. cc. If operable, enaH 6 she Hydrogen Water Chemistry ' Systo in accorocnce with 00P 2700-1, a,, < 4 Main turbine start-up,
- a. Verify that the main turbine has been on turning gear in accordance with step C.6. and that the rotor
- eccentricity reaaing has a steady value of less than /- 2 mils. / (1) A varying eccentricity reading or one that is greater i than 2 mils could indi"!e a rotor bow. L (2) Increased snaft vibra. + 'ollowing a rapid temperature reduction or load swi>9 N; be indication of a c.acked rotor if not rotating n.fr critical speed. If this condition is noted. Genstal Electric should be notified z y for further evaluation. j b. Dispatch an operator to perform the following: O (1) at Turbine 115'F. oil coolerb,4 outlet/Lft temporatup'A . - (2) Place the hydrogen panel control ir6.o the RUN mode. Me (3) CUT-0UT the turbine supervisory tri YYmo c rlayb.hr 8
- c. Verify above and below seat drains are open,
- d. If available, the following computer information may be utilized:
(1) 00-22. TV Color Olsplay Request. (a) Option 2, turbine overview (vibration) N I 7 N' (2) 00-37, Operator Selected Analog Trenu. Q.C.O.S.R. (a) Turbine Speed T146 (T246),
- e. Place the turbine supervisory recorder on HI speed.
- f. Verify that the motor suction oil pump and the e turning gear oil pump are running.
1/001th ;
OGP l-1 Revision 45
- g. Verify that the pressure in steam chest P! 5640-50 (gs) is greater than 80% of the main steam line pressure, v P! 3040 10. This indicates the steam headers and turbine steam chest are warm and drained. This condition must te satisfied before main tur,ine #
stop valves are opened. /37
- h. Notify the Load Dispatcher that the turbine is teing rolled. Request permission to CPEN the following OCBS.
remove the unit line disconnect Specist Order Card, and CLOSE the unit line disconnect. 4 4 M h_ (1) Unit 1: OPEN OCB 6-7 and OCB 7-8. AuMu (2) Unit 2: OPEN OCB 1-11 and OCB 10-11 .
- i. Coordinate the opening of the ring bus, closing the
- isconnects, and roiling the turbine to minimize Idling the a
turbine unloaded at 1800 RPM.
- j. Verify that the LOAD LIMIT is set at an indicated reading C 100% and the MAX COMBINED FLCH 15 set at an indicated reading of 1057.. /# f
- k. Determine the turbine start-up rate in accordance with the Fi st Stage Bowl Temperature established it, ster 0.3.g.
(1 'c). , (1) 250'F to 350'F (Cold and Harm): HEDIUM (90 RPM / minute). (2) > 350'F (Hot): FAST (180 RPM / minute). CAUTION Turbine should not be operated for more than 5 minutes below 800 RPM. When unusual vibration is noted at lod speed, which may indicate packing rubbing, the turbine should be immediately shutdown and placed on turning gear. 00 NOT OPERATE AT LOW SPEED TO CLEAR RUBS. APPROVED Throughout the starting and loading of the unit, the temperature difference 140V 171989 across the walls and differential expansions should be monitored and kept Q.C.O.S.R. within the recommended limits. Startup vacuem should be high as possible. A backeressLre in excess of 5" Hg should be avoided. 1/0011h
- 1. PRESS the FAST start-up rate.
/b
QGP 1-1 Revision 4$
- m. PPfSS the 1800 RPM speed set button, When the ttuaine rolls off the turning gear, PRESS the start-up rate determined in step 0,4,k. Verify /
that the following occurs: f7 (1) Main stop valve 2 and intercept valves I, 3. and 5 open. /
/v,j (2) When main stop valve 2 15 full open, main stop valves 1, 3, and 4 open, f
(3) Wheninterceptvalv'sI,3,and5arefullopen,4f intercept valves 2, 4, and 6 open. /' (4) When all main stop valves and intercept valves are full open, the speed error signal will open the control valves enough to roll the turbine off the turning gear. [ (5) Verify that the main turbine is accelerating. 7 (6) Verify that chest warming goes to zero. /h
- n. Monitor turbine vibration during acceleration. If several consecutive vibrations are greater than 10 mils and increasing, notify the Shift Engineer and consider tripping the turbine.
- o. When the main turbine speed approachet the critical speed of 1200 RPM, select the FAST start-up and then O
re-select the proper start-up rate after the turbine f) is faster than this crit l cal speed. /B
- p. STOP the turning gear motor.
q. M1'l When the turbine speed levels out at '800 RPM, verify that the turbine oil temperature lev 0is out at 115'F, Verify that the turbine is running satisftctorily with proper expansion and with vibration less than 5 mils. -
- 5. Synchronizing the main generator,
- a. Verify the following prior to unit synchronization:
(1)
- Ring bus is open and the unit line disconnects are *7 closed.
(2) Stator cooling water supplisd to the field # rectifiers. (3) Generator voltage control transfer swit h . in MAN. - APPROVED 1/00llh g97 Q,C.O.S.R.
j ' 4 r QGP l 1 L Revitten 45 1 (4) Hanual VOLT AD] CONT. Is just above its low I o limit. Do this by Icworing the setpoint to the low limit and then raising it until the low r limit light extinguishes. // L 1
- b. START an isolated pnast bus blower. M
- c. If available, the following computer information may te uttitzed:
(1) 00-22. TV Color Otsplay Request. 1 (a) Option 11, cold and hot end hydrogen tenceratures. (b) Option 48, load pick-up data. (2) 00-37. Operator Selected Analog Trend. (a) Gross megawatt electric G128 (G228). (b) Hydrogen cold end temperature G121 (0221). (3) . Verify that hydrogen cold end temperatures, G-12)(G-221), are approximately 40'C. 3 .g
- d. Notify the Eculpment Operator that the generator field breaker is to be closed. N
- e. -CLOSE the generator field breaker.
n
- f. If the generator voltage increases beyond 19 kv. then trip.the field breaker immediately /?f
- g. Using the MANUAL-VOLTAGE A0JUST CONTROL switch, acjust the stator voltage to that all three phases incicateLIB kv. /[/
- h. .Using the REG VOLTAGE A0JUST SETPOINT. ADJ CONTROL switch, bring-the Null Voltmeter to zero. '
- 1. Place the GEN VOLTAGE CONTROL TRANSFER swltch in i AUTO.
j .- Place the OCB 6-7(1-11) synchroscope switch to ON.
- k. . Verify that the synchroscope dial is rotating, the- :
- synchronizing lights are operating, and. the INCOMING and RUNNING voltmeters are incicating. 6
~1. Adjust the generator speed with the Governor control-
' Switch- to ootain a slow clockwise (FAST)- rotation on the synchroscope dial. O Aeaaoveo i , 1/00llh HQy J 7 l969 C.?.O.S.R. l
i X,P 1 - 1 Revision 45 APPROVED m. Use the KEG VOLTAGE ADJUST $[TPOINT A0J CONTROL ROV 17 switch to bring the INCOMING voltage slightly higher > than the RUNNING voltage ehen the syncaroscope dial Q.C.O. .. is at twelve o' clock
- n. Readjust the generator speed and voltage as necessary to maintain proper rotation and voltage.
o, When the synchroscope dial is apprortmately I degree 4 before twelve o' clock. CLOSE OCB 6-7(1-11). Verify that the OCB closed and synchroscope dial stops a' twelve o' clock, (~ ((. 0 Use the LOA 0 SET to slerly bring generator power up to the appropriate initial load. Hold this initial load for a minimum of 15 minutes. (1) Cold turbine 50 WHe. (2) Warm turbine 50 MWe. (3) Hot turbice 120 MWe. Q. Turn off the synchroscope switch on OCB 6-7(1-11) and # turn on the synchroscope switch on OCB 7-8(10-11). /@
- r. Verify that the synchroscope is stopped at midnight -
then CLOSE OCB 7-8(10-11). V
- s. Turn off the synchroscope switch.
- t. After the generator is synChron12ed and initial lead is applied, perform the following:
(1) Apply 20 to 40 MVARs by adjusting the REG - VOLTAGE A0JUST SETPOINT ADJ CONTROL switch. ./M, (2) Rezero the Null voltmeter with the MANUAL , VOLTAGE A0JUST CCNTROL switch. . , . (3) Notify the Rockfo u and Chicago Load Olspatchers that the generator is synchronized and that Auxiliary Power is to be transferred. [ (4) STOP the turning gear oil pump, turbine lift pumps, and motor suction pump. Leave their control switches in AUTO. < (5) Verify that the turbine oil outlet temperature # is llL*F. [k (6) CLOSE the above seat and below seat drains. M (7) CLOSE the main steam line drains, MO-220-1, 2, 1/00llh P
QGP l-1 Revisten 45 F (8) P14Ce the supervisory recorder on LO speed. N (9) OUI.!N thelts turbine alarm. supervisory l [ l and RESET f tmt vtribrh Mays M . /k (10) - CLOSE the cff-gas filter cut! ding eypass 4.44;
~
vage5499-71A. __
- u. Transfer auxiliary power as follows:
- CAUTION 1
Oo not allow buses to be in parallel any longer than necessary. (1) furn on the transformer 11(21) to bus 11(21) synenroscope and verify that they are synchronized. <e-(2) CLOSE the transformer 11(21) to ous 11(21) .~ . tie circuit breaker, r
'( 3 )- OPEN-the transformer 12(22) to bus 11(21) tie circuit breaker,
/h .-
-(4) Turn on the transformer 11(21) to bus 14(24) synchroscope and verify that they are A synchronized. . /
U-
-(5) CLOSE the transformer l1(21) to bus 14(24) tie circuit breaker.
(6) OPEN the transformer 12(22) to bus 14(24) tie > fy circuit breaker.- /N (7) Turn off the synchroscope. r-N
- v. Verify that all turbine generator parameters are normal. ""
[# CAUTION Operation at low load should be= performed with the lowest possible back pressure. ,At low loads backpressure in excess of 4" Hg should be avolded.
- 6. - _ Increasing load after generator synchroni:ation,
- a. Oo not allow backoressure te erceed 5" Hg. when this back-pr_ essure _is reached, STOP increasing load and recuce load as necessary to maintain backpressure less than or equal to-5" Hg.
APPROVED 1/0011h gy l / g Q.C.O.S.R. l
. - - _ , .,.,-.J,.-...,_. , , . _ , _ , . . , , , . . - , . _ . - _ , _ . . _ . _ _ _ _ . _ _ _ _ _ _ , . , _ . , _ _ _ - _ - , - - , . . - _ . . . . . . _ -
l OGP 1-1 Revision 45
- b. Maintain the LOAD SET st least 10% above generator load throughout load increase,
- c. Increase cower with control rod withdrawal at the rate prescribed by tne Shift Engineer,
- d. CPEN VALVES:
3599-23, 3599-28, 3599-43, 3599-25, 3599-30, 3599-45. M50T to 0 heater LCV manual isolation. M /a/
- e. Maintain neat up rate of first stage bowl metal temperature less than 150'F per hour, f.
On 901-5(902-5) set the values of the E.G.C. in accordance with QOP 5670-1.
- g. Check OPEN or OPEN the feedwater heater extrtction valves in the following order: Verify that the extraction bypass valves are closec wnen the extraction valves are open.
(i) B feedwater heater. ((
- 32) C feedwater heater. /7 (3) D feedwater heater. M
- h. Latch all feedwater heater drain valves in accordance f 1.
with 00P 3500-1. p 4 f, /6 h0, CLOSE startup vent valves. all extraction drain valves and/,feedwater heater k
- j. Verify that the recirculation pump speed controllers aresetatminimumgeforethereactorfeedwater flow reaches 2 X 10 lbs/hr.
I
- k. When 20% power is reached (2 X 106 lbs/hr feedwater flow), verify that the RWH was operable from start -
up to 20% power. << If the RWN was inoperable after the first twelve rods were withdrawn, supply the name of the person who verified the control red movements. Verifter /
- 1. If the Hydrogen Water Chemistry System was enabled.
verify hydrogen and oxygen flow Indication on Hydrogen Addition Control Console 901-53 (902-53). /b I ' ll w u $l % APPROVED 1/00llh g)7g Q.C.O.S.R.
i CGP 1 1 l Revision 45 I
- m. Notify Radiation-Chemistry to sample anc analy:e racloactive gaseous waste (T.S. Table 4.8-1).
Foreman Notified /Od / Time
- n. Verify no ad ltional dry = ell entries are in progress or clannec. Have operator turn off cry = ell lignting. f I
- o. When reactor feecwater flow exceeds 2 X 106 Its/hr.
verify tnat the recirculation cumo speed interlock resets by clearing coth A anc B RECIRC LCCP FLCH LlHIT alarms. ,/h-
- p. As power increases, monitor the off gas radiation levels and place cencensate :emineralizer vessels in service as necessary.
- a. Before reaching 2 % reactor co.er, lace the acser:er MODE s w i t c h i n (rR Ep :e r 00P 5400- 1, s t e p F .14 verify A0 5418 cToses and A0 5414 opens. /
(T.S. 3.8.A.4) M
- r. At 30% reactor power, verify that both crannels of #
the Rod Block Monitor are operating. M ,
- 5. When the flow n the running reactor feed pump O reaches 4 X 10 lbs/hr., START a second reactor feed pump in accordance with 00P 3200-3.
NOTE Do not increase reactor power above 40% if MSOT's level is not stable or the normal or emergency Grain valves fer MSOT's are not f%nctioning properly.
- t. At 40% reactor power, perform tne following:
(1) Increase recirculation pump spesas until total core flow is greater than or equal to 45 Hib/hr. ,. (SIL 380 Rev. 1) / (2) Verify that TURS PRE'S GEN LOAD RE] SiH VALVE BYPASS alarm clears. contact Shift Engineer If alarm will not clear [ I-(3) PLACE reactor recirculation control into MASTER-PANUAL in accordance wity QOP 202-3 4
,-g,wk avw j.y147) t &"' &
g APPROVED 1/00llh DI7N Q.C.O.5.R. 1
QGP 1-1 Revision 45 (4) For feedwater Regulating valve operation above 40% power refer to 00P 600-3. g NOTE If feedwater instabilities occur. use the second feedwater regulator valve to return the feedwater system to a stacle state,
- u. Continue power ascention with QGP 3-1. /6'CMu Unit .6/ % w ' h~ 4-Dateli\me h4C- l$ i l9 9 0 / /l C
Completed c.u/h' e
" (Opeggter V '
Reviewed ($ntft Engineer) Reviewed (Operating Engineer) h (final) APPROVED $ 1/0011h gy l 7 g Q.C.O.S.R.
Simulator Suso 8/r/cr Tost Procoduro Covor Sheet Test Number Ae'/-2 PTAO-105T1 oete eerformeo </-za-so O Test Description fjy,, gy y ,y g 7y gggy g y g ,,g y , Discrepancies Section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date i Test Results
- 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test t results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above afterl correction of above discrepancies.
Retest -Coinplete Date Test Complete / Date M i#
. SFCC Acceptance Date 3 5 f/
i Simulator Supervisor's Acc ptance Date 8* 9 / L l l C.E.CO. 86-121$ 12-69 D
bli h) < GP '.:
$d! C ENG N M- Revist:n ;2 CATE_ A/ny ,.tL /190 UN!i STARTUP TO NOT STANDBY July 1989 A-4 DURPOSE T~ ' - F The curtose of thir ;r:cecure is to outline the metn d used to startup the unit from a ctic concition to a not stanacy cencitien.
S. REFl;ENCis
- 1. OCP DO-1, 50urce Range Menitoring Oceration (SRM). ATPROVdD
- 2. 'CP DC-2, :nterneciate Range Monitoring Operation (IRM).
, O I 61907
- 3. :CP 1300-1. RCIC Precaration for Standby Oceration. Q.C.O.S.R.
- 4. OOP 2300 1. nPCI System Preparation for Operation, s
- 5. 00P 1200-7. Reactor Water Cleanuo System Coolant Rejecti n.
- 6. 00P 2200-2. Startup of the First Reactor feed Dump.
- 7. OGP 4-1. Control Roc Movements anc Control Rod Secuences.
- 8. 00P 207-2, Rod Worth Minimizer Bypass Control.
- 9. 50ER-88-2, premature Criticality Events During Reactor Startue.
- 10. OTP ilC9-1. SRM Performance Check. [d - h C. DREREQUISITES INii!AL
- 1. Vaster or Minimum Start-UD Checklist complete with the exception Of tne following valve line-uo:
- a. all inocara and outboard MSIV's CLOSED. #
- e. 90 220-1, MO 220-2, and H0 220-4 CLOSED. !
- c. MO 220-3 OPEN.
- 2. Vaster Outage Check Sheet com0leted and reacy \/ k for start-up (not recuired for a scram recovery). /Y
- 3. Reactor vessel level being maintained between 20 incres and 40 inches with the Lew Ficw Controller in accordance alth 00P 600-1.
4 Criticality preciction octsined from the Nuclear , Engineer. _ , E. If this procecure is terminatec at any time curing its execution, insert a statement ac tne point of termination as to the ivasen ano ( the title of sucsecuent croceaure. Insert N/A in all remotning s blankt, cate, time ano sign last page. Retain terminateo oc;cedure in startuo package.
- /0010h -1
l lCP ' 2 Revis1 n 22
- 6. Coeration during heatup or cooldown, with the reactor :*iti:al (eutect Ouring low power physics testing), ; hall be conducted crily g wnen vessel temperature inteciately celow the flange 15 edual to or T apove tnat snewn in curve B and curve C of Figure 3.6.1 of the Technical Specifications. (IS)
D. ?QOCEDURE CAUTION As control rods are withdrawn, special care is reduired to insure conservative actions are always taken and all procedures are strictly followed during control rod reposittening. During the accroach to e criticality activities should te avoided that can distract coerators and their supervisors involved with reactor startup. Activities such as shift turnovers and surveillance testing should be delayed 50 that they occur after the approach to criticality (50ER 88-2). CAUTION Ouring the approach to criticality, the operator must use all pertinent llll instrumentation to monitor the reactor status. This includes SRH's, IRH's, and SRM period meters. There should be periodic causes in control rod withdrawal to allow this instrumentation to stabilize (50ER 88-2). 1 Bring tne reactor to criticality as follows:
- a. Verify that the operable SRH detectors are fully -
inserted and that they indicate greater than 3 cos,
- b. Verify that the SRM recorder is selected to the twc hignest indicating SRMs and that it is operating in the H! speed.
- c. Record SRM readings on QTP 1109-52 in accordance witn QTP 1109-1. (SOER 88-2)
A!' PROVED g 1/0010h ' O Q C.O.S.R.
OGP . Revtsten 22
- c. Verify that all coerable IRH detectors are fully p inserted and their range switches are all on Range 1.
V Verify tnat their recorcers are operating and one recorder on eacn channel is on H! speed, unen tne SRH period meters indicate an approach to critical (or if the Nuclear Engineer recommends that the recorders te placea in Hi speed at an earlier time cased en ena.cf-core-ilfe o" Xenon concitions, etc.i
- e. Verify that the RWH is operable and blocks are enapled to 1007. power. /u f
- f. Verify that the reactor mode switch 15 in STARIUP.
- g. Verify that there are no red blocks.
v
- h. If availacle, the following computer information may ce utilized:
(1) 00-22. TV Color Otsolay Recuest. (a) Option 43. Vessel level anc pressure, turbine speed, ano clean-up loop temperature rate (heat-up rate). (b) Option 44, di3 plays option 43 as bar trends. p a (2) 00 37, Operator Selected Analog Trend. A.~PRovgo (a) Reactor vessel level C101 (C201). y, j g l939 (b) Reactor " 'a' pressure C109 (C209)- Q.C,0.S.R. (c) Reactor coolant temperatura C123 (C223). (clean-up loop inlet temperature) (d) Clean-up loop temperature rate 0126 (0226). (heat-up rate)
- i. Withdraw control roas in accordance with QGP 4 1 Notch
. ide shall not be used between positions 00 and 24 fecm the time the count rate on the SRH with the highest inttlal reading has doubicd 3 times (8 times initial reading) until tne reactor is critical. Use of NOTCH OVERRIDE .ontrol rod
<ithdrawal is not allowed between position 04 ano 12 on control rod arrays 3 and 4 and between ecsitions 00 ar.0 24 from the time half the control rods are fully withdrawn until the reac br pressure reaches 920 psig and at least one cypass salve is ca ially open. When a rod reaches position 48, perform a coupling cneck by attempting to withdraw tne rod past position 48, (1) If uncoupling should occur, STOP rod withdrawals, notify p/
y :ne Snift Engineer and refer to the Abnormal Procedures. 1/0010h t
e-.a. , _.__ _ a -- a. - _ _ -
*CP ' :
EevisiC0 22 CAUTICN the 400 Wortn Minimiter must be operaDie for the first taelve (12) control rods to be fully withdrawn. After the first twelve rods, if at any j time the AWM is Dypassed or inocerable below 20% cower, there must ce a verifier for control rod movements, iho RWH may only be bypassed by using QOP 207 2.
- j. Withdraw control rods until the reactor is critical.
(1) The reactor is critical when the neutron count increases at a :enstant period without control red mevement. (2) Do not allow a reactor period of less than 30 teconds to be sustained. l CaUit0N l High rod and notch worths can ce encountered during accroacn to riticality on a hot starteo following a scram, the fast recovery after a scram results in peat xenon conditions l 4t the time the unit is approaching criticailty; and, when combined with zero voids and hot temperr Jres, cLei result in large notch worths in the region of criticality. Use of the i NOTCH OVERRIDE switch is not allowed between positions 04 and 12 on centrol red arrays 3 ana 4 and between positions 00 and 24 from half control rod density until the reactor pressure is 920 psig with at least one eypass i valve partially open. Caution should l be evercised in this area to avoid I pulling into a snort ceriod witn a single noten witndrawal,
- k. Notify the Load Dispatcher of reactor criticality and log the
'ollowing in tne unit log.
'l) Time, dNO
- 12) Rod position.
9[CV (3) coolant temperature. J240 AFPROVED 1/0010h 4- fjl,,t8j969 i l Q.C.O.S.R. l
.. . . _ . . _ . . . _ _ . _ . _ _ _ _ _ . _ _ . _ _ _ _ _ . . _ _ . . _ _ . _ . - .~_ _ _ _ _.
OCP I
- Revisten 22 (4) Reactor ceriod (calculated). / /9 OE O (a) 2alculated period a time for power to dcuble X 1,443.
, l
- 1. Notch-out control rods as necessary to maintain reactor ceriod. M
, m. Retain OTP 1109-52 in the startuo package. (SOER 88-2) d
- 2. Establish the reactor heat-vo rate as follows:
- a. As reactor power increases, verify all operacle IRMs are on scale ano then withdraw the SRM detectors in accordance with 00P 700-1. (SER 27-38) d
- b. As reactor oower continues to increase, increase ,
the IRM range in accordance with 00P 700-2.
- c. As the rekctor oower increases into the heating range, the power will. level off. Notch-out control rods as necessary to maintain the reactor power in the range that will heat-up the reactor coolant within the following limits:
(1) Reactor coolant heat-up 1 100'F/hr. (2) Reactor vessel to flange differential temperature i 140'F. NOTE In steo 0.2.d.. If the strip chart falls, comeuter trending can be used to monitor the following temperatures. However, to avoid reaching the process comeuter's " low reasonaole level". Instrument Maintenance should be contacted to install a multimeter to monitor the resistance directly from the RTO inouts to the comeuter. The resistance reacing can be graphea to correscena to a temperature.
- d. The following temoeraturei must ce recorded during heat-uo.
If any_one'of these; strip charts fall, record that temperature at 15 minute intervals and send the recora to Technical Staff. (1) . Reactor vessel shell. (2) R1 actor vessel flange.- ' (3) A recirculation loco. APPROVED 1/0010h N ION Q.C.O.S.R.
OGS 1 0 Revisi:n 22 (4) B recirculation loop,
- e. If the reactor vessel shell temperature is belCw 220'T and the reactor vessel is net vented, reactor vessel shell temperature and reactor coolant 3ressure shall te permant fly recor0ed at 15 minutes intervals ano the record sent to Ivchnical Staff.
(IS)
- f. Maintain the vessel ater level greater than 20 inches and less than 40 inches tnroughout heat-uo by rejecting ater as necessary through the RWCU system in accordance with 00P 1200-7.
- g. CLOSE the vessel head vent before coo' ant temperature reaches 190'F. g
- 3. Reactor vessel pressurization,
- a. Dull rods as necessary to maintain heat-vo rate.
- b. When low Dressure isolations clear, warm the HPCI and RCIC steam lines as follows:
(1) OPEN MO 2301-5; HPCI steam outboard isolation valve. ,_ . (2) Crack OPEN MO 2301-4; HPCI steam inboard isolation. /h (3) OPEN HO 1301-17; RCIC Stea'n outboard isolation. /8) (4) Crack OPEN H0 1301-16; r,CIC steam inboard isolation. (5) When HPCI steam line pressure eauals reactor vessel pressure, fully OPEN MO 2301-4. (6) When RCIC steam line pressure eauals reactor vettel pressure, fully OPEN MO 1301-16. 8 (7) Place RCIC and HPCI in standby oDeration in . accordance with QOP 1300-1 and OOP 2300-1.
- c. At 100 psig reactor pressure. OPEN oower supply breaker to MO-1001-47, RHRS shutdown cooling suction outboard isolation valve, at 250 VOC reactor building MCC 1B (2B), compartment 502 (S02) (10CFR50 Apot. dix P.;.
y esele L.-<4sk
- d. At 300 psig reactor pressure START 1 re c tor feed pump in accor0ance with QOP 3200-2.
APPROVEg 1/0010h
-o- JUL I 81989 Q.C.O.S.R.
! j t SGP 1.; Reviston 22 i
- e. at 325 esig reactor cressure, <erify that channel / :
A and B MAIN STEAM LINE LOW PRES $URE alarms :lesr. //
- f. At approximately 875 estg noten in ro s to stop tne cressure rise.
g, uaintain tse reactor vessel Oressure :etaeen !!O est; anc 920
- sig Dy one or more of the following metnces:
'1) START the RCIC system in ac:Or ance with QC$ 1300-2 anc regulate the turbine flow controller as ne:essary.
- (2) Regulate clean-up system reject (Iow as necessary.
;3) Regulate react:r power alth : ente:1 ro s as necessary, r4) If all of the above methods fail, relief valves may Oe MANUALLY operated to prevent reactor pressure from reaching 1060 psig, h, When hot stancty is reached, verify that the RWM was ODerable from startup to not standby, , _
'f the RWM was inoperable after the first twelve rocs were ~
withdrawn, supply the name of the person who verified the control roc movements, O pr verif'er Unit .9 ( M _ _ . Dat9/ Time. / b 2 0 ~~ 7 @ Completed . Reviewed /4
~t Sntft ingineeri Reviewed M" (Coerating Engineer)
APPROVED
.O 2d I 0 N (final) 1/0010h- Q.C.O.S.R.
_ _.._2 ___ . . _ . - . . , _ _ . _ _ _ _ . _ . , = . _ . . . . . . _ . _ . _ _ _ . . _ _ . _ _ _ _ . _ .
L 1 Simulator 6bo dma L Test Procoduro Cover Sheet Test Number St /-3 ! PT A O-105 T1 o ete e error m e e "- 2 7- 9 o . O Test l Description g gg g y g ggg g.jg i Discrepaneles section of Test Discrepancy Corrected l' ttom # Comments Requiring Report # (initials) Retest and Date
~
. O Test Results - 1, Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY, Retest the above after ~
correction of above discrepancies. _ Retest Complete Date Test Complete / Date WW)?/fd SFCC Acceptance (- Date F 9/ Simulator Supervisor's ccepta ce Date -9/ c.c.co ee iris ir eo
. - - -._ -.- - .- - -- - . - . . - - . - - - - . - ~ - .
UNIT '3 QGP 1 3 SHIFT ENG 1(3 Revision 30 4 DATE / W e/to UNIT HOT STANDBY TO August 1989
/ ~ '/ POWER OPERAT!ON A. PURPOSE The purpose of this procedure is to outline the method used to come out of hot stancby condition and continue power ascension.
B. REFERENCES
- 1. QOP 600-1, Placing the Low flow Controller in Service.
- 2. 00P 700-1 Source Range Monitoring Operation (SRM).
3.- 00P 700-2, Intermediate Range Monitoring Operation (IRM). > 4 QOP 250-1, Pressurizing the Hain Steam Lines.
- 5. 00P 5600-1, Gland Seal System.
~
- 6. 00P 5400-6, Condenser Mechanical Vacuum Pump Startup.
- 7. QOP 5400-1, Off-Gas System Startup.
j 8. QOP 5400-7. Condenser Mechanical Vacuum Pump Shutdown.
. 9. 00P 1200-7, Reactor Water Cleanup System Coolant Rejection.
- 10. 00P 1600-5,-Nitrogen Inerting of Primary Containment with SBGTS Using the Steam Vaporizer,
- 11. -QOP 1600-6, Nitrogen Inerting of Primary Containment with Reactor Building Ventilation Using the Steam Vaporizer.
- 12. -00P-5670-1, EGC Settings.
- 13. 00P 3500-1, Manual-Automatic Feedwater Heater Le a l Control.
14 00P 600-2, Placing the First Main Feedwater Regulator in Service.
- 15. 00P 3200-3. Startup of the Second Reactor feed Pump.
- 16. QOP 600-3, Placing the Second Main Feedwater Regulator in Service.
- 17. 00P 202-3, Reactor Recirculation System Flow Controller Operation.
- 18. QGo-3-1, Power Changes.
- 19. GEK 46390, General Electric Starting and Loading Instructions.
- 20. GEK 25460', Control Valve Allowable Temperature Olfference Curves,
- 21. _QOP 1600-19. Nitrogen Inerting of Unit 1 or Unit 2 Primary APPROVED O Containment Using the Unit Electric Vaporizer.
1/0014h NIIN Q.C.O.S.R.
CCP 1-3 Revision 30
- 22. QOP 1600-20, Nitrogen inerting of Unit I or Unit 2 Primary Containment Using Both Electric Vaporizers.
- 23. 00P 1600-14, Obtaining and Haintaining a 1.2 PS! Olfferential Pressure between the Drywell and Suppression Chamber using Nitrogen Make-up.
- 24. QGP 4-1. Control Rod Hovements and Control Rod Sequences.
- 25. QOP 207-2. Rod Worth Minimizer Bypass Control.
- 25. QAP 300-22, Water Chemistry Control.
- 27. QOP 2700-1, Hydrogen Water Chemi5try System Startup.
C. 84ERE0VISITES
- 1. Reactor is in hot standby.
- 2. If this procedure is terminated at any time during its execution, insert a statement at the point of termination as to the reason and y the title of subsequent procedure. Insert N/A in all remaining blanks. date, time and $1gn last page. Retain terminated procedure in startup package.
- 3. The turbine must be on the turbine gear for a minimum ported of ten ,
times the length of time the turbine was off of gear or a minimum / of four hours prior to turbine roll.
- 4. Verify that all water chemistry control limits are within y satisfactory bands prior to going into power operation. See QAP 300 22.
5, Off-gas system ready for operation in accordance with prerequisites /. in QOP 5400-1. D. PEOCEDURE
- 1. Pressuri:e the main steam lines as follows,
- a. Verify that the pressure regulator setpoint is 50 psig above reactor pressure to prevent opening turbine bypass valves at 7 inches vacuum in the main condenser,
- b. OPEN the MSIVs in accordance with QOP 250-1.
- c. Place the gland seal system into operation in accordance with 00P 5600-1.
- d. START the mechanical vacuum pump in accordance with 00P 5400-6,
- e. V < Fy that the chimney radiation release limits posted on j
r
. ;
- are not exceeded.
APPROVEU h 1/0014h liOV 171989 Q.C.O.S.R.
i QGP l-3 Revision 30
- f. Place the off-gas system in operation per QOP 5400-1.
- g. When the steam jet air ejector is operating !
and the main ccncenser backeressure is less !- than 7 inches Hg (greater than 23 inches Hg y vacuum), verify the mechanical vacuum pump AUTO trips. SHUTDOWN the mechanical vacuum pump in accordance with QOP S400-7. / , 1
- h. Send an operator to the turbine oil reservoir to verify the operability of the AUTO-START of <)
the motor suction pump. 4g4 (1) Verify AUTO-START of the emergency bearing oil pump from the control room # by momentarily shutting off the motor suction pump and TGOP. -
- 1. Maintain the pressure regulator setpoint 50 psig greater than f reactor pressure,
- j. Verify that the RWM is operable and blocks are enabled 'o 100% #
power. k, Withdraw control rods in accordance with QGP 4-1 as necessary to maintain the reactor power in the range that will heat-up O the reactor coolant. Use of NOTCH OVERRIDE control roc withdrawal is not allowed between position 04 and 12 on control rod arrays 3 and 4 and between positions 00 ano 24 / from half control rod density until the reactor pressure reaches 920 psig with at least one bypass valve partially open, Heat-up rate must be limited as follows. When a rod reaches positicq 48, perform a coupling check by attempting to withdraw the roo past position 48. CAUTION High rod and notch worths can be encountered during approach to criticality on a hot startup following a scram. The fast recovery after a scram results-in peak xenon conditions APPROVED at the time the unit is.appresching criticalityl and, when comoined with NOV j 7 l9&9 zero volds and hot temperatutos, can
-result in large-notch worths in the Q.C,0.S.R.
region of criticality. Caution.should be exercised in this area to avoid pulling into a short period with a single notch withdrawal, p (1)- If uncoupling should occur, STOP rod withdrawalt, notify y the Shift Engineer, and refer to the Abnormal Procedures. 1/0014h , . - . - , - . - . -
QGP l-3 i Revisien 30 I l (2) Reactor coolant heat-up ~( 100'F/hr. i 1 (3) Reactor vessel to flange differential temperature 1 1 140'F. 1 CAUTION The Rod Worth Minimizer must be operaple up to 20% power, or a verifier for conrol rod movements must be t present, the RHM may only be bypassed by using 00P 207-2. NOTE l In s tep 0.1.k. , if the s trip chart fails, computer trending can be used to monitor the following temperatures. However, to avoid reaching the process computer's " low , reasonable level", Instrument Maintenance should be contacted to ! install a multimeter to monitor the resistance directly from the RfD inputs to the sputer. The resistance r..dtng can be graphed to correspond to a temperature.
- 1. The following temperatures must be recorded during heat-up.
If any one of these strip charts fall, record that temperature at 15 minute intervals and send the record to Technical Staff. (1) Reactor vessel shell. l (2) Reactor vessel flange. (3) A recirculation loop.
'4) B recirculation loop.
- m. Maintain the vessel water level greater than 20 Inenes and less than 40 inches throughout heat-up by rejecting water as neces'ary tnrough the RHCU system in accordance with QOP 1200-7.
- n. CLOSE VALVES: 3599-23, 3599-28, 3599-43, 3599-25, 3599-30, 3599-45; MSOT to 0 heater LCVS manual
, isolation. This orevents damaging the MSDT due to flashing-to-steam-induced vibration. _ // /F d pielhd APPROV$ 1/0014h Q.C.O.S.R.
- _ . _ _ _ _ _ . -._-_-___________.__._._______..__m.-. _ _ . . _ _ _ _ ~
QGP 1 3 Revision 30
- o. If first stage bowl upper-inner surface temperature 1:
' < 250'F, the turbine shell must be warmed prior to rolling START shell warming as follows: (1) Record the first stage bowl temperature. /bl
-(2) Verify that the lead limit it off zero, I (3) Verify that the CHF.ST/SHELL warming demand meter is s' Ot. 'jF (4) RESET the turbine. ,d7 (S) OPEN the feedwater heaters (B C S D) extraction valves. Verify that the extract'on bypass valves are closed when the extraction valves are open.
/M//
NOTE If high heater level prevents opening at this time, attempt to open after unit is synchronized. (6) PRESS the OFF button.
<v (7) PRESS the CHEST /SHELL warming button.
O V Verify that the SHELL portion of the button Illuminates and the turbine control valves open. CAUTION If the turbine trips during shell warming, it may be nr.ossary to range up the !RMs in order to avoid a high neutron flux scram. (8) PRESS the INCREASE button to admit shell warming steam. -Limit the first stage shell , pressure to 70 psig to prevent rolling the turbine off the turning gear. Steam should be admitted slowly and steadily at first to Avoid excessive vessel pressure transients. Monitor operating parameters closely. / NOTC It is important that the MSDT's emergency drain valves are closed during SHELL warming. If these valves are open, turbine will roll muen easier and very poor SHELL warming occurs. Also, during SHELL varming the abovee O- seat and below drains can be closed as .APPROVEQ l an aid to better shell warming. I/0014h -S- l@V I 71969 Q.C.O.S.R. 1 L
QGP 1 3 Revis'en 30 (a) If difficulty is encountered in keeping the turbine on the turning gear during shell warming, maintain turbine RPM less than 100 RPM Dy stooping tne turbine lift pumps, (9) Continue shell warming until all of the following conditions exist: (This will take approximately 3 hours of shell warming.) (a) Shellexpansion>0.3inc"b5. o d (b) Otfferential expansion > 0.150. 8-(c) First stage bowl upper-inner surface temperature > 250'F. (Record temperature.) 2 97 / (10) Toterminateshellwarming,PRESSthe[ button. Verify that the OFF butten illuminates. Verify that the control valves close. _ NOTE Hith shell warming on, turbine startup rate cannot be selected,
- p. START chest warming as follows. If the shell was not recuired to be warmW. chest warming shall commence af ter the reactor steam temperature is greater than steam chest inner surface temperature.
(1) Verify that the turbine is reset. (2) Ve y that the load limit is off (3) PRESS the INCREASE button to admit chest . warming steam. (4) Verify that the following chest warming limits are adhered to: (a) Turbine chest heat-up rate < 100'F/hr. (b) Steam chest INNER & OUTER surface differential temperature is less than 80*F. (c) When the steam chest outer :urface temperature is greater than 460'F, ! PRESS the chest warming 0FF button. Verify that the OFF button illuminates and that chest warming is terminated. /O APPROVE 1/0014h g)7g Q.C.O.S.R.
OGP 1-3 Revisten 30 A ,<ta R O V E! Q. Verify that the main generator voltage regulator is operational as follows: Q.C.O.S.R. (1) VerifythattheGENVOLTAGECONTROLTRANSFE[R switch is in Mali. (2) Place the MANUAL VOLTAGE ADJUST CONTROL switch to the RAISE position untti the HIGH LIMIT light illuminates, then place the 1ightswltch to LOWER until the LOW LIMIT illuminates. , _ r (3) Place MAN VOLT A0J CONT switch to RAISE position until the LCH LIMIT light extinguishes. N.,0,.T E Step D.I.r. does not apply to the B train of Unit One. S.4 9 '.r. does not apply if the recombiner was started with the SJAE's.
- r. At 700 psig reactor pressure, start a recombiner per 00P 5400-1, step F.I'.
5. At 825 psig reactor pressure, verify that O Channel A and Channel 8 HAIN STEAM LINE LOW PRESSURE alarms clear. t. At 900 psig, vrrify that the operable recombiner is within the allowable band of the baseline plot of recombiner outlet temperature vs. reactor power, QOP 5450-T3 to T6. ( T.S. 3.8. A. S. ) / _ u. STOP increasing the pressure regulator setpoint when its setpoint Indicates 920 psig, d v. Verify that the main condenser backpressure - is less than 7 inches Hg (23 inches Hg vacuum). w. Continue to increase reactor power with control rod withdrawal. (1) Monitor IRM and APRM recorders. Do not allow reactor power to increase above 127. In START-UP mode. (2) Verify that the main turbine bypass valve, open as reactor power increases to maintain reactor pressure at 920 0519 . x. STOP rejecting water from the reactor vessel in accordance with 00P 1200-7 when the Low Flow O Contro)ler level. is able to maintain reactor vessel
'0014 h 7
y QGP 1-3 Revision 30 A142 ROVED y, Notify Radiation Protection to determine if the water Chemistry control limits are met for power operations (See QAP 300-22). //n,1 Q.C.O. (1) Time Radiation Protection notified AI (2) Name of Radiation Protection personnel notified . kg (3) Variance Request Report completed for any variance (see QAP 300-22). N
- z. Transfer the raactor MODE switch to RUN as follows:
(1) When 1-2 bypass valves are open, calibrate the APRH's according to the following relationship: (a) Percent power - (40/9 x no. of bypass valves open) + 1 (SER 27-88) (2) Verify on 901-5(902-5) and 901-37(902-37) that all APRMs are indicating between 4% ano 12%. (3) Verify that all APRM DOWNSCALE lights are not illuminated. (4) Verify that the main condenser backpressure is less than 9 inches Hg (greater than 21 inches Hg vacuum). _ (5) Verify that the CHANNEL A/B LOW VACUUM alarm is cleared. g (6) Place one IRM/APRM recorder on each RPS channel to APRM. (7) Place the reactor H00E switch to RUN. 8 (8) Place all IRM/APRM recorders to APRM, (9) Withdraw control rods to maintain the APRHS off downscale. (10) The drywell is reautred to be inerted within 24 hours after going into the RUN mode. (QOP 1600-5, QOP 1600-6, - 1600-@ QOP 1600-20) < (11) A differential pressure of 1.20 psid or greater is to be established between the drywell and suppression chamber within - 24 hours after going into the RUN mode. , (QOP 1600-14) 1/0014h ,
ocv I-3 Revision 30 APHHtOVEC
- b. Dispatch an operator to perform the following:
(1) Turbine oil cooler outlet temperature et ** ner. 4 . (2) Place the nydrogen panel mode, gyh p g( n the RUN /
,_f(/ ' '
(3) . CUT-0UT the turbine suotrvi}ory trip reiny. ph @tw~
- c. 'hrify above and below seat drains are open.
- d. If available, ttie following computer information may be uttilzed:
(1) 00-22 -TV-Color Otsp~ lay Request: (a) Option 2, turbine overview (vibration). (2) 00-37, Operator Selected Analog Trend. (a) -Turbine speed il46 (T246), e, Place the turbine supervisory recorder on HI speed. .
\
- f. Verify that the mctor suction oil pump and the l turning gear oil pump are running,
- g. Verify that the pressure lx steam chest
-PI 5640-50 is greater than 807. of the main .
steam Iine pressure PI 3040-10. This indicates the steam headers and turbine ) steam chest are warm'and drained. This conaltion must be satisfled before main turbine stop valves are open. .,
- h. Verify that chest warniing is at zero,
- l. Notify the Lead Dispatcher that the turbine is being rolled. Request permission to OPEN the fallowing OCBS. remove.:the-unit line disconnect Special Order Card, and CLOSE the unit line disconnect. Mg (1) Unit 1: OPEN OCB 6-7 and OCB 7-8. __
(2) Unit 2* OPEN OCB l-11 and OCB 10-11. /f/
- j. . Coordinate the opening of the ring bus.
i closing the disconnects, and rolling the tureine to minimize idling the turbi unloaded at 1800 RPM.ffg+t04..%+pe_ +W i/0014h 10-
.l 1
l
QGP l-3 . Revision 30 (12) If a drywell entry has been made when primary containment wAs required, the drywell airlock must be leak rate tested within 3 days of the entry. If frequent entries 1re made, the airlock must be leak rate tested at
- intervals not to exceed 3 days. M_
aa. Withdraw the IRM detector in accordance with 00P 700-2. Range down the IRMs as necessary to maintain them off downscale. su If 3" Hg or less backpressure is not attained prior to opening the bypass valves, a reactor scram may occur on low vacuum when preparing to roll the turbine, bb, Continue to increase reactor power with control rod withdrawal until the proper number of turbine bypass valves are open for initial generator load. (1) " Cold and Harm Start-up" initial generitor load reritres q 1-2 turbine bypass valves open. (2) " Hot Start-up" initial generator load requires 3-4 turbine bypass valves open, g cr. Place the first main feedwater regulating valve en the line in accordance with QOP 600-2. [7 dd. If operable, enable the Hydrogen Water Chemistry - System in accorda'ce with QOP 2700-1. ,
- 2. Main turbine start-up.
- 4. Verify that the main turbine has been on -\
turning gear in accordance with step C.4 and that the rotor eccentricity reading has a steady value of less than 2 mils. b t y (1) A varying eccentricity reading or one that is greater th u 2 mils could indicate a retor bow. (2) Increased shaft vibration following a rapid temperature reduction or load swing may be an indication of a cracked rotor if not rotating near critical speed, If this condition is noted. General Electric should be notified for further evaluation. APPROYf 1/0014h NOV 171969 Q.C.O.S.R.
, QGP l-3 Revision 30
- k. V elfy that the LOAD LIMIT is set at an G- indicated reading of 100% and the -
MAX COMBINED FLOH is set at 105%. / /W
- l. Determine the turbine start-up rate in accordance with the First 5ttge- Bowl Temperature established in step 0.1.n.(9)(c).
(1) 250*F to 350'F (Cold and Harm): ME0!UM (90 RPM / minute). (2) > 350'F (Hot): FAST (180 RPM / minute). CAUTION (i) Turbine should not be operated for mare than 5 minutes below 800 RPM. (2) When unusual vibration is noted at Icw speed, which may indicate packing rubbing, the turbine shoula be immediately shutdown and placed on turning gear. 00 NOT OPERATE AT LOH SPEED TO CLEAR RUBS. (3) Throughout the starting and leading of the unit, the temperrture differente across the walls and differential h expansions should be monitored and kept within the recomended limits. (4) Startup vtcuum should be as high as possible. A backpressure in excess of 5" Hg shrd be avoided.
- m. PRESS the FAST start-up rate. Y
- n. RESS tt- 1800 RPM speed set button, When the curbine rolls cf/ the turning gear, PRESS the star *-ep rato determined in step 0,2.1. Verify that the fiowing occurs:
(1) Main stos valve 2 and intercept valves 1, 3, and 5 open. (2) When main stop valve 2 is full open, & main stop valves 1, 3, and 4 open. I'// (3) When intercept vah; '
.nd 5 are full open, intercept va...s 2, 4, and 6 open.
APPROVED NOV 171969 1/0014h ell-
GGP 1-3 Revision 30- APPROVE (4) When all main stop valves and intercept valves are full open, the speed error q,e, signal will open the control valves ' enough te roll the turbine off the turning gear.
-( 5 ) Verify that the main turbine is accelerating. _,
- o. ,ter turbine vibration during acceleration. If several cscosecutive vibrations are greater tnan 10 mils and increasing, notify the Shift Engineer ano consider tripping '
the unit. ' p, When the main turbine speed approaches the [ critical soeed of 1200 RPM, select the FAST start-up and then re-select the procer sti.rt-up rate after the turbine is faster than this / critical speed. /~~)-
- a. STOP the turning gear motor.
,/ v
- r. When the turbine speed levels out at 1800 RPM, verify that the turbine oil temperature levels out at ilS*F. Verify that the turbine is running satisfactorily with proper expansion -
and with vibration less than 5 mils. 1
- 3. Synchronizinc a main genere,:or, 9
- a. Verify the following prior to unit synch,* ization:
(1) Ring bus is open and the unit line disconnects are closed. - (2) Stator cooling wa'er . cnlied to the A field rectifiers. 'r (3) Generator voltage control transfL A switch in MAN. # , (4) hanual VOLT A0J CONT is just above its low limit. Do this by lowering the setpoint to the low limit and then raising it until the LOW LIMIT light extinguishes.
- b. START an isolated phase ous blower,
- c. If available, the following computer information may be utilized:
(1) 00-22, TV Color 01 splay Recuest. (a) Option 11, cold and hor end hydrogen temperatures. I'0014h -12
QGP l-3 Revision 30 (b) Option 48, load pick-up data.
'2) 00-37, Operator Selected Analog Trend.
(a) Gross megawatt electric G128 (G228).
, (b) Hydrogen cold end temperature G121 (G221).
(3) Verify that hydrogen cold end temperatures, G-121(G-22'), are approximately 40'C. -
- d. Notify the Equipment Operator that tN.
generator field breaker is to be closed. M
- e. CLOSE the generator field breaker,
- f. If the generator voltage increases beyond 19 kv, then t?lp the field breaker immediately, [
g ,- Using the MANUAL-VOLTAGE ADJUST CONTROL switch, adjust the stator voltage so that all three phases indicate 18 KV,
- h. Using the 'G VOLTAGE ADJUST SETPOINT ADJ CONTROL m tch, bring the Null Voltm1ter to zero,
- 1. Place the GEN VOLTAGE CONTROL TRANSFER switch in A'JTO.
g W , J. Place the OCB 6-7(1-11' synchroscope switch p to OH. U
- k. Verify that the synchroscope dial is rotating, the synchronizing lights are operating, and the INCOMING and RUNNING vo'tmeters are Indicating.
- 1. Adjust the generator speed with the governor control switch to obtain a s'ow clockwise (FAST) rotation on the synchroscope clal, m.
Use the REG VOLTAGE A0JUST SETPOINT ADJ CONTROL switch to bring the INCOMING voltage slightly higher than the RUNNING voltage when the synchroscope dial is at twelve o' clock,
- n. Readjust the generator speed and voltage as necessary to maintain proper rotation and voltage.
- o. When the synchroscope dial is
- 0ximately I degree before midnt1ht. ^ LOSE OC8 6-7s ;). Verify that O- the OCB closed and synchroscope dial stops at twelve o' clock.
APPROVED 1/0014h g)7g Q.C.O.E A
QGP 1-3 Revision 30
- p. Use the LOAD SET to slowly bring generator power up to the appropriate initial load. Hold this initial load for a minimum of 15 minutes.
(1) Cold turbine, 50 MWe. 1 (2) Warm turbine, 50 MWe, (3) Hot turbine, 120 MWe.
- q. Turn off the synchroscope switch on OCS 6-7(1-11) and turn Sn the synchroscope switch on OCS 7-8(10-11).
/
- r. kerify that the synchroscope is stopped at twelve o' clock then CLOSE OCB 7-8(10-11). _
- s. Turn off the synchroscope switch.
,r
- t. After the generator is synchronized and initial load is applied, perform the following:
(1) Apply 20 to 40 MVARs by adjusting the REG VOLTAGE ADJUST SETPOINT ADJ CONTROL switch. .. (2) Rezero the Null Voltmeter with the MANUAL . VOLTAGE ADJUST CONTROL switch. . (3) Notify the Rockford and Chicago load Dispatchers that the generator is synchronized and that auxiliary power is to be transferred. A/d (4) STOP the turning gear oil pump, turbine lift pumps, and motor suction pump. Leave their control switches in AUTO. ,8 (5) Ver'#v that the turbine oil outlet temps 'ture is 115'F. (6) CLOSE ' above seat and below seat drains. (7) CLOSE the main steam line drains, MO-220-1, 2, and 3, (8) Place the supervisory recorder n Lo speed. (9) CUT-IN the turbine supervisory trip relays and RESET lts alare,
%m::-.r < APPR (10) CLOSE the off-gas filter building l bypass valve 5499-71A per 00P 5400-1, NOV 17 m
- i. step F.13.
!' Q.C.O.S.R. 1/0014h i OGP 1-3 Revision 30 g u. Transfer auxiliary power at follows: CAUTION Oo not allow buses.to be in parallel any longer than necessary. (1) Turn on the transformer 11 (21) to bus 11 (21) synchroscope and verify i that th6y are synchronized. (2) CLOSE the transformer 11-(21) to bus 11 (21) tie circuit breakar. 'c (3) OPEN the transformer 12 (22) to bus 11 (21) - tle circuit breaker. v (4)- Turn on the transformer 11 (21) to bus 14-(24) synchroscope and verify that they are synchronized. (5) CLOSE the transformer 11-(21) to bus 14 (24) tie circuit breaker. O OPEN the transformer 12 (22) to bus 14 (24) tie circuit breaker. (7) Turn off the synchrr.aope. v, Verify that all turbine generator parameters are normal. CAUTION Operction at low load should be performed with the lowest possible backpressure. At icw loads backpressure in excess of 4" Hg should be avolded.
-4. Increasing load after generator synchronization,
- a. Do not allow backpressure to exceed 5" Hg. Lnen this backpressure is reached STOP increasing load and reduce load as necessary-to maintain backpressure less then or equal to 5" Hg.
-b. Maintain the LOAD SET at least 10% above generator load throughout load increase.
- c. Increase power with coMeol rod withdrawal at the rate 3
~ prescribed by the $N Ft [ng3nger, J
APPROVED 1s0014h NOV f 71969 Q.C.O.S.R.
QGP 1-3 Revision 30 J. OPEN VALVES: 3599-23, 3599-28, 3599-43, 3599-25, 3599-30, 3599-45: MSDT to 0 heater LCVs manual isolation. gg
- e. Maintain heat up rate of first stage bowl metal tempera',ure
}ess than 150'F per hour, f.
On 901-5 (902-5) set the value of the E.G.C. In accordance with QOP 5670-1.
- g. Check OPEN or OPEN the feedwater heater extraction valves in the following order: verify that the extraction oypass valves are closed when the extraction valves are open.
(1) B feedwater heater. (2) C feedwater heater. (3) 0 feedwater heater.
- h. Latch all feedwater heater drain valves i accordance with QOP 3500-1. p
- 1. CLOSE all extraction drain valves and feedwater heater startup vent valve.s. ._
- j. Verify that the recirculation pump speed control'ers are set at a minimum before the reactor feedwater flow reaches 2 X y 106 lbs/hr.
k, When 20% power is reached (2 X 106 lbs/hr feedwater flow), ' verify that the RWH was operable from not standby to 207. power.
/
If the RWH was inoperable belcs 20% power, supply the name of the person who verifled the control rod movements. WV Verifier
- 1. If the Hydrogen Water Chcmistry System was enabled, verify hydrogen and oxygen flow indication on Hydrogen Addition Control Console 901-53 (902-53),
- m. Notify Radiation-Chemistry to sample and analyze radioactive gaseous waste. (T.S. Table 4.8-1)
Foreman Notified
- n. When reactor feedwater flow exceeds 2 X 106 lbs/hr. , verify that the recirculation cump speed interlock resets by clearing both A and B RECIRCULATION LOOP FLOW LIMIT alarms.
APPROVED hi : 1/0014h gy j 7 g Q.C.O.S.R. I 1
QGP l~-3
-Revision =30
.t. Continue power' ascension'in accordance .;cn QGP-3-1.-
Unit $ Ih'Y1 w # th.I. Date/T\me ' klovmbeu $ Q lff D Completed
/ (/
I-dr) (Ope Reviewed Mb ' (Shift Engineer) Reviewed M~ (Operating Engineer) Q m APPRvVED-(final)
' 1/0014h- NOT171989 Q.C.O.S.R.
),
1
QGP 1-3 t t Revision 30
- o. As power increases, monitor the off gas radiation levels and place condensate demineralizer vessels in service if necesse 7
- p. At 30% reactor power, ve'.ify that both channels of the Rod Block Monitor are operating. /
- q. .When the flow gn the running reactor feed pump "
reaches 4 X 100 lbs/hr., START a second reactor feed pump in accordance with QOP 3200-3.
- r. Before reaching 30% reactor power, place the adsorber MODE switch in TREAT per 00P 5400-1, step F.14. Verify A0 5418 closes and A0 5414 opens. (T,5. 3.8 A.4)
NOTE Do not increase reactor power above 40% if MSDT's level is not stable or s the noraal or emergency drain valves for MSOT's are not functioning properly,
- s. At 40% reactor power, perform the following:
(1) Increase recirculation pump speeds until total core flow is greater than or equal to 45 Mlb/hr. (SIL 380 Rev. 1) h g (2) Verify that the TURB PRESS GEN LOAD RE] STM VALVE BYPASS alarm clears. If alarm will not clear, contact Shift Engineer. (3) PLACE reactor recirculation control into MASTER-MANUAL in accordance with Q3P 202-3. (4) For feedwater regulator valve operation above 40% power refer to QOP 600-3. NOTE If feedwater instabilities occur use second feedwater regulator valve to return the feedwater system to a stable state. APNROVE0& 1/0014h Q.C,0,S,p, l
Simulator Ova Omer l Tost Procedure Cover Sheet Test Number & z-s a /-s2 PTAO-105T1 Date Performed /2-4-90 () Test Descriptlon $E/CroA SMAM h%mury ukerup 0Hecwsr i Discrepancies section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date Test Results [ 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after, correction of above discrepancies.
Retect 'omplete
. Date l Test Complete M Date /2 /h 94_
SFCC Acceptance nd Date 3
- V ' Yl Simulator Supervisor's ccepta ce h Date -88'9[
e,c.co, ae iz n i2-se
APPROVED 1 DEC 101990 l i Unit Q.C.O.S.R' QGP 2-3 Shift Engr.._ h mI w A [4 13 Revision 27 _L Date Dec F/9'r0 September 1989 ff. ' REACTOR SCRAM A. PURPOSE To outline the procedure use1 to shutdown the reactor when an emergency l requires a manual scram to pr3 vent exceeding a safety limit or damage to plant equipment. The same steps are taken following an automatic scram. B, REFERENCES
- 1. QGP 2-1, Normal Unit Shutdown.
2, QGP 2-51, Scram Report Data Sheet and Start-up Authorization.
- 3. NSO Directive N00 P0.6.
4; QGA 100-1, Reactor Pressure Vessel Water Level Control.
- 5. QOP $400-8, Starting Sparge Air to the Recombiner.
C. PREREQUISITES 4
- 1. An. automatic reactor scram has occurred, or during plant operation t
y . the operator has. recognized the need to implement this procedure,
- 2. If sufficient time is available, before scramming the reactor, perform one or more of the following:
- a. If the unit is operating in ECC,- trip EGC and retum
- recirculation flow control to MANUAL,
- b. Reduce power with recirculation flow , reduce the trans,ent.
- c. Transfer auxiliary power to T12 (T22).
- d. START-the turbine motor suction pump and the ESOP.
- e. Raise reactor water level to high level alarm point (approximately 40 inches),
- t. .Announce the impending' reactor scram over the plant page system.
O. PROCEDURE INITIAL
-1. }f_ this procedure has oeen entered from a QGA procedure, lHJ continue in this procedure at step 0.9.
O V 2. Press both SCRAM buttons if a manual scram is required. -- NO i 1/0024h , -.c. -e 4 ~, - , __.__________________.__u.. _ _ _
- APPROVED I ON Cilijn27 Q,C,0.S.R.
- 3. Place reactor node switch to SHUTDOWN. /k 4 E a Group ! Isolation occurs.
OR reactor pressure vessel pressure exceeds 1060 psig, THEN exit this procedure and enter QGA 100-1, Reactor Pressure Vessel Hater Level Control.
- 5. Maintain feedwater in AUTO unless controller failure occurs. "
Control level between +20 and +40 inches.
- a. On a reactor scram, if the f0edwater control system is in AUTO, the reactor water level dll be m trolled at 50% of ' ,
the setpoint. If the scram is reset wh.le the feedwater control system is in AUTO, reactor water level will return to the setpoint value,
- b. If necessary, place the feed control system in MANUAL or STOP /
feed pumps to prevent excessive reactor level,
- c. If reactor water level has increased above +48 inches, reject water to the hotwell via FCV 1239, reactor water clean-up system blowdown valve. Closely monitor RBCCH temperature and 7 drywell pressure. The added heat load through the non-regenerative heat exchangers will cause drywell pressure to increase,
- d. E reactor pressure vessel water level cannot be maintained /
above +8 inches, THEN exit this procedure and enter QGA 100-1, Reactor Pressure Vessel Hater Level Control. NOTE Verifying all rods inserted on a Reactor scram may be performed by Toving the mode switch to " Refuel". / If the Reactor is still scrammed and not required to be in COLD SHUT 00HN, 005 500-4, Moving the Reactor Mode Switch out of the Shutdown Position is not required. l INITIAL
- 6. Verify all control rods fully inserted. M
- a. E any control rod is n_ot inserted to or beyond position 02 AjLD reactor power is above 3% or cannot be determined, THEN exit this procedure and enter QGA 100-1. Reactor Pressure Vessel Water Level Control.
- b. If all the control rods did not scram into position 00, record the rod coordinates and position en QGP 2-51 and then insert to position 00.
1/0024h QGP 2-3 Revision 27 pg 7. Verify scram discharge volume vent valves V 302-21A, 21B, 21C, and 210 and drain valves 302-22A. 228, 22C, and 220 CLOSE. If valves ' are not operable, log the reason (if known) and alert the Shift Engineer to notify the NRC within 24 hours as per NRC bulletin commitment. /If
- 8. Verify reactor recirculation pumps have run back to minimum speed on feedwater flow (2 x 106 lbs/hr and-recirculation master controller is in HASTER-MANUAL. h I
- 9. Verify that the SRM and IRM detectors fully insert automatically.
- 10. Verify turbine and generator have tripped, if I the generator has not tripped within 30 seconds, verify zero or negative output, then PRESS the Generator Trip button. -
- a. Verify turbine motor suction pump auto started. 4
- b. . The Generator Trip also trips stator cooling pumps. Reset 86Gl(G2) and 86BGl(G2) relay to start stator cooling > pumps. % <h ( - o W ) M ,
- 11. Verify that' alarm H-9, GEN EXCITER F11LO BRKR OPEN, .
-on panel-901-8(902-8) is energized.
- 12. Verify.aexiliary power has. transferred to the reserve auxiliary transformer. [
'13. Announcethereactorscramovertheplantpagesystem.[ h 14 . -- Limit the cooldown rate to 100'F/hr. In an emergency,- a 240' step change may be used. v Do not exceed the 140'ai limit between reactor
-vessel-and flange.
jp
- 15. Monitor the reactor safety systems such as HPCI, auto depressurization, LPCI
. operation, isolation valves, etc. Operate
- .. manually if required. d'
- 16. -Maintain vacuum in the main condenser with the SJAE, and uypass y steam to cool down and depressurize:the system, if cooldown is required.
- 17. If it becomes.'necessary to raise reactor water level, do so very slowly to minimize thermal shock on the-system.
APPROVED
'l/0024h Q.c.o.s A
___________m.___._
OGP 2-3 Revision 27
- 18. Check control room panels to verify all systems are operating properly. /h
- 19. Perform the following on the Off Gas system within 30 minutes after the scram.
1 a. (vf( h k h hc^ Startspargeairtotherecombinerinaccor)dancewith QOP 5400-8. /.
- b. Place the Adsorber H00E switch in BYPASS on 901-54 4 (902-54). /#
! NOTE l For the B train of Unit One off gas j system, skip steps 0.19.c. and 0.19.d l below.
- c. OPEN the recombiner bypass, VALVE 5499-718. Nd
- d. CLOSE the recombiner train inlet, VALVE 5499 'i5/76. _f #3 l CAUTION If only channel A of the RPS can be reset, the scram valves may not close. In this case, close the scram discharge volume vents and drains by f pressing tt^ close buttons on the l 901-5(902-5) O nel. Verify that the vents and dralas close. If they still do not close insert a manual scram to close them.
- 20. Reset RPS channel A and channel B trips as follows with mode switch in SHUT 00HN or REFUEL.
- a. Place SOV high water level bypass switch to BYPASS. j Verify alarm on 901-5(902-5). /7 l b. Reset RDS channels A and B. Verify that the 50V vent and drain valves OPEN to drain the SOV and tnat the individual scram valves CLOSE.
- c. After draining, place SOV high water level bypass f switch to NORMAL. Clear alarms. 'N
- 21. If the unit was operating in EGC or AUTO rlow control, press the EGC trip button and transfer m 4.s b Ver
- p recirculation pump control to individual manual
- with the pump speed demand at minimum. #8 Complete Control Room Log Book 22.
intries.[' . APPROV$ DEC 101990 1/0024h Q.C.O.S.R.
- . _ _ . - . . . . . . .. . _ _ . _ . . - ._.. . - ._ _.~.. . _ _._ __ _._._
QGP'2-3 Revision 27 ,
- 23. Complete Scram Report Data Sheet (QGP 2-51), d [+M
- 24. --
Submit Operating the cr.apleted
'.igineer. Submit a Deviation scramReport with QGP report data2-51 sheet, QGP 2 unless +.< scram was initiated in accordance with QGP 2-1, step 0.33.~
- 25. Maks an entry on the ARRAY:IN line of each applicable Control Rod (un-)
Psquence sheet (QTP 1600-S3) i ndicating the fact that the control iods in that step of the sequence were inserted by means of-'a i eactor strain.
- 26. - Initiate the minimum startup checklist QGP l-52 if a fast scram [
recovery-is to occur. 4#u I
- 27. Ifthe'scramoccurredduringaunitshutdownorifitisrequired[pg to shutdown the reactor, complete QGP 2-1, Normal Unit Shutdown.
- 28. - If desired, reset control room ventilation isolation-by pushing RESET button on the 901-5 (902-5) panel and the RESET switch on the d i/2-9400-105 panel in the "B" train HVAC equipment room.
DATE/ TIME: /2'/6'76 6933
.PLETED: - j
g-(0 pef'ator) REVIEWED: (Shift Engineer) REVIEHED:
-10rer'eing Engtreer) l APPROVED DEC 101990 = l (final) 1/0024h. - 5 Q.C,0.S.R.-
F yw a e ce v 7-.rmr w r rw~ , - er e-e.- e mv - a w .. -r-www r-n- - , < - - . , =e E~- ---=---w*-----. .+e. - < - =
- Unlt . 5 / % L M [** h QGP 1-S2 Date. /.2 /6 90 Revision 28
( S.E. -M , February 1991 - MINIMUM STARTUP CHECKLIST (All Startups Following Shutdown Less Than 48 Hrs. Including Scram Recovery) Tech. Spec. requirements for reactor st'rtup indicated by *. Tech. Spec. references shown as (T.S....).
.For a system to be considered operable, all required survt111&nces must have been performed within the required time period.
- 1. Scram recovery startup only. INITIAL /0 ATE / TIME
- a. QGP 2-3 completed. /2'/6 4 M M
- b. Verify that-reactor protection system components operated as required during the scram. If there are indications of a f malfunction of any RPS comoonent, that component and associated _ logic circuits must be demonstrated operable prior to start-up.
This work must be documented with a work request.
-c. A thorough investigatilon of circumstances surrounding the scram has been conducted to e determine the root cause of the scram. The cause has been satisfactorily corrected. _. .
QB
- d. Following a thorough investigation, the root cause of the scram cannot be determined. The reactor protection system operated satisfactoril y and startup is peraitted by the concurrence of the Production Superintendent or-his designated /
alternate. /7
- 2. The following systems are operable:
- a. All ECCS systems (T.S. 3.5.A,B,C,0,E and G).
- b. The Auto Blowdown Inhibit Keylock switch .
is in NORMAL (T.S. 3.5.0).
- c. All. safety valves (1.5. 3.6.E).
- i
- d. Both standby liquid control systems /)y (T.S. 3.4.A), */ #
g JU APPROVED L FEB 191991 U0013h - Q.C.O.S.R. 1
QGP 1-S2 Revision 28 lELUyJD4TE/TlBE G)! e. Both standby gas treatment systems
%M (T.S. 3.7.8).
- f. Drywell coolers and booster fans in operation. (?,',
- g. Condensate pump room flood protection system j ;
(T.S. 3.5'H). (p ' h, At least 1 monitoring system for stach gas (chimney) and each exhaust ventilatio' duct 4 (T.S. 3.8.A.1). /#
- 1. Dijwell sump and air sampling systems (T.S. 3.6.D.2). .
-j . At least four MSIV room area coolers in
-operation, m,mn ./ j
- k. Verify main steam line isolation valves ind main steam:line drains ' PEN (drains may se lef t closed if reac':<r pressu e is greecer than 100 psig), s / t <' 4 - bV '
._off-gas system reaoy for operation in 1.
accordance with prerequisites in QOP 5400-1. (Air Ejector Suction valves and steam supplies to air ejectors may be left open ',f vacuum is maintained). p< 3, "R" doors locked.and location of "R" keys checked. (May be omitted if no "R" areas were opened up-and released). (pyn./M rg
- 4. RHRS and Core Spray compartment doors CLOSED (T.S. 3.7 C.2). [u ./d
- 5. Primary and secondary containment establis e , -
(T.S. 3.7 A.2 and 3.7 C.1). (gfe,d g
- 6. Pressure. suppression chamber level at 2 2 incnes and temperature < 95'F. (T.S.'3.7.A.I.). [4 /
-7. Electric power availability:
- a. Power available from one 345 KV l_ine through g T12(22).(T.S. 3.9,A).
f5' _
- b. Power available from another 345 KV line through the 14-1/24-1 but tie, (T.S. 3.9.A). b r ;
=O~ APPROVED fE8191991 1/0013h Q.C.O.S.R.
- . - . - ~ . - -. . . - --- . . . . _ - - -
APPROVED , l QGP l-52 FEB 191991 Revision 28
. Q.C.O.S.R. INITIAL /DATE/ TIME l 1
zO-Y c. The unit and the 1/2 D.G. operable, (T.S. 3.9 A). M I
- d. .4 KV buses 13-1 and 14-1-(23-1 and 24-1) energized, (T.S. 3.9.A). /f-r a
{
- e. 480 volt buses 18 and 19 (28 and 29) .
energized. (T.S. 3.9.A). l 1
- f. All 250, 125 and the unit 24/48 volt battery systams operable with battery charger operable /
for esch battery, (T.S. 3.9.E). /f _ (1) See Tech Spec 3,9 C for exceptior,s to # startup from hot shutdown (>212'F) condition .
- 8. All control rods inserted or Tech Spec 3.3.A.1 -
and 3.3.A.2 met.
- 9. _ Instrument Maintenance will perform the following-tests (required by Tech Specs unless performed w hin the preceding 7 days) (TsS. 4.1.A and g
- a. Prior to Startup-Shutdown Instrument
*Mb -
Surveillance (S.T. 41)-
- 10. Verify that thetfollowing functional tests are cotpleted if not performed within the last seven days.
- a. SRM NOT IN STAR"UP POS TION Itod BI'ock (QOS 700-1). ,
-b. IRH NOT IN STARTl'P POSITION i<od Block (QOS 700-3). ,,
- 11. All SRH detectors reading 3 cps and fully ,
Inserted. This requirement meet: and exceeds :T.S. 3.3.B.4. /
- a. Highest SRM-in each channel selected to .
record. ~
- b. ~SRMcountsCH21[CH22 CH 23__ CH 24
- c. Theaboverequirementmaybereducedtoat[
least 2 SRM channels operable with the concurrence of the Production 5.sperintendent. Prod S.ot/Date/ Time R D Ar v e -
- 12. Review "S" lock log for locks removed and replaced.
7q 4- gh 1/0013h ##
QGP l-S2 Revision 28 , 7 - -- , INITIAL /DATE/ TIM t
- 13. RHH Control Rod Sequence Verification, QTS 680-1, performed (T.S.-?.3.B.3). QTS 680-1 need not be
- performed for stact-up when no sequence e.hanges have.been made and when no aalntenance has been performed on the RHH (For verification, contact a Qualified Nuclear Engineer.). If QTS 680-1 is not applicable, enter "NA" in oignk,
- N
- 14. With the RHM mode switch in NORMAL, reactor mode switch in STARTUP, no rod drift alarms present and the first rod of the first step in the sequence selected, record if the ready light is present for the respective RHM computer.
"A" [ "B" m
One RHM must be operable to proceed. If one RHH cannot be made operable, /- contact a Nuclear Engineer for assistance. >- - __ 15. If "B" RHH computer is READY, place-the selection ' D switch to 'B' and depress the initialize button ( and-verify insert and withdraw blocks clear and no-alarm messages are present after completion of the initialization. If the READY light is not present, enter NA in the blank and for steps G.5;a, b, c, and d below.
- a. Depress DIAGNOSTIC button and verify diagnostic test is completed with no errors.
-(T.S. 4.3.B.3). The screen should indicate "BELOW 20% POWER" with blocks enabled.
Any unacknowledged alarms should be /J acknowledged. ?/"
- b. Select an out-of-sequence rod and verify that a select error occurs (T.S. 4.3.B.3).
This_will be denoted by the selected rod
-appearing white on the display screen.
*g
- c. . Notch withdraw the out-of-sequence rod and verify ROD BLOCK occurs at pos1tton 02 (T.S. 4.3.B.3). *
- d. Return the rod in step IS.c. to position 00.
] APPROVED FEB 191991 1/0012h .Q.C.O.S.R. l l
APPROVED 1 QGP l-52 FEB 191991 Revision 28
. , Q.C.O.S.R. INITIAL /DATE/ TIME-
- 10. P o hWM computer is READY, place the selection Iwltch to 'A' and depress the INITIALIZE button and verify insert _and withdraw block clear and no alar.m messages are present after completion of the INITIALIZATION. If the READY light is not present, enter NA tr, the BLANK and for steps 16.a. b, c, and d below.
f'
- a. Depress O! AGNOSTIC button and verify diagnostic test is completed with no errors.
(T.S. 4.3.B.3). The screen should indicate "BELOH 207. POWER" with blocks enabled. Any unacknowledged alarms should-be acknowledgcd. *
- b. _ Select an out-of-3equence rod and verify that a select error occurs. (T.S. 4.3.B.3).
This will be denoted by the selected rod ,A appearing white on the display screen. * '&
- c. Notch withdraw the out-of-sequence rod and verify ROD BLOCK occurs at position 02 (T.S. 4.3.B.3.). *
- d. Return the rod-in step 16.c. to position 00, d '
17, O't pump operability completed (r 202-4).
-W ify recire pumps are operatinq , th retirc MG ~ speed controllers in MANUA , and set at minimo: " ~mimately 307.) .
18 .- Intermediate Range'Honitoring System.
- a. Chambers fully inserted. I
- b. All channels in each protective channel in service. This requirement may be reduced to at least 3 channels in each protective channel with the concurrence of the Production Superintendent. P t/Date/ Time '
- c. IRM channels selected on power range-recorders. _ _ .
- d. -IRM range switch positioned as required.
- 19. Average Power-Range Monitoring System.
- a. Calibration and checklists completed if required. pg 4 i> . At least two (2) channels in each protective -
l channel in service. 1/0013h -S- l
QGP l-52 Revision 28-
.. , INITIAL /DATE/ TIME
- 20. Rod Block Honitoring System.
- a. At least one (1) channel operative. h
-21. ' Reactor Protective System.
- a. Channel A reset. I
- b. Channel B reset. 4'J
- 22. Scram Discharge Volume.
- a. Verify SOV vent and drain valves are in the NORMAL position and SOV high level scram bypass switch not in BYPASS. / .i
/
- 23. TR-260-20 operable with temperature sensors for main steam relief and safety valves indicating. [h (T.S. Table 3.2-4) /
- 24. Main steam safety ed relief valve acoustic monitors on 901-21 (902-21) GREEN 1ights ON and //
digital displays indi:ating. -(T.S. Table 3.2-4) /7
- 25. -If maintenance performed on main steam relief or V,G safety valve, verify acoustic monitor functional test has been performed. (QTS 140-4)
(T.S. Table 4.2-2) NI$-
- 26. Required valve checklists completed. #/k
~27. CRD system in service and accumulators charged.
- 2 8 .- Notify-Radiation Protection to determine if the-water chemistry control limits are met for startup (see QAP 300-22) and to sample reactor water every 4 hours and analyze-for. conductivity and chlorides.until steam flow is greater than 100,000 LB/HR. (T.S. 4.6.C.2). 8
- a. Time Radiation Protection notified .
b, Name of Radiation P otection personnel. notifled .
- c. Variance Reauest Report completed as p needed. F //
jh APPROVED o FEB 191991 1/0013h C.C.O.S.R.
.l
-- ~ . _ _ _ ._-
QGP l-52 Revision 28
. INITIAL /DATE/ TIME
. 29. Check the Electrical Jumper and Relay _ Block Log
.to verify that all unnecessary jumpers and blocks have been removed. 48
- 30. Authorization receiv0d for startup from Production Superintendent or Assistant Superintendent Operating. _///I i
- 31. Load Olspatcher notified of impending startup. #/3 _
l
- 32. Announced primary and secondary containment integrity in effect. A/ d
- 33. Announced reactor startup to commence. NO
- 34. REACTOR H00E switch.in STARTUP,
- 35. Note any items on'this checklist that could not be satisfied: ;
v4 iks nd 9dl3 ffd becca ,e b udnubd6
- 4. e
- 4- n dua hn u rs m s anhib '%-k / vom, ,5 v a u ~4-fvs - V ' '
t
, :36. Initiate the applicable unit startup procedure. [
4: DATE/ TIME /2 ./4 90 Ofg5' COMPLETED -
' '# (Operyor)
REVIEHED 8 (Shift Engineer) REVIEHED IM
'(0perating Engineer) 1:
I APPROVED
- - . pf ls FEB 191991 l (final) Q.c.o.s.a.
1/0013h I L -m . -. _ _ - . _ , _ . _ _ . . _ _ . - . . _ . _ . _ ._. . - . . _ . _ - . _ . - - _ , _ . . - _ _ , . _ .
Simulator MuAo dtr/dr Test Procedure- Cover Sheet Test Number - os e 2-/ PTAO-105T1 -h - Date Performed //- 2*) *J o Description g g gf7 ,g,7 g Discrepancies Section of Test Discrepancy Corrected Item # Commer ts Requiring Report # (initials) Retest and Dato
-Test Results
- 1. Test Completed. Satisfactorily 2.- After correction of the above discrepancies, test results are cetisfactoy, Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY, Retest the above after; correction of above discrepancies, Retest Comp!ste Date
. Test Complete [ + Date //~2 9' id SFCC Acceptance e Date J T[9/
Simulator- Supervisor's Accept ce M , Date _ -f.- 9/ c.c.co. ee iais i2 oo -
_. ~ . _ - _ _ ..-.- . . _ _ _ _ _ .. _ _ . - _ .__ _ . . _ _ __ _ _ _
-Unit $[% . QGP 2-1 Shift Engr.- ve Revision 34 -l t Oatt M w #9 M io October 1989 ;
NORMAL UNIT SHUTDOWN' q A. PURPOSE The purpose of this procedure is to tine
- method used to shutdown the unit from a power-generation modt *b - 'qutdown condttion.
B.- REFERENCES <
- 1. Q0? 1000-2, Venting the Residn' t Ren; val System.
- 2. 00P 1000-3, Filling and Venting the Shu.tdown Cooling Suction Header.
- 3. 00P_ 5670-1, EGC Settings.
- 4. QOP 202-3, Reactor Recirculation System Flow Controller Opention.
- 5. 00PL600-8. Removing One of Two feedwater Regulator Valves.from Service.
c
~6. QOP 3200-5, Reactor Feed Pump Shutdown.
- 7. QOP_700-2, Intermediate Range Monitoring Operation (IRM).
- 8. 005 700 Block.
- 9. 00P 600-5, 4 moving-the Main Feedwater Regulator from Service.
- 10. 00P 700-1, Source Range Monitoring Operation (SRM).
- 11. QOP-1000-5, Shutdown Cooling Startup.and Operation.
- 12. .QOP 5400-2, Off-Gas System Shutdown.
- 13. 00P 5400-8, Starting Sparge Air to the Recombiner,
-14. QOP 1000-7, Reactor Head Cooling..
- 15. QOP 5600-1, Gland Seal. System.
16.- QOS 250-1 MSIV~ Closure Monthly Scram Sensor Functional Test.
- 17. 00P 1200-12 Changeover of Clean-up Recirculation Pump Suction from Hot to Cold-or Cold to Hot.
- 18. QGP-4-1,-Control Rod-Hovements and Control Rod Sequences.
19 QOP 207-2, Rod Worth Minimizer Bypass Control. O Aeraoveo 1/0012h~ -1 !4AR 61990 c.c.o.S.R.
QGP 2-1 Revision 34 C. PRERE")UISIT ES l-
- 1. Permission has been obtained from the Load Dispatcher to shutdown the unit.
i
- 2. The Rod Worth Minimizer is operational /or a qualified person is l available to verify rod moverents in accordance with the rod
! sequence chosen prior to reactor power reaching 207.. The RWH may only be bypassed by using 00P 207-2. (TS)
- 3. The RHR system filled and vented in accordance with 00P 1000-2 and
- its SDC suction header filled and vented in accordance with l QOP 1000-3.
l
- 4. Drywell de-inerting may commence 24 hours before placing the mode i
switch in SHUT 00HN, The drywell-suppression chamber pressure differential may be relaxed at this time. (TS)
- 5. Perform MSIV Closure Monthly Scram Sensor Functional Test, 005 250-1.
! a. If no work is to be performed in the HSIV room or drywell, this prerequisite can be bypassed if authorized by an Operating Engineer. #h Op Engr. Date l
- 6. If this procedure is terminated at any time during its execution, insert (. statement at the point of termination as to reason and the g L title of subsequent procedure. Insert N/A in all remainding l blanks, date, time, and sign last page. Retain terminated l procedure in startup package.
l l 7. Operation during heatup or cooldown, with the reactor critical (except during low power physics testing), shall be conducted only when vessel temperature is equal -to or above that shown in curve B and curve C of Figure 3.6-1 of the Technica' Specifications. (TS) l D. PROCEDURE Initial
- l. If the Recirt flow controller is in EGC oc HASTER-AUTO I mode, place the controller in the MASTER-HiNUAL mode. #h 1
- 2. Verify that the RWH is operable and' blocks are enabled l to 100% power. @d..
l l APPROVED g (MR 161990 1/0012h L Q.C.O.S.R.
A if o ?@ Y
%q>
9 "gQs Q3 IMAGE EVALUATION
'kg o.
,Cd+
S <<'
\) g// 1 [ (' % fB TEST TARGET (MT-3) /({(p
\ khl' II 3 ~
{
+ <e Ib O!!!M l,j 5
b
@b- o ph m
=
ll11 1.8 kil== -3 1.25 1.4 11!! i . 6 ___ p +,.
- 150mm >
4 6" - hi % +
+ /Ao 4>A,gy , $jj>Szzzz
,, eggg/4
, /, t:
l'. y
-. . .. - _ _ _ _ _ _ - - _ _ _ _ _ .- - li
QGP 2-1 Revision 34
- 3. Reduce power with the Master Rocirc flow controller and/or l O by inserting rods per QGP 4-1 and observe the following:
- a. Power re;sction rate shall be in accordance -
with the most recent operating and/or Nuclear Engineer's recommendations under NORMAL and emergency conditions,
- b. Ccntinuously monitor power decrease on APRHS.
- c. Maintain Load Set 10% above Generator load. /4
- d. On 901-5(902-5), maintain the EGC settings in accordance with QOP 5670-1. F4
- e. Continue to reduce Rectre flow until the I" b#' M " " I l Master Controller reaches minimum speed (45%). then place the Recirc flow controllers in the d
I LOCAL-HANUAL mode in accordance with QOP 202-3. _
- f. Continue reducing Recirc flow until total core l flow is approximately 45 Mlb/hr. Maintain the Recirc pumps at approximately equal speeds. l (SIL 380, rev.1) 4-
- 4. As Condensate Demineralizer differential pressure
/* \
approaches 15 psid, isolate units one at a time to maintain greater than 1500 gpm flow through the p a 'tralizer. O
- 5. Continue inserting Control Rods in proper scauence using QGP 4-1 until the TURB PRESS G&N LOAD REJ SIM VLV BYPASS alarm first annunciates (approximately 42% power). Then reduce Recirc flow to minimum with the Dotentiometer j on the Recirc pump speed controllers. Continue to insert control rods. If the rod worth minimizer mode switch is in NORMAL, verify proper tracking of rod motion. /i _,
6, At 40% reactor power CLOSE the Feedwater Regulator valve l that is in MANUAL in accordance with QOP 600-8.
- 7) ,
NOTE b If feedwater instabilities occur, use OPEN Feedwater Regulator valve that 's in MANUAL until the feedwater systeu returns to a stable state. 1 O A." PROVED v
!aR 161990 1/0012h O.C.O.S.R. ;
1 QGP 2-1 Revision 34 7, At approximately 4 x 106 lbs/hr feedo ter f Ww and 150 amps on the condensate pumps, 570,5 a RFF in accordance with QOP 3200-5 and then STOP a Condensate pump as follows:
- a. Verify that RFP suction pressure is greater than # l 350 psig. M
- b. Place the "Indby Condensate pL'O selector switch ,4 to 0FF. <<,
- c. STOP a Condensate pump. /b
- d. Select the tripped Condensate pump for STANDBY //7 operations. /M C.AUTIQN As power is furthe- decreased below
! 200 MHe, leave at least three Condensate Demins on. If the Condensate pump amps fall below l 150 amps, open the RFP Recirc valves and/or the 3401 Condensate Rectre FCV to increase amps to 150 amps, i
- 8. At 200 MHe open the feedwater Heater Extraction Orain #
l valves, r/
- 9. At-approximately 2 x 106 lbm/hr Feodwater flow:
4
- a. Observe that the Recirc loop A and 8 flow /g j limit alarms annunciatt.
CAUTION l The PHM may only be bypassed by I using QOP 207-2.
- b. Verify the RWH screen displays "8ELOH 207. POWER" and
" BLOCKS ENABLED," the screen shows no unacknowledged errors .and the control rod positions are in accordance with the RHM sequence. If the RHM is inoperable, a verifier is required for rod movement. /j.7.
- c. If the RHH is inoperable, an independent verifier is required for rod movement. Enter the verifie:'s I
name. A/N verifier
- 10. Insert the IRM detectors in accordance with 00P 700-2. A AIPROVED 1/0012h 4- W 1 6 1990 C.C.O.S.R.
l
QGP 2-1 Revision 34
, ,\
11, Tech Spec Tables 4.1.2 and 4.2.1 require the following ( surveillances be performed during controlled shutdowns k unless performed within the preceding 7 days.
- a. Operating Deoartment snall perform 00S 700-5, IRM High Flur (005 700-5) must be done at approximately 207 reactor power, n,f- gew It' </)
+c S -l -
- b. Instrument Maintenance Department shall perform Prior to Shutdown surveillance for SRMs and IRMs. /D
- 12. START the Turbine Bearing Lift pumps, run for 10 minutes #
to cneck croper operation then STOP them. /7 CAUTION Do not start the turning gear inotor during the performance of the next step.
- 13. Dispatch an operator to the Turbine oil reservoir and test the auto start of:
- a. Emergency Bearing 011 Pump (EBOP) N /7
- b. Motor Suction Pump (MSP). "
[f/ ; 4 t c. Turning Gear Oil Pump (TGOP). M l 14. Transfer auxillary power from TR 11(21) to TR 12(22) as i follows: CAUTION Do not allow buses to be in parallel any longer than necessary,
- a. Turn the synchroscope switch ON for TR 12(22) to ..
Bus 11(21) breaker.
- b. Check that TR 11 (21) and TR 12 (22) are o synchronized and the voltages are equal. [C cal' TION Failure to trip the breaker immediately may result in a trip of both breakers
- from high circulating current,
- c. CLOSE TR 12(22) to Bus 11(21) breaker.
! (1) Check for breaker closed indication. (2) Check for parallel feed alarm, 1/0012h fEt161990 l .C.O.S.R.
QGP 2-1 Revision 34 APPROVE ~ g NAR I 6199 d ,- OPEN TR 11(21) to Bus 11(21) breaker. /$ QC. (1) Check for breaker open Indication. (2) Reset parallel feed alarm,
- e. Turn the synchroscope switch 0FF for TR 12(22) to Bus 11(21).
- f. Turn the synchroscope swit*.h ON for TR 12(22) to Bus 14(24). M'" ,
- g. Check that TR 11 (21) and 12 (22) are synchronized and the voltages are equal, s CAUTION Failure to trip the breaker immediately may result in a trip of both breakers fmm high circulating current.
- h. CLOSE TR 12(22) to Bus 14(24) breaker. /
(1) Check for breaker closed indication. (2) Check for parallel feed alarm,
- i. OPEN TR 11(21) to Bus 14(24) breaker. /
(1) Check for breaker open indication. (2) Reset parallel feed alarm.
- j. Turn the synchroscope switch 0FF for TR 12(22) to d Bus 14(24). O
- 15. Continue inserting Control Rods in the selected rod f' sequence. /9
- 16. When the feedwater Master Level Controller output approaches a zero signal transfer Level Control to the Low flow Control valve-In accordance with 00P 600-5. / fpy
/
- 17. Request permission from.the Load Dispatcher to separate the Generator from the grid. Mi l
- 18. STOP insprtW Control Rods when Generator output is betweerr (50 p and 150 MWe as determined by the Shift s Engineer or Operating Engineer. /'7 1
- 19. Place the Turbine Supervisory instruments on HI speed ,r-l and Turbine rpm T-146(T-246) on trend if desired. l
- a. Verify that the Bypass Valve Opening Jack green CLOSED light is on at panel 901-7(902-7), and the fy 9i indicator reads :ero, //_ !
1/0012h QGP 2-1 Revision 34 AFPROVED OL NOTE-Ouring the performance of the next steps if the OCBS do not trip within 30 seconds after. reaching zero output,- manually TRIP the Generator. The Generator Trip button also trips Stator Cooling Water pumps. RESET the 86 relay in the Aux Electrical Room to start the Stator Cooling Water pump.
- 20. With the Load Set reduce Generator output to 10 MWe and establish VARs at zero. D,,' -
21, TRIP the Turbine with the Remote Trip Button and verify the following:
- a. All Stop and Control valves close.
- b. All-Intercept valves close. ## '
- c. The Extraction Check valves close and the A0 Extraction Bypass valves open. 4-
- d. Generator OCBs' auto trip after 30 seconds time delay. /b h CAUTION Opening the vacuum breaker at high rpms (1200) imposes excessive loads on the Turbine last :tage buckets. Do not open the vacuum breaker unless it is necessary to quickly reduce Turbine rpm and then do not lower vacuum below 25-inches of'Hg (no greater than
.5 inches of Hg back pressure).
- 22. Perform Turbine overspeed test (s) if required. /
-23. Notify the Load Olspatcher that the-Turbine is tripped and receive orders to-OPEN the Unit disconnects and reclose the 345 KV ring bus. Notify the Equipment
_ Operator-before closing the 345 KV OCBs. I1 2 4. - Monitor Turbine vibration and-if vibration is excessive through.the critical. speed range (1200 rpm) open the - vacuum' breaker, then CLOSE it when the turbine is past - the:ctltical: speed.
-l I.
- 25. .-Verify the Motor Suction Pump (MSP) and the Turning
-Gear Oil Pump (TGOP) automatically start as Turbine /
lube oil pressure decreases to 20 psig. 'f 1/0012h -
QGP 2-1 Revision 34 APPROVEC IAAR 161990
- 26. START the Turbine Bearing Lift pumps before the Turbine comes to rest, but not before Turbine speed Q.C.
is less than 800 rpm. f f'
- 27. Verify the turning gear motor starts and the Turnin~
Gear engages as the Turbine comes to rest. o /U
- 28. Set the Turbine Oil Cooler outlet temperature at 90'F.
- 29. Press tra vant pushbutton ' the local Hydrogen panel to place the Hydrogen syst in a vent status. Set the rotometer flow at I scfh, t regulatirig with valve G-27. v U
hut
- 30. OPEN the Above Below Seat Drains valves.p m a k 4 / 4, l
- 31. Verify that alarm H-9 GEN EXCITER FIELD CRKR OPEN, on panel 901-8(902-8) is energized. /1
- 32. If Hain Condenser is available as a heat sink and Reactor is to be depressurized OPEN main steam line drain valves HO-220-1, H0-220-2. HO-220-3. OPEN HO-220-4 when Reactor pressure is below 100 psig. - l
/ '33. f it is desired to continue the shutdown with normal
)controlrodinsertionsskipthisstepandgotostep0.34.
Otherwise;
- a. Put mode switch to SHUT 00HN.
- b. Refer to QGP 2-3; Reactor Scram. #
f
- c. Continue with this same QGP 2-1 as stated in step 0.26 V of QGP 2-3. /5 ffy 34 Insert Control Rods in the selected sequence. $/ 6 CAUTION It may be necessary to carefully move the mode switch to the one o' clock position to assure the scram bypass relays are energized. This step must be completed before Reactor pressure reaches 850 psig.
- 35. When Reactor power is between 5% and 10% transfer the Reactor mode switch to STARTUP as follows;
- a. Verify that the APRMs indicate between 4% and 12%
on both 901-5(902-5) and 901-37(902-37). /M
- b. Verify that the IRMs are on scale in accordance witn 00P 700-2. /g 1/0012h -
QGP 2-1 Revision 34 s
- c. Transfer the mode switch'to STARTUP. //d d.- Sw' itch the IRM-to record. O e.
VerifythefollowingrelaysareenergizMed. 590-112A, B, C, and 0.- pub enuw( /M ~
- f. If not previously done per QGP 2-3, form the following:
(1) Start Sparge Air to the Recombiner in 4 accordance with 00P 5400-8. k/ (2) Place the adsorber MODE switch in 8YPASS on - 901-54(902-54). ._ NOTE For the'B train of Unit One Off-Gas system, skip steps 0.35.f.(3' and 6 tWA 0.35.f.(4). (3) OPEN the recomi'ner bypass VALVE 5499-718. II./I (4) CLOSE the recombiner inlet VALVE- 5499-75/76. MN
- g. Continue Off-Gas system shutdown in accordance with 00P 5400-2. [2 NOTE-In step 0.36.,'If-the strip. chart fails, computer trending can be used to monitor the following temperatures. However, to avoid
-reaching the process computer's " low reasonable level". Instrument
- Maintenance sMuld be-' contacted to install a multimeter to monttor the
; resistance directly-from the RTO inputs to the computer. The resistance: reading:can'be graphed to correspond to a temperature.
;36. The following temperatures mu'st be-recor_ded during cooldown. If-any one of these strip charts fail, graph _
that. temperature at 15 minute _ intervals and send the graph to the Technical Staff Supervisor.
- a. Reactor vessel shell.
b, Reactor vessel flange. APPROVED lAAR 161990 1/0012h _- . _- . _ . - _ . -
l CGP 2-1 Revision 34 AT'PR O VE NAR 16199i
- c. A Recirc loop.
Ig ng d*JD I k-Q.C.
- c. B Recirc loop.
v' \
- 37. Fully insert all Control Rods in telected sequence. l
- a. Range the IRM range switches in accordance wIth QOP 700-2 M
- b. Insert the SRM detectors in accordance with QOP 700-1. M
- 38. When all Control Rods are inserted, verify that the RHH was operable from 20% power to all-rods-In.
',4 If the RHH was inoperable, supply the name of the person who verified control rod movements.
Verifter
- 39. When all control rods are inserted place the mode switch to SHUTDOHN and RESET the scram. The SDV high water level bypass switch will have to be placed in BYPASS to reset the scram and drain the 50V.
NOTE g The Inode switch may be placed in REFUEL to allow troubleshooting or surveillance testing.
- 40. ODserve the following cooldown limits;
- a. Reactor cooldown at less than 100*F per hour,
- b. Reactor vessel flange to shell differential temperature less than 140*F.
- c. Maintain Reactor water level between +20 and
+40 inches to prevent relatively cool water l from contacting the hot upper area of the vessel shell.
- 41. START pressure reduction by opening No. I Bypass valve slightly (10% to 15% on valve indication) with the bypass valve opening jack. Adjust Bypass valve position as necessary to maintain cooldown rate. Follow pressure reduction with the Pressure Regulator. Maintain the Pressure Regulator approximately 50 psig above Reactor /
pressure. O, (
- 42. Observe that the Channel A and B Hain Steam Line Low Pressure alarm annunctates at approximately 825 0519 7[-
l 1/0012h MP 2-1 Revision 34 W- 43. 'If--the MSIVs are to be Local Leak: Rate tested, at 400 psig: V: Reactor pressure, CLOSE the HSIVs on main Steam lines A, B, and C as follows. - 00 NOT CLOSE the O steam line valves. Close each valve-individually. a, CLOSE A0-203-2A. /7
- b. CLOSE A0-203-1A. /
- c. CLOSE A0-203-2B. dh
- d. CLOSE A0-203-18. k
-e. CLOSE A0-203-2C. --
- f. CLOSE A0-203-lC.
-44. Approximately 300 psig STOP the remaining RFP.in ,
accordance with QOP 3200-5 then STOP a Condensate l
-pump as follows: ,4
- a. ' Place Condensate pump select switch in OFF. A
- b. STOP the Cont.ensate pump. N
- c. ' Select the tripped condensate pump to STANDBY. M>
0- 45. At a Reactor pressure of less than 100 psig perform the following:
- a. OPEN the Gland Steam Seal bypass valve as necessary-to maintain Gland Steam Seal pressure
at 4.0 psig. O"
- b. CLOSE power supply to MO-1001-47, RHR SDC suction outboard isolation valve, at -l 250 VDC Reactor Building MCC 1B(28).- /-
compartment 502 (502) (10CFR50 Appendix R). 7
- 46. When Reactor water temperature is below 350*F place the SDC mode of-RHR in operation in gccordance with QOP 1000 -5. %
~
l NOTE Honitor that the RHCU pump discharge l' temperature is below 273'F. Check for erraticLIndications that would signa 1 - _ pump cavitation'. If this occurs, i change over RHCU-system valves as per l l l 00P 1200-12. APPROVED 1/0012h -il- - ! bb Q.C.O.S.R.
QGP 2-1 Revision 34
- 47. If the HSIVs are to be Local Leak Rate tested, at 50 psig I reactor pressure, CLOSE the D main steam line HSIVs as follows. Close each valve individually, h
- a. CLOSE A0-203-20. W
- b. CLOSE A0-203-lD. v (1
- c. OPEN @ 220-1, HO-220-2, HO-220-3, H0-220-4. N0
- 48. As Feedwater flow to the Reactor decreases verify a Condensate pump recirculation flow path is available .
and pump amps are maintained greater than 150 amps. y
- 49. Maintain condenser vacuum until SDC-15 operating ,f7 proper 1y. t c l
- 50. When it is no longer possible to maintain steam seal pressure, OPEN Condenser vacuum breaker to break vacuum. CLOSE the vacuum breaker just before vacuum reaches zero. Run the gland exhauster to bleed off A remaining vacuum. / '/ _
- 51. CLOSE the main steam byr, ass valves and steam ce41 isolation and bypass valves. [9 1
- 52. If required, CLOSE the HSIVs and make the following valve lineup:
- a. H0 220-90A, B, C and 0 CLOSED. /d
- b. H0 220-1, MO 220-2, MO 220-4 OPEN. /UN
- c. HO 220-3 OPEN. #b
- 53. Shutdown the Gland Steam Seal in accordance with .
l QOP 5600-1,
- 54. OPEN Reactor Head Vent when temperature is below 190*F. /'I l
- 55. After the Reactor Head Vents are OPEN (and the HSIVs are CLOSED) verify the following valve line-up: l
- a. HO-220-90A, B, C, and 0 CLOSED.
fs
- b. HO-220-1, H0-220-2, H0-220-4 CLOSED. M
- c. H0-220-3 OPEN.
l APPROVED , f4AR 161990 l i/0012h O.C.O.S.R. l 1 l l
OGP 2-1 Revision 34 eg 56. Notify Chemistry to sample and analyze l Q radioactive gaseous waste (Tech Spec Table 4.8-1). Foreman Notified _ Od / Time
- 57. Continue cooldown to 125'F (or higher if required). d'
- 58. The vessel shell temperature immediately below the vessel flange must be maintained greater than 100*F /
until the reactor vessel head studs are detensioned. (TS) /'M
} .n Unit dhu uI dv Reviewed / [re 4' /
NSn En'TFneer J
) \]
Date/ Time cR ?) /{lO v' $0 Reviewed /V/Y^ Completed / ~~ (Operator) l l l l l l O V APPROVED (final)
- /coi28 _i3 f4AR 161990 Q.C.O.S.R.
1
Simulator OMB O/WS Test Procedure Cover Sheet Test Number de2-f T' PTAO-105T1 Date Performed 2-/6'-)/ Test . Description Spy 7_,,,,y pp{m p.sa,gg stepp7yng po p :s~rggogy go T f t' t s s u 2 / 2. E D ConD/7/od Discrepancies section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date Test Results
- 1. Test Completed Satisfactorily G
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after-correction of above discrepancies.
Retest Complete Date Test Complete ,b .n // dn /w Date 3,/f/// SFCC Acceptance _ Date 3 P 7 / Simulator Supervisor' Acce tance h Date JEi/ c.c.co. es.n n n ee
q F APPROVED OAP 1100-T6 E3IN TEMPORAR'. ~ 4 NGE TO PERMANENT PROCEDURE Revision 14 REQUEST / 't.MPORARY PROCEDURE REQUEST December 1990 r- Q.C.O.S.R. s.,a .s.y c.,,P. ~ % v.m s..es (;j TITLE ~ ~ % _.;,,e G /. m . fEMPORARY CHANGE NUMBER b > 5q PROCEDURE / BLOCK AFFECTED: k l' U I- 4 T. C. SUPERSEDED
. , Reaue" terminates 30 days from approval date.
CHANGE REQUESTED.- & n lole % sr -- REASON FOR CHANCE: NEW SUPPLEMENT ' REPLACEMENT ALTERNATIVE QAP 1100-T14, Temporary Change Notice Sheets have been prepared for existing procedures and will be distributed to the appropriate manual holders. (NRC Inspection Report 254/88015 and 265/88015) ' ORIGINATOR M a ie s DATE REQUESTED /- ?i4 t Autnort2ed copies held Dy: Permanent Procedure Cnange heeded? h Original-Tech Staff Supv.
- 1. Comm. Ctr.T.C. Log 5. ul m 9.
- 2. Simulator 6. v 2. M i o 10.
- 3. _S Eu 7. Ce .pe M r m e 11.
l 4. SC'RC: 8. A s ru e d e d 12. 1 Obtain the appropriate approvals below in accordance with QAP 1100-7. TM Refer to OAP 1100 71 for the acercoriate sionatures for this reauest. (L '/ c Review and proval: - j O /h' //dA / \ %.M . 0% Nh k-fn
!"'l __,,,0ff h Super ds%r __,,' Technical Supt. Tech 'f Sup'erv sor C Tech Staff Qupv Asst. Supt. Operating
,[ Operating EngFneer [ Asst. Supt. Maintenance /[6 a b . /'
.;sl5 ,_,_, Health Physics Supervisor '
.- ~~~
Chem Supervisor St tion 'Hafger
.C Master Electrician SPECIAL REVIEN Tc
/
/s l'/ / 7 /
$ [MasterInst. Mechanic
,,__ Master Mechanic E0P Ccordinator Phe;/w-$)atet MIR ES C .,,,,,,,Qua l i ty Con t rol Supv . _ GSEP Coordinator t559 MM ()2 jgg)
~
u, Temporary Change tnat does not cnange " Intent" (includes uncnanged renewals). CD LL. SRO _ SRO _ Security Administrctor Master Hechanic Mech. Maint. Foreman Master Inst. Mechanic Instrument Foreman Office Supervisor Chem Supervisor DATE APPROVED Haster Electrician
- Elect. Maint. Foreman
, - . . - - . - . . Tech Staff Supv. Technical Supt,
[U ~M [H.P.Supv. [GSEPCoordinator ON-SITE REVIEW (14 OAYS) ___EOP Coordinator (For QGAs) b555 ._ i (.)i _ Asst. Supt. Operating Tech Staff Supv. Station Manager _,,_ Asst. Supt. Maintenance
,__ Rad-Chem Supervisor Security Administrator (QSP) DATE
~~'~
Technical Supt. ) _ Office Supervisor (final) 2/0039a
n gg , ~.
~
~
r QGP 2-4 ,D UNIT 1(0)- SAFETY RELATED ON HAND TEMPORARY SHUTDOWN FROM P0wER OPERATION TO A STANDBY HOT PRESSURIZE 0 CONDITION _ _ STAT!CN MANAGJR
. APPROVAL SIONATURE TITLE EcFECTIVE OATE l
A. PURP0i{ The purpose of this procedure 15 to provide the steos necessary to shutdown the Unit 1(2) f rom a power-generating mode of operation to a condition of low power with the Reactor pressurl:ed and the MSIVs g.ither OPEN gr CLOSED. B, DISCUSSION Power reduction from 100% Reactor power to 40% power is attained by reduction of recirculation flow and Control Rod insertion, Power reduction l must be in accordance with QGP 3-1. During the transition from the Run to Startup Modes, it is essential to malrtain nuclear instrumentation overlac, Failure to do so could result in a Reactor Scram due tc aipanion APRH/IRH overlap interlock. M C As Reactor power is reduced in :ne IRH range, other factors such as moderator temperature coefficient, xenon burn-up, rapid pressure changes O and cold water injection can rapidly drive the Reactor suberit1 cal or supercritical- as well as increase ind1vidual Control Rod worth. Tne O operator must take into account all of thest factors while in this j: [y] operating range especially if the HSIVs are closed. Depending on the e .J - Quantity of decay heat, reject of Reactor water via the RWCU System e,"4 provides a suff1cient balance between a temperature coeff1cient and Reactor
=.,Cl*., criticality, tir.de r these steady state . conditions, the Reactor will C
g osc111 ate .between critical and subcritical with no ef fective thermal _ power change. l- , u .= i C The point of adding heat to the Reactor is general,9 on IRM range 7_ and i above. Below the point of adding heat, only residual and decay heat will i b= affect Reactor temperature and pressure Therefore continuing to insert ! CD Control Rods below range 7 will-N_QT reduce Reactor pressure. [ W .
,, TEMPORAR1 EXPlRES
~
pnerDJRL gag MAR 021991 (3 O b. ;. 2
' ...M V -
1
t TE*.y>Raov _ r=?~y-- '
~~e p ,,
%- ' NO#g$ UNIT 1(2) Id:R g ;> 39y TEMPORARY If the MSIVs remain open. lMih Reactor pressure control can be maintained v ta tne ENC system (Bypass Nalves), cumping steam to the Main Concenser via steam crains and SJAE's. [E the MSIVs are closed, TtJS Reactor pressure should be redu:e1 to - 600 to 800 os19 Reactor pressure control can be achieved via Control Rod insertion. RCIC and HDCI Systems for large Quantities of decay heat, and the RwCU System L^c "E c ' : for small quantities of decay heat, it must be noted, however, that overloading the RBCCW system v1a the RwCU Non-regenerative Heat Exchangers cetreases Dry. ell cooling, thus Increases Dry ell temperature / pressure which coulc result in-a Reactor Scram / Group 2 Isolation. When inserting Contro' Rods to decrease Reactor oressure after all Bypass Vahes have closed, sufficient time should be allowed between subsecuent Control Rod maneuvers to allow for Reactor pressure and power to stabill:e. If sufficient time is N2T allowed, power may decrease significantly suberitical. In this condition changes in Reactor pressure will be cue to ' heat losses to ambient and NQT negative raactivity insertion. This will reovire Control Rod witnora.al to bring the Reactor crit 1 cal and raise power to the point of adding heat in order to have control over Reactor pressure. If Control Rod movements are performed slowly, it is possible to control [
~
Reactor pressure by inserting or withdrawing fewer Control Rods to compensate for Reactor moderator temperature and Xenon to centrol Reactor pressure. C. RE ERENCES j3I? 1 Technical Specifications Table 4.1.2, Scram Instrument Calioration. Cl. C;C) . 2, Technical Spec 1fications Table 4.2.1, H1nimum Test and Cal 1bration Frequency for Core and Containment Cooling Systems Instrumentation, CE Rod Blocks, and Isolation. O
*. f"3 3. Technical Specifications, 3.6.A/4.6.A. Thermal L1mitations.
C13
}"
4 Technical Spec 1f1 cations, 3.6.C/4.6.C. Coolant Chemistry. L C"> 5, QAP 300-10, Operating Records. M. C- 6. OCP 000-3, Reactor Water Chemistry T%T9fAM
~' Nt EXPIRES
==
Lu. 7. QGP 3-1, Power Changes. ;;c9 MAR 0 21991 O LWb= 8. QGP 4-1, Control Rod Novements and Control Rod Seouences.
- 9. QIS 41-1, Prior to Standby / Shutdown Instrument Calibration Check and
,, Functional Test.
\s / 10. QOP 207-2, Rod Wortn M1n1mtzer Bypass Control.
- 11. QOP 600-5, Removing the Main Feedwater Regulator from Service and Placing Level Control onto the Low Flow Control Valve.
l
F T P,':C W . . 3 QGP 2-J f V] , , . , , . O ? ? '1 # a. c2:30{ UNIT 1(2) TEMPORARY 12, 00P 600-8, Removing One of Two Feecnater Regulator Valves f rom Serv 1:e.
- 13. 00P 700-1, Source Range Monitor Operation (SRM).
14 00P 700-2, Intermeciate Range Monitoring Operation (IRM).
- 15. 00P 1000-9, Torus Cooling.
- 16. 00P 1200-7, Reactor water Clean-Up System Cuolant Rejection.
17 OCOP 1300-2, RCIC System Manual Startup (Injection / Pressure Control). -
- 18. 0000 2300-6, HDCI System Manual Startuo (Injection / Pressure Control).
- 19. 00P-3200-5, Reactor Feed Pump Shutcown.
- 20. 00P 5400-2, Off-Gas System Shutcown.
- 21. 00P 5400-5, Glycol System Shutdown.
l
- 22. QOP 5400-8, Starting Sparging Air to the Recombiner.
D QOP 5400-9, Isolating Sparger Air to the Recombiner, [d 23. 24 00P 5500-2, Removing a Condensate Deminerall:er From Service.
--- 25. COP 5600-1, Gland Seal System.
W. C 26. 005 250-1 MSIV Closure Monthly Scram Sensor Functional Test.
- 27. QOS 700-5, IRM Detector High Flux Comparison to APRHS After Heat
.3
.s Balance Check.
G 28. QOS 5600-6, Turbine Generator Annual Test: Turbine Generator Overspeed Test. c Q 29. 00S 5600-7, Turbine Generator Annual Test: Turbine Generator Back-uo
% Overspeed Test.
D
- 30. SIL 380 Rev. 1, BWR Core Thermal Hydraulic Stability.
L
- 31. OCNPS Procedure Writers Gulde, Revision 1, dated 1-31-90.
D. PREREQUISITES
- 1. Permission has been obtained from the !.cac Dispatcher to shutcown Unit 1(2).
[7
\
- 2. Rod worth Minim 12er is operational QR a Qu?11fiec person is available to verify roc movements in accordance with rod sequence PRIOR to l
Reactor oower reacning 20s. m*PURAR1 rpr EDUR t. EXPIRES 6559 MAR 02 t991 3
r T E Y C C O .* h' . 1. 9eq ' 000 2-4 O V-6 ') ? 9 L UNIT 1(2) e2 931 TEwp0RARY
- 3. 00S 250-1, MSIV Closure Monthly Scram Sensor Functional Test has been perfo med.
- a. if NQ work 1s to be performed in MSIV Room or Dry ell, en Operating Engineer may maive/ the test.
(1) Test waived yes /no ' (2) Author 1:ed by: (Operating Engineer) (3) Date: Time: E. DCECAUTIONS 1 The point of adding heat to the Reactor is generally on IRM range 7 and above. Selow the point of adding heat, only residual and decay neat will affect Reactor temperature and pressure.
- 2. Opening the Turbine vacuum Breaker at high rpm (ie, greater than 1200 rpm) 1mposes excessive loads on the turbine LP Rotor last stage buckets.
t N- 3. The Main Turbine LP Rotor Critical speed of Unit 1 1s approximately 1000 rpm (Unit 2 1s approximately 1100 rpm). Prolonged operation at critical speed should be minim 1:ed. 4 While transferring auxiliary 'oads, failure to trip o_n_g 4KV breaker
,,M,,,,, immediately with both supply breakers CLOSED to a 4KV Bus may result
.c in a tr1p of both breakers due to high circulating currents.
C.b
- 5. Alarm 901(2)-8 H-9, GEN EXCITER BRKR OPEN ind1 cates that the Generator C Exciter field breaker is opened. Failure of the Exciter field breaker
. .C. 3 to open will cause damage to Generator Exciter / Exciter Field Breaker.
+=J (9llg 6. While placing Main Generator hydrogen analyzer in VENT status, care g must be exercised when adjusting 1(2)-G-23, U-1(2) GEN GAS ANALY2ER
& FILT ORYER FCV and 1(2)-G-27, U-1(2) VENT BLEED LINE SV to prevent over y pressurizing Gas Analyzer 1(2) GFL-1 due to a 60 psid between the
% generator casing pressure and atmosphere.
C
""",,, 7. During Reactor operation when just crit' cal or just suber1t1 cal, the a,, following parameters w111 have a sositive reactivity affect and can Cll3 cause the Reactor to go critical or inct.ase the Reactor period:
4
- 8. Xenon decay,
- b. Decreas1ng F3 actor water temperature.
( c. Increasing Reactor pressure, q.- .uay gypjpgg
<s.
I d. Addition of cold water to the Reactor. 5559 MAR 021991 a
W 'cC ,...,n-3 QGP 2-4 UNIT 1(2) t; ,- TEMPORARY
- 8. As Xenon reaches its peak (4-11 hours), relative neutron flux increases in arees e of lo er power prior to the power recuction (eore top and periphery) and can increase the notch worth of Control Rods in tt'ese areas.
- 9. Careful attention must be given to all Nuclear Instrumentation during Reactor reactivity changes by insertion and w1thdrawal of Control Rods.
- 10. All Control Rod movements should be performed in accorcance alth QGP 4-1 and with the concurrence of the QualifiedOngineer, except under emergency conditions, theae 11 Opening or closing of Main Turbine Bypass Valves can change Reactor reactivity. All Turbine Bypass Valve p>sition changes should be rerformed in small increments while closely monitoring Nuclear 1strumentation.
12, 4 f IRMs are at the high end of scale during a 8'1 activity change caused by Reactor pressure changes, a Reactor Scr . may be experienced.
.h. 13. Excessive re,)ect of Reactor water can overload thc RBCCW System via
% the RWCU non-regenative heat exchangers and cause an increase in Drywell Cooler temperature resulting in eigh Oryweil pressure cf Scram / Group 2 Isolation.
D Q 14, When moving the REACTOR MODE SELECT to $TARTUP/ HOT STANDBY position, D q REACTOR N00E SELECT should tLQT be moved back and forth in the STARTUP/ HOT STANDBY to ensure proper transfer of contacts. This may r result in a Reactor Scram. It is preferred that if the mode switch does N N;LT transfer that the REACTOR HODE SELECT switch be placed in REFUEt position and then moved back to STARTUP/ HOT STANDBY po31 tion.
%],,
- 15. WWEN Reactor 1s inHotj y mode with MSIV's closed, THEN di Control Rod withdrawals -
be lim 1ted to qng notch withdrawal ( operation to ensure minimum amount of reactivity addition at any one C3 point of time to help prevent unexpected critical 1tles and/or fast k Reactor periods. F. LIMITATION AND ACTION 1 II 1n 30 seconds from the time the Main Turbine is manually tr1pped, 345 KV OCBs CKT BKR 6-7 (1-11) an_Q CKT BKR 7-8 ('0-11) do NQT tr1p, _ THEN the Main Generator my11 be manually tripped.
- 2. Jf it is necessary to rapidly reduce turbine speed by opening vacuum breakers, THEN do N_(LT lower condenser vacuum below 25 incnes Hg (N) _
greater than 5 inches Hg back pressure). O ttvoorM mae EXPIRES 6559 MAR 021991
l l l n QGP 2-4
\
UNIT 1(',) TEMPORARY
- 3. E either of the following conditions exist, LHff the Tureine Vacuum Breaker should be opened to decelerate Main Turo1ne:
- a. Turbine vibration reaches 12 mils,
- b. A step increase or rap 10 r1se in vibration is 00 served below 12 mils, 4, During heatups and cooldowns the following temperatures snall be permanently recorded at 15 minute intervals per QAP 300-10, Operating Records.
- a, Reactor vessel snell,
- b. Reactor vessel shell flange.
(. . Reactor Recirculation loops A and B,
- 5. At all times, the shell to shell flange differential temperature shall N_QT exceed 140'F,
. 6. During startups and at steaming races below 100,000 lb/hr, a sample
'y% of Reactor coolant shall be takel every 4 hours and analyzed for pg conduct 1v1ty and chloride content, p 7. E the MSIV/MSL drain line valves a'e to be closed QS equipment / systems
( -j being taken off line, THEN a walt 1ng period of a few minutes is g necessary between each valve pressure / temperature to stabilize, movement to allow Reactor A' I. D 6. E during the execution of this procedure, Reactor power / pressure b control is lost. THEN the Reactor g be manually scrarrened.
% 9, g,,l. LE NSIVs are to be closed, TJJM Reactor pressure should be-aecreased
*a to 600 to 800 pstg.
b
-Q 10. E a 20% thermal power :hange occurs within om hour, TWEN Reactor
-Q ccalant/ gaseous samples shall be taken and analyzed, bu rne. Chemdry Department. ~ *
- 11. WHEN Reactor is below 10% power, THEN anytime Control Rods are manipulated, the NSO aM E N E che. b; y cunaLoo; u.w o n u i. e.
Shall norfg the SCRE prior Yo eac,h ed movenicat. TEMDCC'C7
- me - ve- vg TEMPORARY e r,W r)U RE EXPIRES O
U 6E59 ~u - 9 MAR 021991 s
s CCP 2-4 O UNIT 1(2) d TEMPORARY
- 12. If this pro:ecure is terminatec prlpr to full completion TjB -
- a. 'nsgr1 a statement at the point of termination as to reason for termination,
- b. Jflg.r1 title and numDer of subsecuent procedure,
- c. 12Lged N/A in all remaining:
(1) Blanks. (2) Dates. (3) Times. l
- d. $Jan last page.
l
- e. Retain terminated procedure in appropriate Start-up or Shutcown l Package, j G. PROCEQ M O LNLTLALS
~%
- 1. Perform Reactor power decrease per QGD 3-1. f[4 f/// 3 &!df c g >f ?w rT f Continue to reduce Reactor power by inserting
/{
2. Q Control Rods per QGP 4-1.
.;/ig/)f C 3. MiB Condensate Domin cifferential pressure C approaches 15 psid on 1(2)-3340-01, COND DEMIN DP,
*g ' THEN ,uolate gng dem1neralizer at a time to q maintain gr5ater than 1500 gpm through each g' cemineraliger per 00P 5500-2. ^[d 2N3 /
g 4 MLG approximately 40% power is achieved, THEN
% Close 1(2)-640-19A/B, 1(2)A/B FEEDWATER NAN / AUTO /
C
=====
CONT STA that 1s in MANUAL per QOP 600-8. M/
. 3.,,, 5. WWEN at approx 1mately 4.0 E06 lbm/hr feedwater Q flow AM 150 amos Condensate Pump motor current as L.A Indicated on 1(2)A/B/C/0, COND PHP CUR, THEN 11gp gng Reactor Feedwater Pump per 00P'3200-5. AM a T DC W T
,- f. fM. 'h. 3_ EXPIRES m._, . . s. q e 5 , ;, .
6559 MAR 02 Bcf1
OGP 2-4 l9 UNIT 1(2) V TEMPORARY I J FJ WHEN shutting down a Concensate Pump, THEN ensure the two remaining Concensate Pumps are fed from different electrical buses. As feedwater flow decreases it may be necessary to open AQ 1(3)-3201A/B/C. 1(2)A/B/C RFP RECIRC VLV and/or A01(2)-3401, COND RECIRC FCV TO CONOSR to maintain Condensate Pumps current greater than 150 amperes and Condensate
- Dem h flow (app. 1500 gpm througn each Concensate Demin.)
I } INITIALF
- 6. As feedwater flow decreases open A0 1(2)-3201A/B/C, 1(2)A/B/C RFP RECIRC VLV and/or A0 1(2)-3 '
COND RECIRC FCV TO CONDSR as necessary to mainteln: ( .h a. Condensate Pumps current greater '( Q than 150 amperes. Ib9 // / Q b. Condensate Demin flow of 1500 gom W through each condensate Dem1n. *^//$ Ne E/l>[Jh/
,Q 'F!f9M f kr,y,24aQ t
So 7. WHEN gng Reactor Feedwater Pump has been stopped, q THEN:
.C
.f,,- a. Verify on 1(2)-3240-73. RFP SUCT HOR PRESS g Reactor Feedwater Pump suet'on 1s greater /
54=== tnan 350 psig. /l//A
*C b. Place COND PHP SELECTOR switch to 0FF.
b, Q c. Stoo on_g Condensate Pump. f i
- d. SeleQt tripped Condensate Pump to STANOBY operation with COND PMP SELECTOR switch, t/
TE*/ o0PA Pv -
. % ;, g ,
t .,"" 9 E S .
.m p t EXPIRES 55Y :. c;p b5b9 MAR 02 y}g) e
e OGP 2-4 TEW'W , 7
- v -. . q g g UNIT 1(2)
TEuPORARY b559 . :. I LhjTI AlJ
- 8. At 3DO W 1mately 30% Reactor power:
- a. Vgrafy RwM A o_r B is operational by verifying the follo ing lights are O_N /
for Re,M in operation; /d (1) READY light. (2)- ON-LINE light. *
- b. If RWV A AN_Q 6 are inoperable, f
/
ELN bygels RWM per QOP 207-2. / /*d7 ,, ggg 0)'f p n g $ (cu) ltv 9, WHEN Convenient, @j)T below 200 MWe, gpeJ ev o ls Qt1,4)d ag; . Feedwater Heater extraction steam crain valves:
- a. H0 1(2)-3107A, 1(2)B1 EXTR ORN VLV, k 2/8.///
i 'i i b. HO '(2)-3107B, 1(2)B2 EXTR ORN VLV.
- c. H0 1(2)-3107C, 1(2)B3 EXTR ORN VLV.
- d. H0 1(2)-3106A, 1(2)C1 EXTR ORN VLV.
- e. HO 1(2)-3106B, 1(2)C2 EXTR ORN VLV.
D
.g f. MO 1(2)-3106C, 1(?)C3 EXTR ORN VLV. _
%(ty 9.- MO 1(2)-3104A, 1(2)01 EXTR ORN VLV (TURB).
- h. HO 1(2)-31048, 1(2)D2 EXTR ORN VLV (TURB).
- 1. HO 1(2)-3104C, 1(2)D3 EXTR ORN VLV-(TURB),
j, HQ 1(2)-3105A, 1(2)01 EXTR ORN VLV (HTR). I k k. H0 1(2)-3105B, 1(2)D2 EXTR ORN VLV (HTR). 1 Ho 1(2)-31050, 1(2)D3 EXTR ORN VLV (HTR), M g g Open Feedwater Heater vent valves: W SD
- 10. (r g i 8. Ho 1(2)-3610A, 1(2)A1 ORN CLR S/U VENT VLV. / ce t
- b. HO 1(2)-3611A, 1(2)A1 S/U VENT VLV.
/,
y g c.- MO 1(2)-36100, 1(2)A2 ORN CLR S/U VENT VLV.
- d. MO 1(2)-36118, 1(2)A2 S/U VENT VLV. k~ }
- e. 40 1(2)-3610C, 1(2)A3 ORN CLR S/U VENT VLV.
l-w
4 a, a 2.-. - . - . . . . _ , ;...~... QGD 2-4
/
-2 <-
UNIT 1(2)
- TEMPORARY L
bb: INITIALS
- f. MO 1(2)-36110, 1(2)A3 S/U VENT VLV. d !
9 43 1(2)-3606A, 1(2)B1 S/U BYP VENT VLV.
- h. 43 1(2)-3606A, 1(2)B1 S/U VENT VLV.
I I
- 1. MO 1(2)-3606B, 1(2)B2 S/U SYP VENT VLV.
l l
]. HO 1(2)-3606B, 1(2)B2 S/U VENT VLV. !
I
- k. MO 1(2)-3605C, 1(2)B3 S/U BYP VENT VLV.
- 1. .M0 1(2)-3606C, 1(2)B3 S/U VENT VLV.
- m. H0 1(2)-3601A, 1(2)C1 S/U BYP VENT VLV.
- n. HO 1(2)-360SA, 1(2)C1 S/U VENT VLV.
l.
- o. 40 1(2)-3601B, 1(2)C2 S/U BYP VENT VLV.
O. MO 1(2)-3608B, 1(2)C2 S/U VENT VLV. Q. HO 1(2)-36010, 1(2)C3 S/U BYP VENT VLV.
- r. H0 1(2)-3608C, 1(2)C3 S/U VENT VLV.
- s. 40 1(2)-3602A, 1(2)D1 CPER BYP VENT VLv.
- t. HO 1(2)-3603A, 1(2)D1 S/U VENT VLV.
- u. MO 1(2)-3602B, 1(2)D2 OPER BYP VENT VLV.
%w
- v. H0 1(2)-3603B, 1(2)D2 S/U VENT VLV.
b w. =HO 1(2)-3602C, 1(2)D3 OPER BYP VENT VLV. d x. HO 1(2)-3603C, 1(2)03 S/U VENT VLV. Y 11 At approximately 2.0 E06 lbm/hr feedwater flow o_r 20% steam flow: hh g -
- a. Verify Hydrogen Water Chemistry System trips $ $
on Panel 901(2)-63. h!# div[wv5 fI, e
- b. Ver1'
- alarms lit on Panel 90$(2)-4 $h&hb Mlbkt djif f/ g'b '
x O (1)
- tlECIRC LOOP A Flow LIMIT. b[1_ /.g-/ g,75 /j { ;
L 1%yhufm(uh(sQ ' (2) 0-8, RECIRC LOOP B FLOW LIMIT. ,jg,j ,j - l 10 ;
OCP 2-4
\,3/ /
s
' 'r :
UNIT 1(2) TEMPORARV
' ^,
- c. Verify RWM screen displays are lit:
(1) BELOW 20% POWER. [j! 8 Y/ (2) BLOCKS ENABLED. f
- d. A,qknowledge any RWH alarms. _
I
- e. Verify Control Rod positions are in
- accordance with sequence displayed. __,l I'
(1) Verify @ Insert errors. (2) Verify @ withdraw errors,
- f. If RWH 1s Inoperable, T11N an independent ,
ver1fier is required for rod movements: ' (1) Ver1fler's name: d [h 12. WHEN Reactor power is approximately 20%, Tfffy llrwnfh frs tv ,el [(!?'0i rhm.he ' t , ( Insert IRM detectors per QOP 700-2. N.k;J!j/F h g-!g /, s et
/
-[ I
]
NOTE l
.M
;4*
Tecn. Specs Tables 4.1.2 and 4.2.1 reau1re tnat the following tests be performed durina a controlled shutdown ynlesq performed witnin she g( preceding 7 (seven) days.
}
Q C3 ! D 1hIIIALS -l re i 3 13. If the following tests have @T been performed l f* within the preceding 7 (seven) days, THEN: I m 1 r (f) '
%g a. Operations Department shall
'/ Ill &I Q perform 00S 700-5 . h/A 3' Al E C l b b. Instrument Maintenance Department shall / N ce l C3 perform QIS 41-1. lY/A U l Q <
, .S e
l l 14 Start all TURB BRG LIFT PHPS and run for 10 min. 20 b /f/f' sg l
- a. Verify proper operation. I
$2 m w (('
a h,J k {:
- b. Stop aJ TURB BRG LIFT PHPS. f 4
[ca16/J ( p.,j1.<, vee 6)(,;%. l h,u,q cjs s/ g.y
, 9, . i . .
qvfc, or yw DI ' # s
~~<-
,.7,gg 000 ga UNIT 1(2)
[")I -\%- TEMPORARY
. . . ^?1
- r :::::::::::::::::::::
CAUTION Do N.Qi start TURNING GEAR during the performance of the next step. [ ) INITIAL $
- 15. Dnpp_t_q.h an operator to the Main Turbine 011 -
reservoir to perform the following from the oil tank gage panel:
- a. Dush and hold test pushbutton TEST AND SHUTOFF VALVE MAIN PUMP SUCTION until Turb1ne Motor Suction Pump starts, then /
reiease. Rl/h (1) Verify from the Cantrol Room on Panel 901(2)-7 the following has oc.arred for Motor Suction Pump: {~Y
\.) ~
(a) Red ON ' light is lit for TURBINE // MOTOR SUCT PHP,
' J//f/f [
(b) White NORMAL SUCT light is 1.? for TURB!NE MOTOR SUCT PHP. } Q (c) Annunciator 0-7, SHAFT BRG OIL SUCT PUMP AUTO START is lit.
'Ne c' b. Homentarily }gfrn TURBINE MOTOR SUCT PHP to 4g /
%q D
TRIP position. JbL /
~ r//f (1) Verif. from the Control Rcom on Panel
%Q 901(2)-7 the following has occurred for {
Hotor Suction Pump: I b (a) Green OFF light lit for TURBINE D MOTOR SUCT PHP, _ y) . (b) White NORMAL SUCT light is off Ul O for TURBINE HOTOR SUCT PMP. $ { Q. X d[i (c) Annunciator D-7. SHAFT BRG OIL l ce O SUCT PUMP AUTO START clears. I y _ e-(2) Verify control sw1tch for TURBINE MOTOR
/ sy SUCT PHP 1s in AUTO. U @5 cr k' a
@ j~ ..-
k;c. a
.I QGP 2-4 D
[d UNIT 1(2) TEMPORARY I 3 NOTE Turbine Emergency Bearing 011 Pumo will N2 autostart from the test pushbutton 1f the Turning Gear 011 Pump is running with a d1Ccharge pressure greater than 15 ps19 I ] LH1 D K 5
- c. Pyih and hold test pushbutton TEST AND SHUTOFF VALVE D.C. EMER BRG. PUHP until Turbine Emergency Bearing 011 Pump starts, then release.
(1) . Verify from the Control Room on Panel 901(2)-7 the following has occurred for Turbine Emergency Bearing 011 Pump: (a) Red ON light is lit for TURBINE / ' I's EHERG BRG OIL PHP. h4 eC d j/lji! ij ~/
}
(b) White NORMAL PRESS light is lit f0r TURBINE ENERG BRG OIL PHP. (c) Armanciator F-7 ENLRGENCY BRG OIL PUMP AUTO START is lit. k h
- d. Momentarily turn TURBINE EHERGENCY BRG OIL C PHP to TRIP position. r S/7 /
3 O ! g (1) Verify from the Control Room on Panel } g 901(2)-7 the following has occurred for '
.- Turbine Emergency Bear 1ng 011 Pump:
N N (a) Green OFF light Is lit for 6- TURBINE EMERG BRG OIL PHP. (A
~
h L W O (b) White NORMAL PRESS light is off E eq
- for TURBINE EMERG BRG OIL PHP. '
C C
""' i O.
X ce (c) Annunciator F-7, ENERGENCY BRG ! W c:t 3 6 j O OIL PUMP AUTO START clears.
>. w gg,,, !~ xe (2) Verify control switch for TURBINE
,'// g g ch EWERG BRG OIL PHP is-in AUTO. v gw e
/_ sk e
\' j\ ' wE 4 rmpow *'
rmagg 6559 ; , , , ,. , , .2g i 1- .
7g CGP 2-4
- d' UNIT 1(2)
TEMPORARY IN11LuS
- e. Push and hold test pusnDutton TEST AND SHUT 0FF VALVE FOR A.C. T.G. OIL PUMP until Turning Gear 011 Pum; starts, then releast. ,.
(1) Verify from the Control Room on Panel 901(2)-7 the following has occurrea for Turning Gear 011 Pump: (a) Red ON light is 11t for TURNING /
- GEAR OIL PMP. Mf(('/ 'J,/O!
I tb) white NORMAL PRESS light is lit for TURNING GEAR OIL PHP. (c) Annunciator D-9, TURNING GEAR OIL PUMP AUTO START is lit, \/
- f. Homentarily g rn TURNING CEAR OIL PHP to TRIP position,' /
_ M_ f )// ] f-/ (~ 1 ) Verify from the Control Room on Panel 901(2)-7 the following has occurred for Turning Gear Oil Pump: b , (a) Green OFF light is lit for Q TURNING GEAR OIL PHP, C3 (b) White NORMAL PRESS light is off C for TURNING GEAR OIL PHP, Q D (c) Annunciator 0-9, TURNING GEAR OIL ("Q PUMP AUTO START clears, f 6 (2) Verify control switch for TURNING GEAR Q OIL PHP is in AUTO position, kh Q 16. Recuest permission from Rockford Load 01soatcher to transfer auxiliary power from XFMR 11 (21) J (f % b Q to XFMR 12 (22), />
/
-gW)p'
- 17. Transfer auxiliary power from XFMR 11 (21) to XFMR 12 (22) as follows:
( o.$ X , W 4 m TEMPORARY g a j q gc; ce.mm n ( 559 MAR 02 )991 h ," e. Nf E 14
TEV POR A P * '
,,y m m.t. no cap g . .t
-l Uhli 1(2)
(/ ) hj,, ,, TEMPORARY I 3 CAUTI@ Do NQT allaw buses to N in parallel any longer than necessary. [ ]
- Ili!TI AL1
- a. Turn M synchroscope switch for
- XFMR 12 (22) to BUS 11 (21), d,
--e
- b. Verify XFMR 11 (21) and XF4R 12 (22) are: f l
(1) In phase. 1 (2) Voltages are equal. [ } CAUTION rN Failure to tr1D 4KV breaker xFMR 11 (21) TO BUS 11 (21) ACB 1mme galgh with both supply breakers to Bus 11 (21) closed may result in a trip of both breakers due to nign circulating currants. ( ) INITIAL $ M c. Close 4 KV breaker XFMR 12 (22) TO BUS 11 (21) ACB. 7 (1) Ve_rify breaker CLOSE indication. Ci C"J (2) Verify Alarm 901(2)-8 0-2, 4 KV g g
*gj BUS 12 (22) MAIN /RES ACB PARAt.LEL lit. W k
-:n x b
'= d. Open 4 KV breaker XFMR 11 (21) TV BUS 11 (21) ACB.
E~ X e m g c: O y.. l 2 (1) Verifv breaker OPEN indication. , C
"'" * >- w (2) Verify Alarm 901(2)-8 D-2, 4 KV EE y b BUS 12 (22) MAIN /RES ACB PARAt.LEL 9E .; -
CJ"
- Ls.,
resets. ! f- 5 <c n'
'(% e. Turn synchroscope switch to O_ff for ~'
XFMR 12 (22) to BUS 11 (21). I
- f. Turn @ synchroscope switch for XFNR 12 (22) /
to Bus 14 (24). \1 1 + ib
- L8*t*pg t , hhp 2-4 f
~
? " a ' e .;
UNIT 1(2) TEMPORARY Dh* . si 1!illLALS
- g. Verify AFMR 11 (21) and AF64R 12 (22) are:
(1) In phase. (2) Voltages are equal, gL [ ] CAUTtcy - c r ailure to trip 4 KV ureaker xFMR 11 (21) 10 BUS 14 ( 2 4 ) ACB . Lect;311.1,y with both supply breakers to Bus 14 (24) Closed may result in a trip of g both breakers due to high circulating currents. I ] INITIALS
- h. QQH 4 KV breaker XFMR 12 (22) TO BUS 14 (24) ACB. _M.,/cr O '
V (1) Vertfy breaker CLOSE indication. ) (2) ygn.h Alarr 90t(2)-8 B-5, BUS 14 MAIN & RESERVE ACB PARALLEL lit 1 Qp1) 4 kV breaker XFMR 11 (21) TO Q BUS 14 (24) ACB. (1) Verify breaker OPEN indication.
. (2) y3rify Alarm 901(2)-8 B-5, BUS 14 (24) i
%v MAIN & RESERVE ACB PARALLEL resets. I f/)
~
Q
- W h h j. Turn synchroscope switch to Q,F[ for XFMR 12 (22) to Bus 14 (24).
3 Q. m C x o-
- 18. Notify the Rockford Load Dispatcher that transfer W h of auxiliary power from XFMR 11 (21) to b
XFMR 12 (22) 1s complete. /k Ob 2 e
- 19. Continue inserting Control Rods in secuence. ,a ?/7h/
/
- 20. WHEN 1(2)-640-18 Rx LYL MASTER CONTLR output approaches gir.Q. T,H,iES transfer Reactor water O[ #
level control to 1(2)-640-20, FEEDWATER LO Flut [D Q) CONTRL per 00P 600-3. i (( $!
- 21. R.1.19311 permission from Rockford and Chicago Load
. , /
D1spatchers to separate from grid. M//S
/'
16
1 OC p .'- a n u , .s ; UN!i t(2) mg t[wPORARy I ; r. ,
~'
d IMlllRS
- 22. niN Wain Generator output is bet een 150 Mae ana 50 wn e as ceterminec ey t*e Snift Engineer, T M~N
~
.sipy inserting Control Docs, j _
F,qio. ?eTTo;*o Tnt *.ieemc. '
.. x +c ;zt., .s
- a. P1ng 1(2 )-5640-60, ECOENTRICITY AND pj VIBRATION recorder on KIGH speec. M // ,
b, Trt.M turbine speed on Computer Point T-146 (I-246). f n 24 terify that EHC Bypass valve Opening Jack: a, BYP VLV OPENING JACK cemanc indicates Leih
- b. ByP VLV OPENING JACK SELicioR green CLOSED light is QN, 3/ ~
- 25. $3.g!J the f t>11oning pumps:
O'. a. TURE;7NE HOTOR SUCT PWP.
- b. TURNING GEAR O!L PHP, \/
I ) C_AUT ION If in 30 secor.ds f rom the time the Main Turb1ne 1s manually trippoc, 345 KV OCBS CNT BKR 6-7 (1-11) r.g Chi BKR 7-8 (10-11) co NE tr10, THEN tne 3g ( Main Generate m it be manually tripped,
)
n g ::::::::::::::::: n:::::::::::::::::::::::::::::: us:::::::::::::::::::::::: r= I ENns ,2/d'/ IV/f) / . NL O
'y 26. Reagig LOAD SET tp 10 Mwe via LOAD SELECTOR, r l -d ';,..,f s
- 27. Re@st HEGAVARS to terg via M Afd
[5 z-von REa iuto $1rr AoJ tvARS). ,, am a e
% X C
*W f }
t
'j c3 x= n 4 p xx c C ii D
>~
17 e
( .
~
CC* 2-4 UN!T 1: 2)
's . , _
- T[uh0tARv l
l 6: - 1 l LNLI.lfi!
- 28. T. rip Wain Turoine by ceoressing remote fraster ,
TRIP oushoutton anc .>erifv: f,4[/1..
's I
- a. A3 MAIN STOP VLV POSITIONS incicate ag[g. I J
- 0. A] WAIN CONTROL VLV POS!* IONS incicate strg. !
- c. A11 COMBINE 0 INTER STOP VLV POSITIONS incicate ifrg. _,,,i_
- c. All extraction steam check valves c1cse as indicated by alarms on Penel 901(2)-6, HEATER 1(2)x EXTR CHECK VALVE TRIP lit.
- e. AB extraction steam bypass valves open l
on Panel 901(2)-6.
- f. Main Generator OCBs trip open =1tn1n 30 second time celay, on Panel 901(?)-8:
U (1) 345 kV 000 CKT BKR 6-7 (1-11), (2) 345 KV OCB CKT BKR 7-8 (10-11). Y
- 29. If after s 30 second time celay Main Generator !
345 KV OCBs CKT BKR 6-7 (1-11) A_N.p / CKT BKR 7-8 (10-11) fail to apto op.g.0, j h f% Tff!! manually ing Main Generator by cepressing MANUAL TRIP pushbutton, Panel 901(2)-8.
- 30. P_1gt the following 000 C/S's in PULL TO LOCK
,$ a. On Panel 901(2)-8:
%o CJ (1) CKT BKR 6-7 (1-11).
5 (2) CKT BKR 7-8 (10-11). 4' .__ (f) W .
%(*3 b. On Panel 912-2: % N D E C (1) CKT BKR 6-7 (1-11). X %
b W $ O (2) CKT BKR 7-8 (10-11). N v. w
- 31. Monitor Main Turbine vibration on recorcer , 5S &
1(2)-5640-60, ECCENTRICITY ANO VIBRATION, \/ f 3. ~j f') v r,
~'
T' I QGP 2*4 T"" . UNIT 1(2) l '
- x. --
TEMPORARY b5E l' , , ,,-
- iIk::::----------:--------:
[ ] LWTIM Alarm 901(2)-6 W-v, GEN EXCITER BRKR OPEN. Indicates that the Genere*.or Exciter fiele breaker is openec. Failure of the Exciter field creaker to open will cause camage to Generator Exciter / Exciter Fiela Breaker. l [ ] l
- a :::::::::
l!ilTI ALS
- 32. yfr,'y Alarm 901(2)-B W-9 . /
4Ax j. GEN EXCITER BPKR OPEN 1s lit. O- 4 # '# 7^M -: [( [! k iO [
, gj/,
- a. If alarm is .N.2T lit, THEN gnp_algt an operator eculpped with a breaker trip cev1ce to l Alterrex nontrol Cabinet, FIELD BKR SPEC EQUIP
$ECTION Ctbiele by Bus 15 (Bus 25)
(Turbine Lleg. el 611) to manually trip Exciter '<1 eld Breaker, djh', __ ( ) Depressing remote Main Turbine Master TRIP pushbutton also trips Stator Cooling Water Pumps via GENERATOR AUX 86 PRIMARY TRIP Unit 1(2) Relay. Delay must be manually reset 1n order to restart Stator Cooling Water Pumps. [ } LMllLALG
- 33. Restart grte Stator Coollnf, Water Pump as follows:
- a. 01sontch an operator to 901(2)-29 ,/
(Aux Electric Room) to: [/ / h, e e i
%e \ B Q g (1) Ratit GENERATOR AUX 86 PRIMARY TRIP 1 td r Unit 1(2) Relay. _ , _ , @ N a 4
$a, (2) LE GENERATOR AUX 868 BACKUP TRIP Unit f f d @
1(2) Relay tripped, IMEN CA3tt 2 47 GENERATOR AUX 86B BACKUP TRIP Unit 1(2) Relay. :w A 75 @ f D b. Verify Delh Ststor Cooling Pumps O9 C
'a'utomatically start. h; $
(lj r
- c. Verif y white NORMAL PRESS comes M.
19
l
- CGP 2 .1
) UNIT 1(2)
TEMPORARY IMB RS
- d. Lt_;p the previous M?h-runn1rg 1(2)A/B , /
$TATOR CLG PMP, Panel 901(2)-7, _g(?_
34 E turbine overspeed testing is recuirec,
'dLN pe r_[p r,m o v e r s pe e d t e s t i n g be r :
{
- a. 005 5600-5, Turbine Generstor Annual Test: i Turbine Generator 0,erspeed Test.
_i .
- b. 005 5600-7 Turbine Generator Annual Test: ,
Turbine Generator Back-up Overspeec Test. .J
- 35. E turbine overspeed testing is NQJ to be performed, TH_LN perfQr_m the nekt two steps ;
goncurren.11,y curing turb'.ne coastcown. _j_
- 36. Qpen Unit 1(2) manual operated disconnects to 345 KV Ring Bus as follows:
- a. Notify Rockford Load Dispatcher that Unit
, '~)s 1(2) Main Turbine is tripped anc unit 1(2) Main Transformer OCBs are npen,
- b. EtGRail orders from Rockford Load Dispatcher to open Unit 1(2) Main Transformer manually operated disconnects.
- c. 01tpAch Eauipment operator and operating Foreman to 546 KV SW1tchyard,
- d. WH_LN switching orders have been received, THEN:
D (1) Oletti Ecutoment Operator to engn manually operated disconnects. C* (2) Plaqq HOLD W M.[O E necessa/SPECIAL ry. ORDER Card \/ d (*Q @ N l (L C X cr: E =.- d CD Tropagapy W E r.X DI R F'c;
$ h e
cD< -
- r.r.% v . .g) n:
6 p n
"7 e
v
) k h.
O 20
'"'*;^r - , .'. , ~'
_,_* ocp 2 4 UNIT 1(2) g ;,. . TEMPORARY
--- p,i
[ ] NDif Reclosing Cut Out Switches for Unit 1(2) Main Transformer 345 KV OCBs are normally in 1.ie UP (ON) position to allow for auto reclosing of 345 W OCBs and are controlled by the Load 01spatcher. I } INITIAk$
- 37. P3 -clote 345 Ky Ring Bus from Panel 912-2 as follows:
- a. Notify Rockford Lead Dispatcher that manually operated disconnects to Unit 1(2) >
Hain Transformer are open. _ W
- b. Egage11 orders from Load Dispatcher to turn gff Reclosing Cut Out Switches for Unit 1(2)
Hain Transformer 345 KV OCBs.
\ c. WHEN switching orders have been received, TH,LN notif y Eau 1pment Operator in 345 KV Sw1tchyard that OCBs are about to be operated,
- d. T,a,J_9 the following 000 C/S's out of PULL TO LOCK'
%b (1) On Panel 901(2)-8:
(a) CKT BKR 6-7 (1-11). Q (b) CKT BKR 7-8 (10-11). ; q (2) On Panel 912-2: l E 2=' CKT BKR 6-7 (1-11), ! W cr (a) g
-% N (b) CKT BKR 7-8 (10-11).
i k[< W
- e. Turn QS CKT BKR 6-7 (CKT BKR 10-11) W SYNCHRONIZING Switch.
O( , xx 4 f. Verify: ,
$ 5 $'
'i P- -
(l (1) BUS 6 (BUS 10) energized. $ $ '. (f :" E (2) BUS 7 (BUS 11) de-energ12ed.
- g. Close 345 KV CKT BkR 6-7 (CKT BKR 10-11). Y v
OCP 2-4 O UNIT 1(2) TEMPORARY INillA.kS
- h. Tyrn QFF CKT BVR 6-7 (CKT BAR 10-11) /
5IvNCHRONI2ING switch, h 1 Turn QN CKT BKR 7-6 (CKT BKR 1-11) SYNCHRON!21NG switch. 3 Vgrify BUS 7 (BUS 11) and BUS 8 (BUL 1) are: (1) In phase. _ (2) Voltages are e:: val,
- k. Q_1ple 345 KV CKT BKR 7-8 (CKT BKR 1-11).
- 1. Turn Qf_E CKT BKR 7-8 (CKI BKR 1-11)
SYNCHRONIZING switch,
- m. !iptif y ' ockford Load 01sostcher that l CKT BKR 6-7 (10-11) and CKT BKR 7-8 (1-11) '
are closed. ' O. n. Turn pn Re-closing Cut Out Switches for j I Unit 1(2) Hain Transformer 345 KV OCBS i as directed by the Rockford Lead Dispatcher, i
- o. Placg the following OCB C/S's on Panel 901(2)-8 to normal-after-close: :
I (1) CKT BKR 6-7 (1-11), i (2) CKT BKR 7-8 (10-11). l 1
- 38. Monitor Main Turbine vibration recorder 4 1(2)-5640-60. ECCENTRICITY AND VIBRATION. h D
w C
=g
, a rm ,
,-... ,,2. c yf a =
m 6559 ' i 5 *E 5 w ~ Q x ::
% sE
- a.==.
O m m 2: = 14 22
T 'e m .g 34 p
W3 sp'37 1< )
s
.... 'EwPOSARY 002Y o ;,y)
(
* )
N#**
. 1_a Main Tur01he LD 8 0 tor Celtical Sceec of Unit 1 11 80 proximately 1000 rom (Unit 2 15 approx 1trately 1100 rpm).
l } E ]
- EAJLt;;3 Opening the Turbine Vacuum Breakers at high rpm (ie, greater than 1200 rpm.) 1mposes excessive locas on the tureine LP oc tor last stage buckets.
[ ] 1NE]ALS
- a. E githfLr of the following conditions exist, ,
E b throttle QI.gn TURB VAC BKR VLV f'T 90 1(0)-4901 te recuce turbine speed: h,//M L) (1) E vibration tiradually approaches j 12 mils. / (2) U at anytime a step change or rapid l rise in turd 1ne vibration occurs below l 12 mils, f
& I h% D. E it is necessary to rapidly reduce turb1he soeed, THEN 00 @I lower concenser vacuum
,1 D below 26 inches Hg ( @ greater tnan 6 g inches Hg back pressur:).
C)
*% 39. LH,6 turbine speed reaches between 900 anc '
800 rpm, THEN start all, TURB BRC LIFT PHPS. _ e m - 57 40. EW.,$ turb1ne speed decreases to Igrg, TW b verify: W k y .CC. n ,
,. % a, TURNING GEAR ENGAGEMENT SWITCH (L c
=- POSITION light is QN. X cr
==', W <
1E g b. TURNING GEAR auto start. C3 Ek
% c. Ph ;.9 1(2)-6640-60, ECOENTRICITY AND VIBRATION recorder on LOW speed, jg &
m- l o f3 hE 4e U 41. (Lupptch an operator to Unit 1(2) Turbine Lube 011 Tank to set Turoine Lube 011 Cooler outlet 2 "5
,f temperature on TIC 1(2)-3941 to 90 'F. V 23
. ~ .
h 000 2 .s US T *(2 ) T[WPOPARV
- 42. QupAtc.n an operator to panel 251-7 (2262 71, h2 !. STATOR COOLING CONTROL to olace Wyorogen Seal 011 System in VEhi status:
+:::::::::::::::::::::::::::::::::::::
[ l' C AQT[Q!j Care must De exercisec . hen ad,)Usting 1(2)~G-23, U-1 GEN GA$ ANALY2[R f]Li DRYER FCV and i f 0 )-0-2 7, U-1 VENT BLEED LINE SV to pre.ent over Dressur1: Ing Gas Anal,:er 1(2) GrL-1 due to a 60 0510 when placea in VENT
- status.
( '
................,,,,,,,,,: ,2 ,2 :::::,,,2 ,,,,,, :,,,,,2,,,,,,,,,::,,,,,,,::
LNlllA($
- a. Qfpreig 20-27 VENT otshbutton, M7 __ _
- b. A.qlys_t hydrogen flow to rotameter (GF-1) to 1.0 scfh (+325 ma. on LED readout), l'
- 43. QEp3 the follcwing H1n Turbine drains:
- a. MO 1(2)-3004A/0/C/0, CONT VLYS ABOVE '
SEAT ORN. / g# O
.d'. fYdw!
//'N@ /f M!v t
- c. MO 1(2)-3006, CONT VLVS BELOW SEAT ORN. b _ JhcAnturh14D 44 Qontinue Inserting rode in sequence until Reactor ,e j don /. .UO/*i -
power is between 5% and 10%. .e jd,I, t.// //*/,/
/
T'sJoGPAPY , . , , _ , _ _ s
]
W & gWa M W e g g6Wh E = x m A y C
\)\ mE ea > #
k: .V r C5
-c 2
s i
;;,r ;.4
'~"
1 NII 1(0) TEMDORAR, t: : : [ C%IllDN During Reactor Oceration anen Just critical or just sster,tical, the following the Reactor parameters =111 or to yr,o critical have a positive reactivity af f ect and can ca,;se increase the Reactor perioc:
- a. Aenon decay,
- b. Decreasing Reactor mater temperature. -
- c. Increasing Reactor pressure,
- d. Addition of cold water to the Reacto*,
As Kenon reaches its peak (4-11 hours), relative neutron flum increases in areas of lower power prior to the power reduction (core too and peripnery) and can intraase the notch worth of Control Rods in these areas. Careful
'esctor attention must be given to all Nuclear Instrumentation during Rods.
reactivity changes involvir; insertion and witharawal of Control All Control Nuclear Rod Engineer. movements should be with the concurrence off ied the Quali Anytime umw c.. Control Rods are manipulatec, the NSO e og<t ma i ; av Ji P^to e To P a Cd ww.s MSU W 4 ine. SM C r o d M. 0 V C.m. f./\T. [ M :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::] C INITIA($ C3 45. WHEN Roactor power is between h and 10s, T1!Eb: N a. O
.s Verify APRMs indicate between 4% and 12% on both-- (f)
- W E
~
g (1) g Panel 901(2)-5. i bd W 5 5 (?) X ct Panel 901(2)-37. i W C O :E
" b. A f C Verify IRMs are on scale per 00P 700-2.
c. I p: c~ W Transfer REACTOR MODE SELECT switch to STARTUP/ HOT STANDBY position. gh p c2 LA= {} w
7 1 OCP 2-4 (' -e . -
- m i~et c UNIT 1(2)
\
TEMPORARY t INIILALS
- c. $wjl;_h all IRu/APRM recorcers to IRM position. /oy. l . r,/sj h, g
- e. Verify alarm 901(2)-5, F-1, LOW COND VAC MSLIV CLOSED BtPASS is lit. /
- f. Verift eli of the following relays are energized, located on Panel 901(2)-15:
(1) 590-112A, CNDSR LO VACV AND MSIV '
/
CLOSURE BYP AUX REL. /' __ ' /'C !3"7*'4[d (2) 90-1120. CNDSR LO VACU AND MS!V Y o (p7pi Ed ' g ./ CLOSURE BYP AUX REL.
/u/. ,Ohg '" # "
9 Verify a11 of the following relays are energized, located on Panel 901(2)-17: (1) 590-1128, CNDSR LO VACU AND MSIV j (Q CLOSURE BYP AUX REL. ////3 t-V (2) 590-1120, CNDSR LO VACU AND HSIV , CLOSURE BYP AUX REL. _. /I._
- h. LF REACTOR MODE SELECT switch did NE transfer to STARTUP/ HOT STANDBY F1 indicated by the above relays NE being energ12ed, TWEN_ :
(1) P_1A qq REACTOR MODE SELECT switch to / REFUEL position. 4j//3 ,
> (2) P_laqq REACTOR MODE SELECT switch to 'l STARTUP/ MOT STANDBY position, j g (3) Verify the above relays have energized.
Q
.= 46. Notify Chemistry Department to begin 4 hour /
b Reactor water sampling per QCP 200-3. Person notified: Af/d { L.
- a. Time: $ c9 O
Q. O 47. Carefully . insert Control Rods in secuence to X
// U @
cecrease Reactor power. M ,8 f ///fd / E
- I
- 48. Maintng IRMs on scale per 00P 700-2. 6 sW
(~ 6 ig] C <
% h, en p
Las bE e Ei r-e
?-
l l
-r+et' <
- 2 c: Ocp :..t
('N UNIT 1(0) l
!] .y TEurfcARv l
[ 3 C4UT12N Ocening or closing of Main Turcine Bycass Valves can charge Reactor reactivity. If suber1tical it may cause Reactor to go critical ano critical it can cause Reactor to go supercritical at a nigher than cesirec perioc. If IRus are at the high enc of scale during a Reactivity ac01 tion causec
- by Reactor pressure changes, a Reactor Scram may be e<periencec.
[ ; INI'ML.i
- 49. Ajlysi 1(2)A/B PRESSURE $TPOINT c to maintain Reactor pressure at 920 psig. _
f (%.) I I U NOTE Reactor pressure can be controlled by use of the Turbine Bypass Valves witn Reactor 1(2)A/B PRESSURE SETPOINT adjust as long as the MS!vs remain open and the EHC System remains in operation . The point of adding heat to the Reactor is on IRM range 7 and above Belo. IPM range 7, only residual and decay heat will af fect Ranctor temperature and pressure. (
> '............................................... ............. ...............)
C O MITIALS G 50. WHEN directed by SCRE, THEN p.grform one of the O following: (h
*0
,'d W k
- a. E Reactor pressure is to be maintained E N C"4 with Turbine Bypass Valvss, THEN continug CL C-(",", to control Reactor pressure by inserting y$ E e
c-) or withdrawing Control Rods to maintain desirednumberofTurbineBypassValvesopen.3//?
'/
C ' Es '
- b. H 1t is Np longer desired to operate in this yy O'
.O s mode, THEN exit this proceaure and e_rttate the PR <
V CD appropriate procedure as directec by Snift / $'; i l l W Engineer. A /# :i l V
i i QCP 2-4 O UNIT 1(2) ! TEwPORARY l INITIAL) ) i
- 0. H Reactor pressure is to te controlled without the use of the Turbine Bypass Valves, LwB continue performing this procadure.
- 51. E at any time during the perfortrance of this procedure the IRus decrease to range 4 T(N J.,jn ;
insert SRMs into the Reactor core per 00P 700-1 fg/t_/f t v /I N jf'D ! i t/c:,TD%)g i
/^ \
[ ] y/N/ ' NOTE E there is negligible decay heat. LNLN water rejected from the Reactor water Clean-up System may be sufficient to control Reactor pressure. ( }
! } f CAUTION f3 Cl Excessive reject of Reactor water can overload the RBCCW System via the RwCU non-regenativs heat exchangers and cause an increase in Drywell Cooler ?
temperature resulting in high Orywell pressure Scram / Croup 2 Isolation. ( } INITIALS
- 52. Start rejecting water from the Reactor through Reactor Water Clean-up System to Main Condenser or Radweste per COP 1200-7.
N.i .2 /[ // f O 1 A n.;Ob~% .. . es r= e7 e-s W E. < u ,, , b CL C
/\ X CC
#/g W $
/s y n O g& 1:
- v p: <
f gu J P- , 20
. ' 9 Ocp :.s
( V) C:a ., ; UNIT 1(2) TEMPORARY I } 1011 l When inserting Control Rocs to decrease Reactor pressure, sufficient time shoulc De allowed between subseovent Control Roc maneuvers to allo. for l Reactor pressure anc power response cue to negative reactiv1ty insertions. I If sufficient time is @ allowed, Desctor pressure and ocwer may decrease too rap 1dly or too low, this will recuire "ontrol Rod withdrawal to pr1ng the Reactor critical anc raise power to the psint of adcing heat (IRM range *
- 7) to terminate the power and pressure cecrease.
l If Control Roc movements are performed slowi;, it is possible to control i Reactor pressure by inserting or withdrawing fewer Centrol Rocs to compensate for Reactor moderator temperature and Xenon to control Reactor pressure, i ne o . m u m. . Anytime c c- . ;at e.Control Rods are manipulated, thal\ the NSO nem rd SCEE egl'de rSc4E. p ( To eat,,n rod Movemcoi.
............_'............................ ........................ .......... }
C' tmLAJ
- 53. Slowly 101gnt Control Rods until:
- a. Reactor pressure is less than 920 ps19 d _f /$-
- b. Turbine Bypass Valves closed. L h 54 WWES Reactor pressure is less than 900 psig, THEN:
C3 a. Eypass Charcoal Absorbers by placing ADSORB INLT/BYP VLYS g 1(2)-5414/1(2)-5418 moce switch to BYP position A3 Q verifv: m (1) Qpf n A0 1(2 )-5418, CHARCOAL ABSORBERS-BYP A0V. g / fff// C (2) p_1 2 }_t A0 1(2)-5414, CHARCOAL ADSORBERS-INLET A0V.
'f @
g f
- b. Start Sparging Air per 00P 5400-8. h L W "
o c. If g on Unit 1 "B" train, THEN: E L&
- (
\
(1) Qpen 1(2)-5499-71B, OFFCAS RECOM Ek ~ TRNS BYP VLV. Ad / (2) Close if2)-5499-75/76, 1(2)A/B 0FFGAS {' h' REC 04 TRN INLET VLV. i ro
1 OSP ; .1 Ci UNIT 1(2) V TEw NRAR1 ( ' tafla E at any time pressure can NQ1 De controlled tne Reactor s w h te manually scrammec. Snal! [ ] DE.I A_d
- 55. E usivs are to remain open A3 Reactor pressure can be controlled w121gy.; Turbine Bypass Valves.
TM S cont 1nye controlling Reactor pressure with - R*CU reject flow anc Control Rods. $h,__
- 56. bM S It is N_9 longer desired to operate in this mode QD lt is recuired to close HSIVs, _Tyjy perform ;ct of the following:
- a. E it is desired to exit t'03 N 0cedure, TWEN gni.gr tne appropriate prockIure as D3 (g directed by Shift Engineer. Iv/, jA3
- b. E it is desired to (191g HSIVs, j b., o /
TWLN cont 1 nut in this procedure. , jN 1_ I ] tt91.E IF Reactor pressure is to be maintained without the use of the Turbine Bypass Valves and HSIVs closed, THEN Reactor pressure may be maintatried through the increasing and decreasing RWCU System flow, "2 P :O a - . - x N'-"C-M. Turbine Sealing Steam, RCIC System, HPCI System and Control Rods movement. 7
# ( )
Cl3
- 57. H MSIVs are to be closed AM Main Steam Line Iy p
Drain Vahes can be used for pressure control, THEN: p ed V) ~ c.3 .: wwu vnmec h1 E
,. g -
r;*, ~. N
. . . Q. c hhhh k bd \
d O- - h g W 0 OS,::. dh
- w
_ - - . - - , - - , - - ~ .
QGP 2-4 [ UNIT 1(2) TEMPORARY t ) WII when inserting Control Rocs to cecrease Desctor pressure, sufficient time should be allonec between subseovent Control Roc maneuvers to allow for Reactor pressure and Dower resconse due to negative reactivity insertions, If suf ficient time is !!^J allowed, Reactor pressure and power may decrease too rapidly or too low, This will reavire Control Rod w1thdrawal to bring the Reecter critical and raise power to the point of adding heat (!RM range
- 7) to terminate the power and pressure decrease, .
If Control Rod movements are performed slowly, 1t 15 possible to control Reactor pressure by Inserting or withdrawing fewer Control Rods to comoensate for Ceactor moderator temperature and Aenon to control Reactor cressure. Anytime Control Rods are mantoulated, the NSO ad ECMa :o 'l c; v cor:;c+t c . # :;t m , Shall notW [ p r9er To coaq roo; movernent, 3 the SCRE ) n INITIALS
- a. Slowly. insert Control Rods until:
(1) Reactor pressure is between 600 to
//
800 psig, d',o hT,h/ (2) Turbine Bypass Valves closed. U
- b. QpfLn the following steam line drain valves:
7 (1) H0 1(2)-220-1, STM DRN !$0L VLV, hlI )/ (2) NO 1(2)-220-2 STM DRN ISOL VLV. h CD (3) Throttle gpin H0 1(2)-220-3, OUTSIDE N ORN VLV as required to control Reactor e A'*** " ' 0ll(!(f $fpfl t6 /M()-l-)30~} ) ph / tr y Gp
/
TEYFCPD'6flt c/csi,/ r ,f a . m r c it X e cr e - - w g O 3 W 6559 . ,01 ~ V Q e E :t- cc W t 35 nu e 31
w w. ,; g a: 9 i
""'; M t- f p . 5 e. c. QOp .4 O \
UNIT 1(2) TEMPORARv
- r::::::::::::::::::::::::::::::::::
I ) 9.AD1LQB [f at anytime pressure Can NQT be Controlleo the Reactor q ..;s be scrammed. Sh o.!! I J 131I.1A.kl
- c. E at any time during the performance of 1solating the steam lines, the Reactor pressure starts to increase, IH[y perform the following in order 91ven to control Reactor pressure:
(1) Reopen MSIV just closed. (2) H IRM on range 7 or above, THEN inse_rj Control Rods. (3) Increase RWCU water reject flow, i V (4) Slaff RCIC System per QCOP 1300-2. (5) $1gr,,1 HPCI system per QCOP 2300-6. (6) Scram Reactor. 'b /f fl
- d. Q1Q19 Qng MSIV at a time A,,NQ wait a g sufficient time to ensure Reactor pressure
,a is staDil12ed or decreasing before closing
<- the next MSIV.
(1) A0 1(2)-203-2A, 2A OUTBOARD HSIV. I ! C. f
.f3, (2) A0 1(2)-203-2B, 2B OUTBOARD MSIV.
.s G (3) A0 1(2)-203-20, 2C OUTBOARD MSIV.
'~
l 7,% (4)- A0 1(2)-203-20, 20 OUTBOARD MSIV. Y (h g O $ ~ D (5) A0 1(2)-203-1A, 1A INBOARD M$1V. lL'fleht .5 N
.h:: D. c (6) A0 1(2)-203-13 16 INBOARD MSIV. ofen O (7) AO 1(2)-203-1C, 10 INBOARD MSIV. !
L4= >w
=e p (8) A0 1(2)-203-10, 10 INBOARD MSIV. y: ch V
N$
- 5 =
9
I n.+ - 00p 2.1 (p)
. .,. .. , m VNIT 1(2) v TEWPORARY
[ ' NOTE
' hen inserting Control Rocs to decrease Reactor pressure, sufficient time w
should be BIloweo Le: ween subseogent Control Rod maneuvers to allom for Reactor pressure and power response due to negative reactivity insertiors. If sufficient time is @T allowed, Reactor pressure and poner may decrease too rapidly or too low. This will require Control Rod witnorawal to pring the Reactor critical and raise co er w to the point of accing heat (IDM range
- 7) to terminate the power and pressure decrease.
- If Control Rod movements are perforned 31owly, it ts possible te control Reactor pressure by inserting or withdrawing fewer Control Rocs to compensate for Reactor mocerator temperature anc xench to control Reactor pressure.
Anytime Control Rods are manipulated, the NSO enc C00: eisi' te ecote t
^tto- .Shall not' ON ec. SCAF pr e c
( ec to veac ':h noc.! rnevemerd.
)
V INITIA($
- e. If Reactor pressure is stable or decreasing, THEN continue to control Reactor pressure by use of tne following:
(1) Control Rods. (2) Main Steam Line Drain valves, bC (3) RWCU water rejection per 00P 1200-7 Q (4) RCIC System per QCOP 1300-2. C (4) HFCI System per OCOP 2300-6. (([)k2 O 7
*[J 58. WHEN It is @ longer desired to operate in this C'"J moce QR f t is reoutred to depressurize Main Steam m g g Lines. THEN perform gns of the following: Itj C N
b t Q a. U it is cesired to exit this procedure, L c
% THEN enter the appropriate procecure as X Or
=
C oirected by Shift Engineer, b< A LLI 6 b. If it is desired to depressurize Main Steam J h(./ C3 LJ== Lines THIN continue in this procedure. ^> k d//f// [ >j.$vcn
/
pE e. 2> # D5 e e- 0 I 33 J
u- . - _ .. - _ . _ _ . QGr s4 UP. I T 1(2)
, V T[MbCRARY
)
MIE i II Cea0 tor pres!Lre is to be maintainec with Waln Steam Lines cepressur1:ec, hj3 Peactor pressure may be maintained through tre increasing anc cecress1ng Ca0U System fica. RCIO System. WPC! Systet ano Control Rocs. ( )
- 59. If Main Steam Lines are to te cepressuri:ec.
hES: I ) EIms C Do EQJ take any ecuipment out of service until assured that Reactor L/ essure is stab 111:ec. 5 LE at anytime pressure can NAT be controlled tne Peactor we ce
\ scrammec. Shall I )
- n:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::
IN111A'J 4 8. 1[ at any time during tne performance of
% 1solating the steam lines, the Reactor C pressure starts to increase, B_[3 perfgg,3 the CD fol10w1ng in order given to control Reactor pressure:
.h w
(1) Ri pp_tr! the drain valve just closed, (U (2) LE IRMs on range 7 or above, TWEN C"J
. insert Control Rods.
k W F Q (3) In_gfr_tqLe RWCU water reject flow. W g
% ft ,
C (4) Start RCIC System per CCOP 1300-2. E h X o b (5) Start HPCI system per QOOP 2300-6. W ! CD ^ O (6) S_qf_ptm Re a c t o r. _) l b 7[ / p? - i g V 2E u :.
QCP 2 4 UNIT 1(2)
\ T[wp04AAy bU1h.$ l 1
- b. (_1.p.B the following crain valves on9 at a t we anc verify Ceactor presssre stac111:ec or cecreasing before closing the next crain valve:
(1) Slowly glon MD 1( -220 3. 0VicIDE DRN VLV. f(A,vt/r4' g.h ._ (2) MD 1( 2 )-220- 1, STM DRN !$0L VLv. d[f/f'/ /) - (3) MO 1(2)-220-2, STM D#N $0L VLv. , [d M'//'[U
- 60. Isolate Off Gas System per QOP 5400-2. _ _///fN
- 61. If this condition is held for an extenced time l period, THEN gplatng ig for Aenon buildup anc cecay, temperature anc pressure changes as follows:
1 O h 9
%~
,% .. ...s = n ,. p .
~'
~ *[ 7 I } { g p
% W E l
k '5:* , y; % n. 5 e l X cr
- i. i
( W g EE
-O &E &
RF - 2: U' y
(g) OGP 2-4 UNIT 1(0) V TEWPORARY [
]
LWUD During Reactor operation when Just critical or just subcritical, the following parameters will have a positive reactivity affect ano can cause the Reactor to go critical or increase the Peactor cerlod:
- a. Xenon cecay,
- b. Decreasing Reactor water temperature. '
- c. Increasing Reactor pressure,
- d. Addition of cold water to the Reactor.
As Xenon reaches its peak, relative neutron flux Increates In areas of lower power prior to the power reduction (core top and periphery) and can increase the notch worth of Control Rods In these areas. O V Careful attention must be given to all Nuclear Instrumentation during Reactor reactiv1ty changes involving 1nsertion and withdrawal of Control Rods. Anytime Control Rods are manipulated, the NSO w +M SOLE eta'l t+ :a . _ - .. _ __ -_.--, m - . Shajl nofd %c. SC.RE pnor ( te cash re d rfloV C T. tdt. ]
> MM C
1L<>l$h! j
- a. Pi m %" recorcera IRM recorder, one in j ,/
CD each RPS channel, on fast speed, J [ b, / / ' [ j,; f
'/
/
C b. Eeh q1 the two highest SRMJto be recorded on O / the SRM recorder. M/A (/ -
'sU 03 W)
E k w
- a. o r=
~ >< m C *EN'FCRARv W R a:t w :s . -
vmm eo. C b 6559 p,..mn 3g = cr O u O gs 2 h # , V 6 Wk # l- M
p T C R K .., QCr 2-4
> 1 E ,7 UNIT 1(2)
T[MPORARY 6b53 , r.. [
)
Q AUT [QN Activities Engs.lg be avoteed tnat can cistract the operators and supervisor) involv 1d in this evolution. Activities such as shif t turnovers and surv- ' lances .nould be delayed until after criticality has occurred. Anytime Control Rods are manipulated, the NSO eM t h'; ErtE m M ' n :trt ,2 y 4:: 0.;, sho.1\ not4 g RQ peig g
- 5 to Co.Ch rock fn6VBM6d.
During approach to Reactor crit 1Cality the operator myl use all Nuclear Instrumentation to 8:Onitor the Reactor status. Withdrawing Contre l Rodi during plitnt conditions when the Reactor mocerator temperature is decreasing or Xenon is decaying, can cause the point of criticality to occ.fr uitxpectedly or short Reactor Deriods. . f Sho.ll ( A.11 Control Rod withdrawals NM be limited to gng notch withdraw to minimice amount of R9 activity addition so NR to 90 unexpectedly critical or cause a short Reictor period. When approaching criticality a sufficient waiting period should be allowed between each Control Rod movements to allow Nucloar Instrument.stion to settle out. I )
- i::::::::::::::::::::::
INITI At.S g
- c. Carefully withdraw Control Rods qng notch at a time per QGP d-1 and bring Reactor / - N critical. M/d
/k/ / 1 x
0 et
- d. Establish a $1 Reactor period. j f[ N ,/f ! $
K N/f I # g% e. Monitor L ' IRMs, and SRMs period meter, sy Q,%,, *) /,b./9 /
- 1i *
(1) Ran._qe IRMS as necessary per QOP 700-2. t P;
- qi e I
k (2) thdraw SRMS as recuired per
/, b ' v[) 4 f. f_ stab 118.h a slow heat-up rate. A I
37
00P l*4 /^ CNIT i(2)
?EwDC#A8v
( W1 OeDenoing on now long tne plant ras ceen at lower Domer 'eveis n' cetermine now of ten a Control Doc will have to be witncra.n Or inserte: t; I sta0111:e the Reactor. As -enon r Du110s in anc/cr tea:t0* mocerate- ' temperature increases, then accit'onal Contro' Ao:s m'1 have to te withdrawn, As Xenon cecays anc/or tetteratyre cecreases then Ochte01 C;;s will have to be inserted to comcensate. To avoid Reactor pressure /00=er oscillations / transients. It is necessary to slowly adjust ecutement (1e. control rocs. Closing Valves, etc) trat tay af fect power / pressure and to allow the transient /cscillation to canten Ogt orior to making any furtner adjustments , the key to get the Reactor to staD111:e is E to overreact as Aeactor power cycles up and down. The longer the Reactor is in this concition the less Control Roc movements will be recu1 red. ( ) k
.. ::::::::::::::::::::::::::::::::::::::::::: enas :::::::::::::::::::::::::::
[ ,' cAvT:os Anytime Control Reds are manipulated, the NSO e"- :N OCTC- 5 a t' .m
+m . m . . . w.- n p; . S n o.4 6 c* .t .
- h C, S M~
[ PNoe % dach .o i,("o d m ove.m EAT. N
- 4::::::::::::::::
LNZla.il 7 9 No',ch Control Rods Der the approved Rod was Secuence as necessary to maintain the ,/ C". costred Reactor water temperature / pressure, h y'p all ef /E!w'// D ' 62 WHEN this operation is n,g longer recuired, TWEN O enter the appropriate procecure as cirected Dy / 0 the Shift Engineer. $/[a d///d.f /' ff) J ' W 2
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QGP 2-4 UNIT 1(2) TEMPORARY
- 63. Procedure cle,dout:
l Unit: DatefTime: / Procecure Completed By: M. AW(.506^- i (Control Room Operator) Procedure Reviewed By: (Shift Engineer)
- Procedure Reviewed By:
1 (Operating Engineer) H. ATT ACHM LN,TJ None. l l
.- . g. . , p a .. < - - - ; ,m r~ c.:
l M -, . . , Q;$l ,'.' Cl3 c C3 C4 som w m E C3 W 50 w Q: y C E im x x w W y CD LA= ,w af C @ fE q% e 4 (fina1) \ 39
~
QAP 1100-$19 Revision 1 10CFR50.59 SCRitN! M FOR PROCEDURE December 1990 CHAEES, T[Sf 5 AND [XP[ RIM [NTS Procedure Screening Number: PS. 91 -lQ 3 40ft Nhere the preparer 15 conficent that a ' 10CFR50.59 screening will indicate that a 10CFR50.59 Safety [ valuation is reautred, it it permissible to proceed tb.- gj directly to the 10CFR$0.59 Safety Evaluation (QAP 1100-521). Procedure, test or [nperiment
Title:
$ ls v 7~ rl a w a Gem Pewtv . t r> t & ,e n T""e w 5%hv h V SM S u n t e el Cow d T, i ._ Procedure, Test or (speriment Number: Mk b V Unit (s): U / /U 2 Applicable Plant Mode (s): Dv , S*?<. e f v a / # rW SPSP (RUN. 51 ARIUP/w01 StiBY, R(FUEL or SWIDOMN)
- 1. l$ the procedure revision, addition or deletion for a OGA procedure:
( ) Yes - STOP and perform 10CFR50.59 Safety Evaluation (this form may 2 be discarded) ( M No - proceed to Step 2
- 2. 15 the procedure, test or esperiment~ revision an editorial change to a A previously approved procedure, tett or experiment as determined below?
3 (This 15 applicaDie to both 'O' and 'QC' procedures.) C3 YES NO C (M ( ) Rewording without changing actions to be accomplllhed Q D ( VT ( ) Addition of clarifying Information, such 45: m - Location of components C - Litts of tools required - C k o ( ) ( /) Changes to personnel proper names or phone numbers g
~
g_ C ( ) ( d Spdling, gramar or punctuation changes b ( ) ( /) Format changes (changes to form but not action) C3 4 ( ) ( /) Other - provide justification as to why thlt Change 15 he an adelnistration change: 3EC e O -
^'eaoveo H 3,,,, ,,, Dic311990-Q.C,0.S.R.
- 6 .- 0AP 1100-519
- Revision 1 ,
!$ full scope of this change encompassed by one or more of the above?
O(/ ( ) Yes - screening Il complete, proceed to step 9 ( d No - proceed to step 3 3 Has a 10CFR50.59 Screening of Safety Evaluation been previously performed that identif tel this procedure change, test or esperiment' (Previously performed screenings or safety evaluations are valid 45 long 45 tystems are not redified in a way which would change interactions witn systems descriped in the UFSAR.) ( ) Yes - Screening 15 complete, proceed to Step 8 (Note the previous evaluation number where indicated.) ( vi No . proceed to st_ep 4 - 4 List the reference doc 5ments reviewed for this 10CFR50.59 screening. - (Identify documents referenced even if no information was found in that section.)
- a. UFSAR Section(5): {$ j6./ d.3 - /0.3 j /.f. 3, /M
- b. SCR Section(s): ve r C. Tech Spec Section($) /0 J IS/ t L a 3 J J. ( N4 'J T L f 3. 9 J . / 0
^
- d. Fire Protection Program Document Pkg Section(l): N A- .
e, Code of Federal Regulations Section($): #NE f, Regulatory Guidet (NUREG5): Med S, Does the affected procedure do any of the following:
- Estabitsh administrative controls described in the UFSAR.
- Control plant operating conditions described in the UFSAR.
e implement specific UFSAR conenttments. D ( ) Yes - STOP and perform 10CFRSO.59 Safety [ valuation (this form
.D,,,,,, may be discarded)
( d No . proceed to Step 6 q g 6. 15 the affected procedure or procedural activity outlined, summarited. or completely described in the UFSAR or Technical Specifications? (/) [ _~y-E C
%= Yes - STOP and perform 10CFRSO.59 Safety Evaluation (this form g
( ) may be discarded) $EE 80 Ed., ( d No . proceed to $tep 7 sw f) APPROVED $$ & w .
. . , n DEC 311990 4{
4098a c-,Gi .,,, Q.C.O.S.R. l
.- - W 1100-519 Revision I
. Does the activity perfore tests or experleents not described in the g UFSAR or change the procedure for performing tests / experiments
( previously approved in accordance with 10CFR$0.59?
) Yel - STOP and perform 10CFRSO.59 Safety [ valuation (this form may be discarded)
( d No - proceed to $tep 8
- 8. [glelentChange) - Based on this evaluation, I have determined that the propo,ed facility change:
( /> will not change procedures described In the UFSAR, and, will not result in a tettlemperiment not described in the U'SAR
. br
( ) has been previously evaMted . note previous evaluation number attM su l- ? l. 9/ ,_ Preparer signature Date
- 9. Review - The reviewer agrees with the determination that no Safety
[ valuation is feQuired. O /3//22cmk Revtever Signature Date
/ s< 9i .
- 10. Obtain facility change screening number from the Tech Staff ciert ano note on page 1. The original screening documentation shall be filed by the 4cfi Staff ciert. Copies are to be placed with the applicable package (s).
? ( ' ' I"') .$ E- * */ *} ) Q t'l* g c539 .m s;2 131 gg s~e n,
UE :E EW GE
- i ]\ A.' PROVED EE "~I (ftcat) 27'
.r, 40984 3-DEC 311990 O.C.O.S.R.
Quac Ci:les Simu a:or ini':ia Cer':i'ica': ion Reoor': . March, 99' vo #2 . Commonwea:_;h 3d.ison
r . Test Numbor:SV-1 Revision Number /Date:0. 2 /14 /91 Frequency 6nnual _
., O QUAD CITIES SIMULATOR SURVEILLANCE TESTING t- A. PURPOSE The purposo.of this procedure is to:
- 1. Verify that operator conducted surveillance testing on safety-related equipment or systems can be conducted as required by ANSI /ANS-3.5-1995.
- 2. Verify that the simulator's computed values of selected surveillance paramotors shall agroo within i 10% of Quad Cities Unit One plant's surveillanco paramotors as required by ANSI /ANS-3.5-1985.
B. REFERENCES
- 1. ANSI /ANS-3.5-1985: Nuclear Power Plant Simulators for Use in Operator Training.
- 2. Quad Cities Surveillanco Procedures.
q C. SURVEILLANCE SELECTION CRITERIA ,
- 1. The selection critoria used to moet ANSI /ANS-3.5-1985,
-section 3.1.1(10) requirements (simulator surveillanco tenting) are: , a. Surveillanco is safety-related,
- b. Surveillance frequency is monthly or loss.
-c. Surveillanco contains control room indications or requires control board manipulations.
D. INITIAL CONDITIONS
- 1. Use the ' OC, 100% power, equilibrium xenon initial condition (IC) unless a lower power lovel is noted in the '
i surveillance proceduro.
- - - - - ~ . - = - -. - . . ~ - - . - . - . . - . . _ . _ . - . - . . . - . - - . , ~.
1 ll Test Number: SV-1 l Revision Number /Date: 0, 2 /14 /9.1 l Frequency: Annual-(; s . _ QUAD CITIES SIMULATOR SURVEILLANCE TESTING E. DATA COLL'ECTION-
- 1. The Control R( tm: Data required by each surveillance procedure shall be-collected.
- 2. Data-that is obtained from outside the Control Room shall be obtained, if available, from the simulator data pool variables. If the data is not available, mark that step N/A.
F. ' TEST INSTRUCTIONS
- 1. Ensure that the simulator meets the initial conditions as specified in Section D.
NOTE The simulator has the capability to conduct the shiftly/ daily surveillances, various r's channel check surveillances and the system
!s b: lineup surveillances, however these surveillances do'not meet the surveillance acceptance criteria and will not be performed-
- 2 . Using the latest revision of Quad Cities Surveillances, perforia the following procedures:
a . ;QCOS '2 03-3, Main Steam Relief Valves. Operability Test
- b. QOS 250-1, MSIV Closure. Monthly Scram zSensor-Functional ~ Test -
- c. QOS 700-1, SRM-Detector not in Startup Position Rod Block Functional-Test
- d. QoS 700-3,- IRM' Detector not in Startup. Position Rod Block Functional Test e..QOS 700-6,_ 'APRM'High Flux (Heat Balance) Calibration Test
- f. QOS 1000-1, LPCI Flow Rate Test . .
- g. QOS 1000-4, RHR Service Water Pump Flow RateLTesting
-Operations every=90. Days
- h. QOS'1000-6,: RHRS Pump Flow Rate Testing Operations every 90 Days.
- i. QCOS 1300-1, Monthly RCIC Pump Operability Test
- j. QCOS 1400-1, Quarterly Core Spray Pump Flow Rate Test-
- k.- QCOS 1400-9, Flushing Corc Spray Lines into the Reactor O ,
l
._.,.u ..;_...;.--_..- -. ..._.~---_._.-,4,_..
, _ , . , , _ , . _ , . - , , _ , , . . - . _ . ,- . -_ -_J
. . . . . . . . . . - - . - . . . - . - ~ . - - - . -
Test-Number: SV-l' Revision Number / Date: 0, 2 /14 /91 Frequency: Annual i LQUAD CITIES' SIMULATOR. SURVEILLANCE TESTING
- 1. OC'OS 2300-1, Monthly HpCILPump Operability Test 7
-m. QCOS-2300-l'3,HPCI System ~ Manual Initiation Test
.n. QOS 2 9 00-1, Safe Shutdown Makeup Pump (SSMP) Flow Rate
> Testi
- o. QOS 3700-1, Reactor Building Closed Cooling Water System Power-Operated Valve Testing at Cold Shutdown
.p. QOS 5600-1, Turbine Control Vhlve Fast Closure Scram Instrumentation Functional Test
- q. QOS 5600-2, Turbine Stop Valve Closure Scram Instrumentation Functional Test
-r.rQOS 5600-4, Weekly Turbine Generator Tests s.-QOS 5600-5, ' Turbine Generator Monthly. Tests
- t. . QOS_6600-1, Diesel Generator Monthly Load Test u.-QOS 7500-5, Standby Gas Treatment System Monthly i Operability-Test
- v. QTS 1104-1, Shutdown Margin -Suberitical- Demonstration- -
G. ~ ACCEPTANCE. CRITERIA' 4
- 1. Eact surveillance can be~ performed satisfactorily using
? installed control board instrumentation or variables in the simulator data pool _ andLmeets the acceptance criteria given=in the surveillance.
.H. DOCUMENTATION Li
-1. Retain the surveillance procedures along with the copies of the' selected plant-surveillance data used for comparison.
l f I i i i t
.\
Simulator Oub b7/C Test Procedure Cover Sheet Test Number ace 203-3 PTAO-105T1 i Test Date Performed 329/ I Descriptlon g,, pp ggugp yguigs gmgfo.7.Y TGST Discrepancies Section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date O (_.) Test Results I 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary,
- 3. Tests results UNSATISFACTORY. Retest the above after correction of above discrepancies.
Retest Complete .- Date Test Complete / m J -- Date 3'74/ SFCC Acceptance ' < * ~ - 4e Date V 7 '7/ l Simulator Supervis Acc tance x
/
g,, w Date Jf-9/ 0.E.CO. 05-1215 12-09 -
.. .- . ~ .. .. . . - _ . ~ . - . . . .. ~ .- - .. ,
QCOS 203 UN!T 1(2)
\ REVISION O
$AFETY RELATED ;
ON HAND
-HAIN STEAM RELIEF VALVES OPERABILITY TEST hk APPROVAL :5KyitJRE 2
S$ Mex Mir _]/3 ibi TilLE_ Ef7 ECililt DATE A. PURPOSE' Provide steps for the performance of Tech. Spec. manual operability test of the Main Steam Automatic Pressure Relief Valves every six months (or.
.after maintenance).
B. O!SCUSSION-
~1 ;
The 10 second delay between relief valve openings is used to prevent excessive containment _ loads _due to a high water level In the relief valve. discharge line. This water is drawn up into the relief vi ve
. discharge line from the suppression pool as a vacuum is-formed.from
-steam condensation following^reitef valve closure, Opening a relief valve less than_10 seconds after a previous operation would thus send a slug of. water into the suppression pool,-resulting in O. possible. structural damage.
2, Where brackets, ( =), are provided in.the procedure, place a check i to indicate step completion. C. ' REFERENCES
- 1. Technical Specifications 2.5.D.1/4.5.0,i, Automatic Pressure Relief Subsystem.
- 2. l Technical Specificati.ons 3.6.E/4.6.E. Safety and Relief _ Valves.
- 3. ; Technical Specifications 3,7.A/4.7.A,-Containment' Systems, Primary
, Containment.
- 4. OCOA 203al, failure of.a Relief Valve to. Reseat _ Properly.
- 5. QAP 300-10, Operating Records.
6._ OC05 203-5, Safety Valve-Inopetable: Outage Report.
- 7. QCOS 203-4, Automatic Pressure Relief Valve (s)-Outage Report.
'8. 005.1600-05,- Post Accident Monitoring Instrumentation (Containment -
Monitoring Instruments) Outage Report. L 2257a _ _ , , . _ , . - _ . - _ _ . _ . _ _ _ . _ . . _ _ . _ . _ , - ~_ _ __ ,
l QCOS 103-3 UNIT 1(2) REVISION O
- 9. VETI No. C0lS7 Holytek Operating Instructions Model 2702 4Al-R-i/C O
32 Channel Recorder / Data /Relogger(software version 3-A and later).
- 10. Quad-Cities Nuclear Station Procedure Writers Guide, l Revision 1. January 31, 1990. I D. EQUIPMENT REOUIRED None.
E. PRERECCISITES
- 1. The Shift Engineer has completed Section E.1 of Attachment A, ,
Automatic Pressure Relief Valve Operability Test Data Sheet. I
- 2. The Unit is off EGC control. /
- 3. Verify a copy of QCOA 203-1 is readily available. /
- 4. Verify venting of the Orywell and/or Torus is NOT in progress.
- 5. Verify TORUS H2O TEMP, 1(2)-1602-8 recorder on panel 901(2)-21 is operating.
F. PRECAUTIONS
- 1. Minimize the time relief valves are open to prevent reactor pressure transients.
- 2. Do NOT re-open a relief valve within 10 seconds after it has been closed.
G. LIMITATIONS AND ACTIONS
- 1. E at any time during the performance of this surveillance a relief valve fails to close or reseat properly, THEN immediately perform QCOA 203-1,
- 2. E only partial tetting of Relief Valves (less than five valves) is required, THEN:
- a. Ensure all prerequisites are met,
- b. _ Ensure all test setup steps in section I. are complete.
- c. The independent verification and analysis steps performed after valve testing must be performed for all valves cycled during performance of this procedure.
- 3. IF two Automatic Pressure Relief Valves are inoperable. THEN perform 4.
QCOS 203-4 E a Target Rock Relief Vcive is inoperable. THEN perform QCOS 203-5. h
- 5. IF an acoustic monitor and/or temperature monitor is inoperable.
G EN perform 005 1600-05. 2257a QCOS 203-3 UNIT 1(2) REVISION O p) V 6. Due to the location of temperature sensor on large' Rock valve, there is a long time lag before temperature indication will return to normal.
- 7. Torus temperature limitations and actions: (C-3)
- a. WHEN there is indication of relief valve operation or testing which adds heat to the Torus, THEN Torus temperature shall be cor.tinually monitored and logged per QAP 300-10, every 5 minutes until testing is terminated,
- b. If Torus temperature reaches 105'F during relief valve testing, THEN terminate testing A,N.LD reduce Torus temperature below 95'F within 24 hours.
- 8. At the completion of the surveillance the SCRE must immediatelv review the results of this test for compliance to Tech Spec requirements.
- 9. l_F a component fails to perform or falls to meet Tech. Spec.
requirements, THEN:
- a. Notifv Shift Engineer.
O Q b. Complete Section H.2 of Attachment A. H. PERFORMANCE ACCEPTANCE CRITERIA 1, Each Automatic Pressure Relief Valve is manually opened and closed as verified by a compensating Turbine Bypass Valve or Control Valve closure.(C-1)
- 1. PROCEDURE I )
NOTE All checks, data, initials, reviews, and approvals are performed on Attachment A. [ }
- 1. Verify and record that all prerequisites are met.
- 2. Test Setup:
- a. Record initial Torus temperatures from TORUS H2O TEMP, V i(2)-1602-8 on panel 901(2)-21.
O h b. Record Reactor Pressure from RX PRESS, 1(2)-263 156 on panel 901(2)-3. 2 ; ; ,' a
')COS 203- 3 l UNIT 1(2)
REVISION O
- c. Record start time of relief valve testing on recorder VLV LEAK AND CNTMT AIR TEMP, 1(2)-260 20 on panel 901(2)-21.
- d. . Record start time of relier valve testing on recorder TURBINE SPEED AND VLV POSITION, 1(2)-5640-62 on panel 901(2)-7
- e. Open approximately one and one. half (1.5) Bypass Valves by:
(1) J.F Turbine on line, THEN use LOAD SET. (2) IF Turbine NOT on line, THEN use PRESSURE SET. [ ] NOTE The following steps will test each valve individually and will be repeated for the remaining relief valves. Valve numbers are designated as 203-XX where XX represents the specific valve number as shown in Attachment A. , The indicating lights at the valve switches do E n'ecessarily indicate actual valve position. The lights for 203 3A indicate air pressure to the operator which should operate the valve and the lights for the remaining valves indicate solenoid valve position on the valve operator. Relief valves may be tested in any order OR only some of the relief valves may be tested. [ ] [ ] NOTE In order to minimize the time that the relief valve is actually open the performance of the following valve test will require the coordinated actions of several personnel. The following designations for personnel is recommended: a, Operator at panel 901(2)-3 to control start of test, operate relief valve key switch and monitor indicating lights.
- b. Panel 901(2)-7, TURBINE SPEED AND VLV POSITION recorder 1(2)'.
5640-2 to monitor and record Bypass Valve postion.
- c. Panel 901(2)-21, VLV LEAK AND CNTMT AIR TEMP recorder 1(2)-
260 20 A,ND SAFETY / RELIEF VLV ACOUSTIC MONITORS to monttor and record relief valve discharge temperatures and monitor and operate-Acoustic Monitors. [
- O 2257a 4-
1
-OCOS 203-3 UNIT 1(2)
REVISION O
?O M '3, Relief Valve.203-XX temperature recording at 1(2)-260-20:
- a. IF recorder is NOT in MANUAL SCR0LLING OR'is NOT setup to
. monitor the-Relief Valves only. LHM place recorder in single
= scan for relief valve to be tested by:
(1) Open front cover'of recorder 1(2)-260-20 at panel 901(2)-21-to allow access to keyboard. (2) Press key H at keybcard. (3) MANUAL SCROLLING will show on Left display and NO will show on Right display. (4)- Press NEXT to show YES on right display. (5) Press ENTER to use MANUAL SCROLLING, (6): -With + and - keys move 10# monitored to the 10# for the. Relief Valve ~ to be tested as shown on Attachment A.
-b. Record initial relief valve discharge temperature, 4,- Record Bypass Valve' percent (%) open indication from recorder -W 1(2)-5640-62, TURBINE SPEED AND VALVE POSITION.
U (' ) NOTE Data In the next step must be taken rapidly, becau3e the valve will only be. held =open a short time. I . . 3
- 5. _ Place-key switch for-A05 RELIEF VLV,'l(2)-203-XX to MANUAL for one / q second to'open 1(2)-203-XX AR perform:
a; Verify-and record OPEN indication for-1(2)-203-XX at-valve / switch with_swltch in MANUAL. ab. Verify and record percent (%) bypass valve; position at recorder j' 1(2)-5640-62, TURBINE SPEED AND VLV. POSITION =at'901(2)-7
- c. Verify and record that temperature rises for 1(2)-203-XX on' recorder VLV LEAK AND CNTMT AIR TEMP,-l(2)-260-20 on panel v 90)(2)-21.
~
- d. Verify and record OPEN (red)-AJ MEMORY (yellow) indication for 1(2)-203-XX cn SAFETY / RELIEF VLV ACOUSTIC HONITORS on panel '
901(2)-21,
- 6. Return key _5witen to AUTO AND verify the following:
l
- a. Verify and record CLOSE Indication for 1(2)-203-xx at valve switen.
.2257a . -
OCOS 203-3 UNIT 1(2) REVISION O
- b. E testing 1(2)-203-3B O_R 1(2)-203-3C, THEN verifv and record O
INHIBIT light is ON for approximately 10 seconos after valve closure,
- c. Verifv and recoro percent (*.) bypass valve position at recorder TURBINE SPEED AND VLV POSITION, 1(2)-5640-62 on panel 901(2)-7.
- d. Verify and recora that temperature decreases for 1(2)-203-XX on recorder VLV LEAK AND CNTMT AIR TEMP, 1(2)-260-20 on panel 901(2)-21.
- e. Verifv and record CLOSED (green) indication for 1(2)-203-XX on SAFETY / RELIEF VLV ACQUSTIC MONITORS on panel 901(2)-21.
- f. Reset MEMORf light for 1(2)-203-XX on SAFETY / RELIEF VLV ACOUSTIC MONITORS on panel 901(2)-21 by momentarily placing toggle switch to RESET.
- 7. Verify and record Relief Valve 1(2)-203-XX satisfactory operation;
- a. WHEN relief valve is opened, THEN bypass valves close.
- b. WHEN relief valve is closed, THEN bypass valves open.
- 8. WHEN Bypass Valves have stabilized, THEN perform steps !.3 thru I,7 for the next relief valve to be tested (refer to Attachment A).
- 9. Return LOAD SET or PRESSURE REGULATOR to normal.
- 10. Record any Relief Valve testing descrepancies,
- 11. Record final Torus temperatures from TORUS H2O TEMP, 1(2)-1602-8 on panel 90)(2)-21
- 12. Record completion time of relief valve testing on recoraer VLV LEAK '
AND CNTMT AIR TEMP, 112)-260-20 on panel 901(2)-21.
- 13. Record completion time of relief valve testing on recorder TURBINE SPEED AND VLV POSITION, 1(2) 5540-62 on panel 901(2)-7.
- 14. Observe and rec'ord relief valve temperatures return to near normal on recorder VLV LEAK AND CNiMT AIR TEMP, 1(2)-260-20 on panel 901(2)-21 with MANUAL SCROLLING function of recorder indication.
- 15. E desired to monitor channels in tutomatic at the recorder, THEN:
- a. Press H key at recorder.
- b. Press nEXT key to bypass MANUAL SCROLLING.
- c. Press ENTER. Verify SEQUENCE LENGTH in left display-
- d. Press the number corresponding to tne number of channels to De monitored (1-32) AJ ENTER.
2257a - _ _ _ - _ - _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ __ __. _ . _ _ _ ___ _. _ _ _ _ _ _ _ _ _ _ _ _ _
QCOS 203-3 UNIT l(2) REVISION O V.O
- e. As each number is snown on the left display type in the cceresporaing !D# for t*e channels to be displayed and ENTER, 16, Obtain a new sample for venting requirements for Dry ell and Sup;tession Chamber,
- 17. Independentiv verif v the following key switches on panel 901(2)-3 are in AUTO:
- a. ADS RELIEF VLV, 1(2)-203-3A
- b. ADS RELIEF VLV, 1(2)-203-3B
- c. ADS RELIEF VLV, 1(2)-203-3C a, A05 RELIEF VLV, 1(2)-203-30 e, ADS RELIEF VLV, 1(2)-203-3E 18, (( this surveillance was satisfactory, THEN comolete section H 1 of Attachment A, 19, (( this surveiliance was unsatisfactory, THEN initiate the following as Decessary:
7~
- a. Nuclear Work Recuests.
b, Deviation Event Report,
- c. (( two relief valves are inoperable, THEN initiate Automatic Pressure Reitef Valve (s) Outage Report, QCOS 203-4, d, 1[ Target Rock relief valve, 1(2)-203-3A, is inoperable, THEN initiate Safety Valve Inoperable Outage Reoort, QCOS 203-5, e, IF acoustic monitor and/or temperature monitor is inoperaple, TEEN refer to Post Accident Monitoring Instrumentation Outage Report. 005 1600-05,
- f. Complete section H.2 of Attachment A.
- 20. Attach this completed surveillance to 005 005-59, Operations Semi-Annual Surveillance Test Assignment Sheet OR to the appropriate Outage Report.
J. ATTACHMENTS 1 Attacheent A, Automatic Pressure Relief Valve Test Data Sheet. 3 (V 2257a <
QCOS 203-3 UNIT 1(2) REVISION O ATTACHMENT A O AUTOMATIC PRESSURS RELIEF VALVE OPERABILITY TEST DATA SHEET E. PRERE0'JISITES
- 1. The shift Enginecr has comoleted the following:
- a. UNIT 5/n1
- b. Reason for test:
Check the appropriate for purpose of test: ( Normal Surveillance ( ) Post Maintenance ( ) Partial ( ) Other
- c. Permission to start test:
aw SE Signature Date/ Time
- 2. The Unit is off EGC control. ([
- 3. Copy of QCOA 203-1 available. ( O
- 4. Venting of Drywell and/or Torus secured. ( K)
- 5. TORUS H2O TEMP Recorder, 1(2)-1602-8 operating. ( A)
I. PROCEDURE STEP NO. . l 2.a. Initial Torus temperature: Red Pen Black Pen . 8~> Y I- l 2.b. Reactor Pressure: /Bo f psig 1 l l 9ll 2257a
-Oco$ 203-3 UNIT 1(2) etVI$10N 0
~
ATT ACHwf NT A f tent 'd) INITIAL IN THE BLANKS BELOW FOR THE SUCCt$$FUL COMPLET!ON OF (ACH SftP 203-3A 203-38 203 3C 203-30 203-3t INITIAL REL!tF Ihk TEMP (3.e.($)) / fi. / /hh 3 1931 l99
'E!!!of[4,3 . / h'I ' ,/G7 ,/G / , /6 7 ,/G1 REL!tF QPEN
( d' c ( /) INDICATION ($.a.) ( vf - ( V) (V) ' 5 0 $ b.) 032- . 0 0' .uG 7 C6 E ,O O ttL!tF VALyt TEMPtRATUR! INCREA$t$(5.c.) ( [) (/) ( /) ( ) ( /) ACQUSTIC MONITOR V AL VE OP E N .A.,KQ - (M MEMORY LIGHTS ( $.d. ) ..(. d
. ( /) ( V -) ( )
REL!tF CLO$to , ( /) f INDICATION (6.4.) ( /) (/ ( /) ( v') REL!tF, INHIBIT -& A ON A80VT 10 $tc, NA etD O NA NA (6.b.)
- $ ON 6.C.) #! ! ' !b / b'
- 4 REL![F VALVE- -
TEMPERATURE DECREA$t$(6.d.)- (t/)' ( V) ( ) ( Vj ( #') ACQUSTIC MON! TOR / VALVE CLO$t0(6.e.) - . ( /) ' ( v) ( /) (d ( )
'( ( V)
~
Rt$ti MEMORY LIGHT
-(6.f.)
) _( /)' (/ ( /) - '
( /) ( [)
~
VALVE PAS $(7.)~ .( ( (
- 9. LOAD SET or_ PRES $URE REGULATOR to normal.
/
- 10. Record discrepancies;
-/f/0)V L i 11 . Final forus. temperature; Red Pen B1A ct Pen, 3 '7.
~
' Q( 4
- 14. Relief valve temperatures return to normal. -
- 16. Sample Drywell for venting recuirements.
'17 Independently verify following relief valve switenes to AUT0:
D; !N!f!AL INITIAL 1(21-203-3A w' l(2) 201-38 _. l 1(21-203-3C 1(2)-203-30
'1(21-203 3t 22$74 l
OC05 203-3 UNIT 1(2) REVISION O A TTC",ttNT A (Cont ' d ) O H. REVIEW AND APPROVAL
- 1. ACCEPTANCE CRITERIA SATISFIED
- a. Survelllance performec' by: *ve / / 5-7-9/
V Signat e Date
- b. Surveillance reviewed by: ,// d /
SCRE Signature Date
- c. Surveillance approved by: Mk /
SE Signature Date Comments: ll/u V L
- 2. ACCEPTANCE CRITERIA NOT SATISFIED
- a. Description of Deficiencies / Comments: /u h
- b. Surveillance performed by AND Nuclear Work Request (NWR) initiated:
(1) NWR initiated: YES NO
/
Signature Date
- c. Surveillance reviewed by, DVR initiated (T.S. LCO only):
(1) DVR initiated: YES NO
/
SCRE Signaturi" Date
- d. Surveillance approved by @ appropriate Outage Report initiated:
(1) Automatic Pressure Relief Valve (s) Outage Report initiated, QCOS 203-4: YES NO (2) Safety Valve Inoperable Outage Report initiated. QC05 203-5: YES NO (3) Post Accident Monitoring Instrumentation Outage Report initiated. 005 1600-05: YES NO
/
SE Signature Date (final) ; 22S7a 10- l l
Simulator O do dener Tost Procoduro Covor Shoet Test Number dos 250-/ PTAO-105T1 O Date Performed //' /2-70 O Test Description ggjy [zgggg g,47,,z y gyjg ggggng fyggy7ngt,(j,, 75g7-DIscrepancles section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date O V Test Results I 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after-correction of above discrepancies. ;
l i Retest Complete Date Test Complete Date [l-l200 SFCC Acceptance / / Date 3 ~/ #/ [ Simulator Supervisor's Acc ptance [X / 5~.- Date 88-9/ c.e.w ne-n n n-e e ,
- QOS 250-1 Revision 10 October 1988 MSIV CLOSURE MONTHLY SCRAM SENSOR FUNCTIONAL TEST S.R.
A. PURPOSE-
.The purpose of this procedure 15 to outline the method used.to perform the monthly scram sensor functional test on the MSIV's.
B. REFERENCES
- 1. None; D. PREREQUISITES-
- 1. All MSIVs are open_and operable.
- 2. All Group _1 PCI initiation signals are clear and fuses intact.
D. PRECAUTIONS I
- 1. Due-to the installation of Modification M.-4-1(2)-86-32, it will :
f take approximately 30-seconds for the MAIN STEAM ISOLATilN VALVE to reach 10 percent closure using the MAIN STEAM ISOLATION VALVE test switch. However, if the MAIN STEAM ISOLATION VALVE test-switch is , continuously held in the test position or the valve test circuit yd. limit switch falls to ooen, the MAIN STEAM ISOLATION VALVE will
. continue to close beyond 10% closure and. continue until it reaches the full closed position, This can result in a reactor scram from high pressure If reactor power.15-above approximately 75%.
Therefore,1when satisfactory test results are obtained or to abort the test, operate the ISOLATION' VALVE TEST switch to the OPEN
. position to assure that the-test seal-in circuit.ls reset. This duplicates the automatic action of the valve test circuit limit switch._
- 2. Perform the-steps of this procedure In-strict order to prevent an inadvertent-scram.
E. LIMITATIONS AND ACTIONS-l _1, There are no power: restrictions for the performance ~of this test.
- 2. If reactor power is less than:200MWe, verify proper operation of' the valve test circuit limit switch. -This is accomplished by NOT- O
_ operating _the-! SOLATION VALVE TEST switch to the OPEN posttion.and verifying that the valve-returns to its full OPEN position automa t i ca l _l y. L 3. This test is to-be performed by initiating only one ISOL VALVE TEST i SWITCH at a time. NOV.T $88 l 10/0291q Q.C.O.S.R L l_ = .-
005 250 1 Revision 10
- 4. This test shall be performed monthly in accordance with the requirements of Technical Specification Table 4.1. (TS) g
- 5. Ints test snould not be performed with the nit operating in EGC or automatic flow control. If the unit is operating In EGC, contact the Load Olspatcher and trip EGC and return the unit to n.anual flow control F. PROCEDURE
- 1. If the reactor MODE switch is in SHUT 00xN, REFUEL, OR STARTUP/ HOT STANDBY, perform tne following. If the reactor H00E salten is in RUN proceed to Step F.2., 00 NOT perform these steps.
- a. OPEN MSIVs.
- b. Block closed the following relays on 901-15 (902 '5):
(1) 590 101A. l (2) 590-101C.
- c. Block closed the following relays on 901-17 (902-17):
(1) 590-1018. (2) 590-1010. h
- d. Remove the following fuses on 901-15 (902-15):
(1) Fuse 712A (TB-A; F-24). (2) Fuse 712C (TB-E; F 24). l e. Remove the following fuses on 901-17 (902-17): 1 (1) Fuse 7128 (TB-A; F-24). (2) Fuse 7120 (TB-E; F-24).
- 2. On 901-15 (902-15), remove fuse 590-702C (TB-A; F-21).
l
- 3. Verify that relay 590-1020 on 901-17 (902-17) is still energized, CAUTION Oo not hold the test switch in the test position as it will cause full closure of the MSIV. Full closure of the MSIV may cause an inadvertent scram.
^?PROVi3 g I ':'l O ^ Dc6 10/0291q "C0SC
_ . _ _ . _ _ . . . _ _ _ . _ . . . _ . ~_ _ _ . . _ . ___ .. _ . _ _ ._. _ Q0S 250-1 Revision 10 4 Immediately following satisfactory test results or to abort the test, operate ISOLATION VALVE TEST switch to the OPEN position.
- 5. ~Using the ISOLATION VALVE TEST switch, partially CLOSE MSIV 203-1A on 901-3 (902-3). _ Verify _that H5!V 203-1A has partially closed causing.an RPS' channel trip and alarming MAIN STEAM ! SOLATION VALVE NOT FULL CPEN.
- 6. Verify that MSIV 203-1A has f'lly u re-opened.
-7, RESET the RPS channel t-lo and alarm.
- 8. Immediately following satisfactory test results or to abort the test, operate ISOLATION VALVE TEST switch to the OPEN posttion,
- 9. Using the ISOLATION VALVE TEST switch, partially CLOSE MSIV 203-2A on 901-3 (902-3). . Verify that MSIV 203-2A has partially closed causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT FULL OPEN.
- 10. Verify that MSIV 203-2A has fully re-opened.
-11. RESET the RPS channel trip and alarm.
12; Replace _ fuse 590-702C (TB-A F-21), 901-15 (902-15).
- 13. Verify that relays 590-102A thru H are picked up.
14 Remove fuse 590-702A (TB-A; F-3), 901-15 (902-15). l
.15 Verify _that relay 590-102H on 901-17 (902-17) is still energized.
- 16. .!mmediately following satisfactory test results or to abort the- -
Ltest, operate ISOLATION VALVE TEST switch to-tne OPEN position;
- 17. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV.203-1B on 901-3-(902-3). Verify that MSIV 203-18 has partially closed causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT FULL OPEN.
- 18. Verify that'MSIV 203-18 has-ful.ly re-opened.
'19. RESET--the RPS channel trip.
20; Immediately following satisfactory test results or to abort the test, operate ISOLATION VALVE TEST switch to the OPEN position,
- 21. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV 203-28 on 901-3 (902-3). Verify that MSIV 203-2B has partially closed causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT FULL OPEN. ,; ppgyL iJ.J, C 'Ud8 C0SF 10/0291q . . , . - - . - .. _ ., . -- - . - . - . - . - . -- . . . . -..- -
005 250-1 Revision 10
- 22. Verify that MSIV 203-2B has fully re-opened, g.
- 23. RESET the RPS channel trip and alarm.
- 24. Replace fuse 590-702A (TB-A; F-3), 401-15 (902-15).
- 25. Verify that relays 590-lC2A thru H are picked up.
- 26. Remove fuse 590-702G (T3-E; F-21), 901 15 (902-15).
- 27. Verify that relay 590-1028 on 901-17 (902-17) is still energized.
- 28. Immediately following satisfactory test results or to abort the test, operats ISOLATION VALVE TEST switti to the OPEN position.
- 29. Using the ISOLATION VALVE TEST switch partially CLOSE HSIV 203-lC l on 901-3 (902-3). Verify that MSIV 203-IC has partially closed l causing an RPS channel trio and alarming MAIN STEAM ISOLATION VALVE l NOT FULL OPEN.
- 30. Verify that MSIV 203-lC has fully re-opened, 31, RESET the RPS channel trip and alarm.
l 32, Immediately following satisfactory test results or to acort the test, operate ISOLATION V;,LVE TEST switch to the OPEN position.
- 33. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV 203-2C on 901-3 (902-3). Verify toit MSIV 203-2C has partially closed I causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE l NOT FULL OPEN.
- 34. Verify that MSIV 203-2C has fully re-opened.
RESET the RPS channel trip and alarm.
~
35.
- 36. Replace fuse 590-702G (TB-E; F-21), 901-15 (902-15).
- 37. Verify tnat relays 590-102A thru H are picked up.
- 38. Remove fuse 590-702E (TB-E; F-3), 901-15 (902-15).
- 39. Verify that relay 590-102F on 901-17 (902-17) is still energized.
- 40. Immediately following satisfactory test results or to abort the test, operate ISOLATION VALVE TEST switch to the OPEN position,
- 41. Using the ISOLATION VALVE TEST switch, partially CLOSE MSIV 203-10 on 901-3 (902-3). Verify that MSIV 203-10 has partially closed .
causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE l 42. NOT FULL OPEN. Verify that MSIV 203-10 fully re-opened.
/J PHO V L g' E0iW Ed8 10/0291q OC0SR
.- . - - . . ~ - - . - - - . - . . . . - . . - - . . . - - - . - . - .
00S 250-1 Revision 10
- 43. . RESET the RPS channel trip and alarm. -
Immediately following-satisfactory test results or to abort the
~
44, test, operate ISOLATION VALVE TEST switch to the OPEN position.
- 45. Partially CLOSE with the ISOLATION VALVE TEST switch MSIV 203-20 on 901-3 (902-3). Verify that MSIV 203-20 has partially closed causing an RPS chaMe1 trip and alarming MAIN STEAM ISOLATION VALVE
, NOT FULL OPEN.
- 46. Verify that MSIV 203-20 has fully re-opened.
- 47. . RESET the RPS~ channel trip and alarm.
- 48. Replace fuse 590-702E (TB-E; F-3), 901-15 (902-15).
- 49. Verify that relays 590-102A thru H are picked up.
- 50. Remove fuse 590-7020 (TS-A; F-21), 901-17 (902-17).
- 51. Verify that relay 590-102C on 901-15 (902-15) is still energized.
i 52. Immediately following satisfactory test results or to abort the test, operate ISOLATION VALVE TEST. switch to the OPEN position.
- 53. Usina the. ISOLATION VALVE TEST switch partially CLOSE MSIV 203-!A O'- cr. 901-3 (902-3). Verify tnat MSIV 203-1 A has partially closed causing an RPS channel' trip and alarming MAIN STEAM ISOLATION VALVE NOT FULL OPEN.
- 54. Ver'fy that MSIV 203 1A has fully re-opened.
55, RESET the RPS-channel trio and alarm.
- 56. _! mediately following satisfactory test results or to abort tne test, ooerate ISOLATION VALVE TEST switch to the OPEN position.
'57. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV 203-2A' on 901-3_-(902-3). Verify that MSIV 203-2A has partially' closed causing.an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT. FULL ~OPEN.
5 8 .- Verify that MSIV 203-2A has fully re-opened.
-59. RESET the RPS channel trip and alarm.-- n. PkOVis
[' Replace fuse 590-7020 (TB-A; E-21), 901-17 (902-17).
- 60. ' fl o' g g
- 61. Verify that relays 590-102A thru H are picked up, rc0gc
- 62. Remove fuse 590-7028 (TB-A; F-3), 901-17 (902-17).
! 63. Verify that relay 590-102G on 901-15 (902-15) is still energized. 10/0291q - - - -- _ - - .- - -- - --
005 250-1 Revision 10 64 Immediately folic.ing satisfactory test results or to abort the test, operate ISOLATION VALVE TEST switch to the OPEN position.
- 65. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV 203 1C on 901-2 (902-3). Verify that MSIV 203-lC has partially closed causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT FULL OPEN.
- 66. Verify that MSIV 203-lC ;.as fully re-opened.
- 67. RESET the RPS channel trip and alarm.
- 68. Immediately following satisfactory test results or to abort tne test, operate ISOLATION VALVE TEST switch to the OPEN position.
- 69. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV 203-2C on 901-3 (902-3). Verify that MSIV 203-2C has partially closed i
causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT FULL OPEN. l
- 70. Verify that MSIV 203-2C has fully re-opened.
l 71. RESET the RPS channel trip and alarm.
- 72. Replace fuse 590-702B (TB-A; F-3). 901-17 (902-17).
- 73. Verify that relays 590-102A thru H are picked up.
- 74. Remove fuse 590-702H (TB-E; F-22), 901-17 (902-17).
- 75. Verify that relay S90-102A on 901-15 (902-15) is still energi:ed.
- 76. Immediately following satisfactory test results or to abort tne
! test. operate ISOLATION VALVE TEST switch to the OPEN position.
- 77. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV 203 1B on 901-3 (902-3). Verify that MSIV 203-1B has partially closed causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE I NOT FULL OPEN.
- 78. Verify that MSIV 203-1B has fully re-opened.
- 79. RESET the RPS channel trip and alarm.
l l 80. Immediately following si.tisf actory test results or to abort the l test. operate ISOLATION VALVE TEST switch to the OPEN position.
- 81. Using the ISOLATION VALVE TEST switch partially CLOSE MSIV 203-28 on 901-3 (902-3). Verify that MSIV 203-28 has partially closed causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT FULL OPEN.
- 82. Verify that MSIV 203-2B has fully re-opened.
l
.H ,dl 10/0291q -
n; - l
,q, QOS 250-1 Revision 10 N 83. RESET-the RPS channel trip-and alarm, S4. Replace fuse 590-702H (TB-E; F-22),=901-17 (902-17).
- 85. Verify that relays 590-102A thru H are picked up.
- 86. Remove fuse 590-702F (TB-E; F-3), 901-17 (902-17).
8 7 .- Verify that relay'590-102E on 901-15.(902-15) is still energized.
- 88. Immediately following satisfactory test results or to abort the
-test, operate ISOLATION VALVE TEST switch to the OPEN position. -
- 89. Using tne ISOLATION VALVE TEST switch partially CLOSE MSIV 203-10
-on 901-3 (902-3). Verify that MSIV 203-10 has partially closed causing an RPS channel trip and alarming MAIN STEAM ISOLATION VALVE NOT. FULL OPEN,
- 90. Verify that MSIV 203-10 has ful'ly re-opened.
- 91. RESET the RPS channel trip and alarm.
- 92. Immediately following satisfactory test results or to abort the test, operate: ISOLATION VALVE TEST switch to the OPEN position.
- 93. Using:the ISOLATION VALVE TEST switch partiall_y CLOSE HSIV 203-20
=%- .on 901-3-(902-3). ~ Verify that MSIV 203-20 has partially closed causing-an RPS channel-trio and alarming MAIN STEAM ISOLATION VALVE NOT FULL 0 PEN.
- 94. Verify that MSIV-203-20 has. fully re-opened.
._95. , RESET the RPS channel-trip and alarm.
96.. . Replace fuse 590-702F-(TB-E; F-3)',-901-17-(902-17),
- 97. -Verify that relays- 590-102A-thru_H are-picked up, s -98. -If the reactor MODE swltch_is.in SHUT 00HN, REFUEL, or STARTUP/ HOT STANOBY, pet f orm the:following. 'If the reactor MODE switch-is th RUNL proceed to step F,99, 00.NOT perform this step.
la. Install-the following fuses on-901-15-(902-15).
- ( l )-- 590-712A (TB-A; F-24),
(2) 590-712C (TB-E; F-24).
- b. Install the following fuses on 901-17 (902-17).
(1) 590-7128 (TB-A; F-24). (2)- 590-7120 (TB-E; F-24), i PROVc-F.J! OI 3 OLC 0 S P
QOS 250 1 Revision 10
- c. Remove the relay blocks from the following relays on 901-15 (902-15).
(1) 590-101A, (2) 590-101C.
- d. Remove the relay blocks from the following relays on 901-17 (902-17).
(1) 590-1018. (2) 590-1010.
- e. CLOSE the MSIVs if reautred.
- 99. Verify the system is returned to normal.
100. Record the test results on 005 250-51. 101. Report any system discrepancies to the Shift Engineer. If one or both RPS trip channels are inoperable, refer to Tech Spec Table 3.1-3. QOS 500-01 should be filled out,
- a. If one or more HSIVs do not cause a 1/2 scram for one trip channel, a 1/2 scram must be manually taken for that channel,
- b. If one or more HSIVs do not cause a 1/2 scram for both trip channels, either all control rods must be inserted within 4 hours, or the MS!Vs must be closed within 8 hours.
G. CHECKLISTS
- 1. 005 250-51, Main Steamline Valve Closure (Operations Monthly).
- 2. 005 500-01, RPS Instr mentation Outage Report.
H. TECHNICAL SPECIFICATION REFERENCES
- 1. Table 4.1-1$
- 2. Table 3.1-3, RPS Instrumentation Requirements in the RUN mode.
- 3. Notes 2A and 2C in Table 3.1-4.
'
- ht O v e ,
l' . A" {jy (final) G C. O. s a . 10/0291q l
. . . . - . - . . - - . - . ~ , - . - - - - . - . - - - - - - . . - - - . . - - . - _ . . - .
--005 250-51 Revision 2 f t. MAIN'STEAMLINE ISOLATION VALVE February 1988' 1
J e CLOSURE =(OPERATIONS MONTHLY)
-UNIT- SMUUTo f fu~l.Y {
lb I2 ')0 OATE OPERATOR' I N/(fWf0
. SHIFT ENGINEER N/A
*).,- Open MSIVs. M/A -
-* 2a.- Block in relays on panel 901-15(902-15) 590-101A WA 590-101C a/A S 42b.LBlock_inrelaysonpanel 901-17(902-17) 590-101B b/4 i 590-1010 4/4
*2c. Remove-fuses on panel 901-15(902-15) . 590-712A TB"A"F M/A 590-712C .TB"E"F-24 N/A L
- 2 d .- Remove fuses on panel 901-17(902-1)) ~ 590-7128 'TB"A"F-24 A/A
'590-712d TB"E"F-24 M/A
".emove fuse 590-702C (panel 901-15(902-15) TB"AF-21
- 3. .
/ lid Verify that relay 590-1020 is-still-energized. -
PARTIALLY
-. VALVE - :-CLOSE - RPS CHANNEL OPEN RESET **
TRIP' NUMBER- -VALVE- ALARM = .VLV' RPS 203-1A; M ffM /fM - N1 4 ' 2032A: YM ; (fM ' p 4 dh-
-Install fuse 590-702C and' verify 590-102A?thru H picked up. -j -
4.- " Remove. fuse 590-702A'(panel 901-15(902-15) TB"A"F-3) #6 Verify that relay. 590-102 Hits still energized. MP1 i
'203'-18: I
[ M fn P-203i2B- IM T M -/G4 M
- Install fuse 590-702A and verify 590-102A thru H picked up. M O APPROVED 24/0521q APR 041988
- O.C. O. S R.
9 9 9 l 1 l
005 250-51 Revision 2 C
- 5. Remove fuse 590-702G (panel 901-15(902-15) fB"E"F-21) d
()T Verify that relay 590-102B Is still energized. _ 'I'1 PARTIALLY VALVE CLOSE RPS CHANNEL OPEN RESET" NUMBER VALVE . ALARM TRIP VLV RPS 203-tC /h [rf b dE d 203-2C iti M Tf1 $1 Install fuse 590-702G and verify 590-102A thru H picked up. 'D7
- 6. Remove fuse 590-702E (panel 901-15(902-15) TB"E"F-3) ij Verify that relay 590-102F is still energized. /fst 203-10 '
S, '0 k /ftt 203-2D 'ifA dki f $_ /$1 Install fuse 590-702E and verify 590-102A thru H picked up. M
- 7. Remove fuse 590-7020 (panel 901-17(902-17) TB"A"F-21 TH Verify that relay 590-102C is still energized, h 203-1A b M /
M efiq 203-2A '91 /nf /C1 /@i install fuse 590-7020 and verify 590-102A thru H picked up. /f71
- 8. Remove fuse 590-702B (panel 901-17(902-17) TB"A"F-3) it Verify that relay 590-102G is sti11 energized. 'fil 203-lC b 4 M 41 203-2C MI $1 'fM /1s'
/$1 Install fuse 590-702B and verify 590-102A thru H picked up, 41
- 9. Remove fuse 590-702H (panel 901-17(902-17) TB"E"F-22) /Irl Verify that relay 590-102A is still energized. M
! 203-18 [M 4 d / 81 % l 203-28 I /fPl 4 <$1 ///, O x, / Install fuse 590-702H and verify 590-102A thru H picked up. 45 APPROVED i 24/05214 l APR 041983 0cosa
QOS 250-51 Revision 2 m 10. Remove fuse 590-702F (panel 901-17(902-17) TB"E"F-3) 'I t Verify that relay 590-102E is still energized. St PARTIAlt.Y VALVE CLOSE RPS CHANNEL OPEN RESET ** NUMBER VALVE ALARM TRIP VLV RPS 203-10 'b 5 $ 'b il 203-20 4' 4 dM 'M
#A Install fuse 590-702F and verify 590-102A thru H picked up, if
*11. Install fuses 590-712A, B, C, O d/N
*12, Remove block for relays 590-101A, B, C, O d[4 __
*13. All fuses and relays returned to normal, k/
*14 Close MSIVs. d/k
- 15. Verify system is returried to normal. TM
- 16. Report any system discrepancies to the Shift Engineer. N/A
/7
(/ Items 1, 2a, b, c, d,11,12,13, and 16 se required LF the reactor mode selector switch is in the shutdown, refsfl, or start-up positions to remove g
" CONDENSER LOW VACUUM MAIN STEAM LINE '.50LATION VALVE CLOSURE BYPASS" +
Do not continue with test unles: QPS is reset. Independent verification of operability status following test: 0fp Ml} Control Room DATE Test procedure: QOS 250-1. APPROVED l f %PR 0 41958
)
(final) 0.C 0 S R 24/0521q Simulator d/u Cmer Tost Procoduro Cover Sheet Test Number los 7oo-/ PT AO-105T1 O d Test Date Performed //-/2-90 D e s c ri ptio n Sgsg pg7,g7g ,g7 y g7, g,,, ,y g 7 ,,, f p g , gg,cz FedartcN'd 7ksv Discrepancies Occuan . of Test Discrepancy Corrected e item # Oomments Requiring Report # (initials) Retest and Date O Test Results
/ 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.-
- 3. Tests results UNSATISFACTORY. Retest the above after" correction of above discrepancies. s Retest Complete Date Test Complete [ a Date #-/2-70 O '
f f SFCC Acceptance / . . e/ Date 3 7 7 [ Simulator Supervis r's cceptance / A Date J-7-9/
/
C.E.CO, 66-1215 12*89
005 700-1 Reviticn 4 7 , SRM DETECTOR Not IN STARTUP POS! TION Marct, 1969 ( ROD BLOCK FUNCTIONAL TEST S.R. A. puR.o0SE s The purpcte of this procedure is to outline the method to functioMlly test the SRM detector not in startup position rod block. B. REFERENCES
- 1. None, l
C. PRERE0V! SITES
- 1. Verify CR0 overhaul platform is locked in place.
O. PRECAUTIONS
- 1. None.
E. LIMITATIONS AND ACTIONS
- 1. The SRM detector not in startup position functional test shall be completed prior to startup or weekly. This test is not required when SRM's are not required to be operable. (i.e. at power operation). This procedure need not be performed when the Rx mode a switch is in " SHUT 00HN" or "RUN".
F. BOCEDURE
- 1. Insert all SRM detectors to the " FULL-IN" position.
- 2. Withdraw SRM channel (21) detector.
- 3. Observe " ROD OUT PERMlf" light goes out.
- 4. Ot, serve "R00 OUT BLOCK" alarm annunciates.
- 5. Insert SRM channel (21) detector to the " FULL-IN" position.
- 6. Observe "R00 OUT PERMIT" light comes on.
- 7. Clear " ROD OUT BLOCK" alarm.
- 8. Repeat steps "2" through "7" for SRM channel 22, 23, and 24,
- 9. Record test results on data sheet 005 700-51.
- 10. Report any discrepancies to the Shift Engineer.
APPROVED a f)
/4PR 2 61989 24/05184 Q.C.O.S.R.
005 700-1 Revision 4 G. CHECKLISTS
- 1. CCS 700-51,
- 2. 005 005 52; operator's Weekiy Surveillance Test Assignment Sheet.
H. TECHN!LAL SPECIFICAi!ON REFERENCE] 1, 4.2.C.
- 2. Table 4.2.1.
O s APPROVEDg (rinal) IJR 2 61989 24/05180 O.C.O.S.R.
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3- ! Simulator $wo Omes l Test Procedure Cover Sheet Test Number aos 7oo-e P T A O-105T1 ! th Test Date Performed /N2Oo l D e s c t ip t io n fyf 35,7,37,, ,g7 g, ,7p,7p ,,,,,77,4 gg , g(, (, 1
.FhfC77cWAL TEST 4
1 i
- j. Discrepancies section of Test Discrepancy Corrected i Item # Comments Requiring Report # (initials)
Retest and Dato i 1
- O 1 Test Results
- 1. Test Completed Satisfactorily
! 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary. 1 i
- .3. Tests results UNSATISFACTORY. Retest the above after
correction of above discrepancies. l Retest Complete Date 1 Test Com@e Yekh Date ll-l200 SFCC Acceptance - Date 3 7 #ll Simulator Superviso s Acc ance (Auv Date 8-[-9/ e.t.co. ee n n nn C
1 005 700-3 Revision i O
!RM DETECTOR NOT IN STARTUP March 1989 :
Pos! TION ROD BLOCK FUNCTIONAL TEST S.R. A. PURPOSE The purpose of this procedure is to outline the method used to test the IRM detector not in startup position rod block. B. REFERENCES
- 1. None.
C. PREREQUISITES
- 1. Verify CR0 overhaul platform is locked in place.
D. PRECAUTIONS
- 1. None E. LiH!TATIONS AND ACTIONS
- 1. This functional test shall be performed prior to startup or weekly. This test need not be completed when IRM's are not required to be operable (i.e. at power operation). This procedure need not be performed when the Rx mode switch is in " SHUTDOWN" or O "RUN".
F. PROCEDURE
- 1. Insert all IRM detectors to the " FULL-IN" position.
- 2. Withdraw IRM channel (11) detector.
- 3. Observe " ROD OUT PERMIT" light goes out.
- 4. Observe " ROD OUT BLOCK" alarm annunciates.
- 5. Insert IRM channel (11) detector to the " FULL-IN" position.
- 6. Observe "ROO 007 PERMIT"-light comes on.
- 7. Clear " ROD OUT Bl.0CK" alarm,
- 8. Repeat steps F.2. through F.7. for IRM channels 12 through 18.
- 9. Record test results on data sheet 00S 700-S3.
- 10. -Report.any discrepancies to the Shift Engineer.
AFPROVED I.PR 2 61989 - 4/00764 O C.O.S.R.
.C
CCS 700-3 Revisien 5 G. CHECKLISTS
- 1. Data Sheet 005 700-53,
- 2. 005 005-52; operations Weekly Surveillance test Assignment Sheet.
H. TICHNICAL SPECIFICATION REFERENCES
- 1. Section 4.2.C.
- 2. Table 4.2.1.
O
^
,FPROVE$
utnai) /JR 2 61989 4N6q Q.C.O.S.R.
O O O i t i UNIT 7 M u/J fb C h4- h 00S 700-53 DATE ((-2 ')0 Revision 3 ' OPERAi0R S t1A((gf6 Isarch 1967 SHIFT ENGINEER 8J/A ' lits DETECTOR NOT IN START-UP POSITION R00 BLOCK FlPICTIONAL TEST i (OPERATIONS PRIOR TO START-UP/WEEKI.Y " REFUEL". START-UP/ HOT STANDBY) i I Ilti CHAf8EL II 12 13 34 15 16 IT 18 !
- l. Insert all liti Detectors to the j " FULL-IN" position. 'fil dQ /{ ' [gf r
k rfrt dk
- 2. Withdraw one detector at a time. di ([M /[d fjf r4 y E 7p <fn
[
- a. Observe " ROD OUT BLOCK" alarm / ),
annunciates. hi i4 ihf f(f dN @ ' 't? h
- b. " ROD OUT PERMIT" goes out. 'h' ih h k jrL 'i?! N. Tit I
- 3. Insert the detector to the " FULL-lM' e y c g position. $' M I/I iff h '!if '!p '((f -
- a. "R00 OUT PEleftT" light comes on. 'IG ffit .th $f th d){ /777 k r
- b. " ROD OUT BLOCK" alarm clears. 'iii iht /[M @' /h /
_Th g ___ 'ff!
- 4. Report any discrepancaes to the Shift
. Engineer. I i TEST PROCEDURE: 00S 700-3 i p p,,in n'i D 4!'l. ",e ljy/ i l t> 4'. O S i< (final) 16/0440g .- - - - ---- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Simulator dya; dme [ Test Procoduro Cover Shoet 7c,, sum 3,, aos 7oo-a ! PTAO-105T1 j O T est oate Pe"ormed '-'e- 9 / D e s c r l p t i o n ggg pg,,7 3,g,ggg g,pyy,y,g,, gy (gg,77,g GoS '700-G 4 ? l Discrepancies Section of Test Discrepancy Corrected ! Item # Comments Requiring Report # (6nitials) Retest and Date l O i I Test Results
- 1. Test Ccmpleted Satisfactorily.
- 2. After correction of the above discrepancies, test
- results are satisfactoy. Retest is NOT necessary.
1
- 3. Tests results UNSATISFACTORY. Retest the above after, correction of above discrepancies.
Retest Complete Date
/ *M Test . Complete Date I-8-7/
l O SgCC Acce,tance KM6py -
,. De,e s.,.gr Simulator Supervisor's Ac eptance ~ Date J-/-9/
- C.E.00. Goal 2tn 12=60
& ,a
005 700-6 p Revision 7 APRM HIGH FLUX (HEAT BALANCE) September 1985 Q CALIBRATION TEST S.R. A. PURPOSE The purpose of this procedure is to outline the method used to calibrate the APRM's by heat balance. B. REFERENCES
- 1. None.
C. PREREQUI5ITES
- 1. None.
D. P_RECAUTIONS
- 1. If power is changed during this test the results may not be valid and the test should be repeated when power is stabilized.
E. LIMITATIONS AND ACTIONS 1. This calibration test shall be completed once every seven (7) days.
- 2. If the process computer is not available or it is suspected that
(" the heat balance determined by the process corrputer is not correct, i notify a nuclear engineer. F. PROCEDURE
- 1. Five minutes prior to test performance, stabilize power by the following:
- a. If the Unit is in AUTOMATIC LOAD CONTROL, notify the lead dispatcher and remove the unit from AUTOMATIC LOAD CONTROL during this test,
- b. Avoid control rod movement or flow increases during this test.
- 2. Calculation of present core thermal power.
- a. Demand program OD-5 (Process Computer Thermal Power). i (1) Determine percent rated power by dividing core thermal power by 2511 (rounded off to the nearest %).
- 3. Fill out the data portion of QOS 700-57.
J A D P R O V I ! O r = i 10/0285q ^^05;.
005 700-6 Revision 7 4. Corrective action for out Calibration of APRM's. (h (v) a. If any of the APRM readings deviate greater than 2% from the percent Core thermal power, notify the shift engineer,
- b. Hold power level constant,
- c. The shift engineer verifles (initials) the APRM calibration and notifies the nuclear engineer to coordinate recalibration of the APRMs per Q15 1512-1.
- d. Subsequent to recalibration, read the APRMs and recora results, e
Upon successful APRM calibration, the shift engineer verifies (initials) the APRMs are properly adjusted and routes tne heat balance to the operating engineer. G. CHECKLISTS 1. QOS 005-52, Operations Weekly Surveillance Test Assignment Sheet. '
- 2. QOS 700-57 for corrputer calculation method.
H. TECHNICAL SPECIFICATION REFERENCES
- 1. Table 4.1.2.
O APPRO'.'I;
; n- .- -
N v+7 .; l (final) 10/02850 0CDS
UNIT OM Mef, QOS 700 S7 DATE/TlHE //fr Revision 4
; OPERATOR -
February 198 N SHIFT ENGINEER ID/15L APM HEAT BAIANCE COMPLTER CALCULATION
- 1. If the Unit ts operating in AUTOMATIC LOAD CONTROL, notify the Load Dispatcher and remove the Unit from EGC for the duration of this test.
- 2. Process computer OD $ core thermal power in MWt. h49794 !
- 3. Percent of rated thermal power (rounded of f to the nearest %). 39
- 4. Visually average each APM channel (nearest %).
Panel 901-37(902-37). 1 912 99 3 3 f' 4 ?9 f 5 $f 8 6 O? 9 (, . i
- 5. If APM readings deviate greater than + 2% from the percent core thetmal power, notify the shift engineer and proceed as follows:
- a. Shif t Engineer notification of APM's out of calibration.
- 6. Shift Ecgineer notification to Nuclear Engineer.
( a. Hold power level constant.
- b. APM's recalibrated.
- c. Record percent of rated thermal power. %
- d. Visually average each APRM channel (panel 901-37(902-37)) to the '
nearest %. 1 95' 2 M 3 C P 4 "79 $ __ N 5~ 6 fb'
- e. Verify each APM ta within t, 2% of the percent core thermal power.
(1) Nuclear Engineer (2) Shift Engineer Test Procedure: QOS 700-6
/ APPRoya a c/,. ! /m/ /
I t/ // s /c)/ A // n.,,/',% j cig/ p g ,,,-
<h ' ~
. AT p ,W L
~
(final) ,lC 0 a?
.i.
l l
Simulator QuAb 0mes Test Procedure Covor Sheet Test Number o n /ooo-/ l PTAO-105T1 Oo Description gpg gg g oate eer<ormee a " *' 7 Discrepancies Section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date O~ Test Results k 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after-correction of above discrepancies.
Retest Complete Date l Test Complete ,1 - f Date 2 .!!' 9L SFCC Acceptance _
.b/ ' Date ? / 9 /
Simulator Supervis 's ceptance /2 a2.~~- Date 8f-9/ c.c.co, e e.i r n ir.es
) 005 1000-1 Revision 12
\ LPCI FLOW RATE TEST February 1988 S.R.
A. PURPOSE The ourDose cf this procedure is to outline the method used to verify the LPCI Flow Rate Requirements. B. REFERENCES 1.- None.
-C. PREREQUISITES
- 1. Verify that the RHR Discharge Piping is filled and vented prior-to performing the Flow Rate Test.
D. PRECAUTIONS
- 1. Maintain RHR service water pressure equal to or greater than 20 psig higher than RHR primary pressure.
- 2. Notify personnel, in the vicinity of active components, of the impending test.
- 3. An operator should be present when starting major pieces of equipment.
4 Repeated starts and/or jogs of induction motors greatly reduce the life of the winding insulation. The heat produced by each acceleration or jog is much more than that produced and dissipated by the motor under full load. E. LIMITATIONS AND ACTIONS
- 1. Once every three months or after pump maintenance, verify that two RHRS pumps deliver at least 9000 GPM against a system head corresponding to a reactor vessel pressure of 20 PSIG with one minimum flow valve open. To ensure Technical Specification 4.5.A 3. is met; pressure must be 1 130 PSIG'as recorded'on QOS 1000.SI (TS).
- 2. During performance of this surveillance an operator should visually inspect for leakage of RHR piping, pumps and valves. Work requests should be inttlated as deemed appropriate.
F. PROCEDURE I
- 1. Establish RHR service water. flow through the RHR heat exchangers.
Verify the following valve positions: O a. (1) VALVES 1001-1A, B, C. and 0 - open. (2) VALVES 1001-3A, B, C, and 0 - open. W 0"> E 2/0058q 0A0 y
Q05 1000-1 Revision 12 (3) H0-1001-4A And B - open. (4) MO-1001-185A and B - open. (5) 40-1001-186A and B - closed. (6) HO-1001-187A and B - closed. (7) VALVE 1/2-1099 closed. l (8) VALVE 1/2-1099-1B - closed.
- b. OPEN VALVES HO-1001-5A and SB to approximately 50% open.
- c. START RHR service water pumps 1001-65A or 8 and 1001-65C or D, i
- 2. Verify the following RHR system valve positions.
- a. HO-1001-7A, B, C and 0 - coen,
- b. VALVES 1001-66A, B, C, and 0 - open,
- c. VALVES 1001-15A and B - open.
- d. HO-1001-16A and B - open.
- e. VALVES 1001-17A and B - open. g
- f. HO-1001-19A and B - open.
- 3. Establish RHR loop flow (suppression pool to suppression pool),
- a. OPEN VALVE HO-1001-34A and HO-1001-348.
NOTE If the RHR system pressure, as maintained by the jockey pump, drops off to zero when the HO-1001-34A/348 is OPENE0, the MO-1001-36A/368 or 37A/370 may be leaking through to the torus. This will cause the RHR piping to drain and create a water hammer when the RHR pump is started. APPROVED M AY 0 31988 9 2/0058q Q.C.O.SR.
i 005 1000-I . Revision 12 I I (~ b. If the RHR system pressure drops to zero, CLOSE the (S~,) H0-1001-34A/348 valve and vent the RHR loop piping as the jockey pump refills the system. When normal pressure is again restored, perform the OPENING of MO-1001-34A/348 in rapid succession with the next step of this procedure, so as to get the RHR pump ruf.ning without creating a water hammer in the piping. Because of the long stroke time of the 40-1001-34A/348 valve, it is necessary to a110w the valve to OPEN partially before rapidly proceeding to the next step of this procedure,
- c. If it is determined that a valve may be leaking through, write a work request to repair the valve.
4 Verify flow through the A loop using the A division pumps (A and B RHR pumps). NOTE Past experience has shown that unnecessary water hammer may be avoided if the HO-1001-36A valve is started open at the same time the RHR pump is started. This precludes the opening of the minimum flow, HO-1001-18A valve, and prevents unnecessary pressure (m) surges in the containment spray piping. LJ
- a. START the "A" RHR pump, and at the same time, OPEN valve MO-1001-36A. Throttle valve H0-1001-36A to establish an approximate 130 psig inlet pressure to the heat exchanger as indicated on the 901-3 (902-3) panel,
- b. START "B" RHR pump and throttle the HO-1001-36A valve to maintain an approximate 130 psig inlet pressure to the heat exchanger as indicated on the 901-3 (902-3) panel,
- c. Throttle the HO-1001-36A valve to establish an RHR flow of 9000 gpm as indicated by FR-1040-7 located on panel 901-3(902-3). Record the total flow on data sheet QOS 1000-51.
- d. Record RHR pump discharge pressures as indicated locally on P! 1001-71A and 71B on data sheet QOS 1000-51. Verify that the average pump discharge pressure is greater than that Indicated on QOS 1000-S1.
- 5. Verify flow through the B loop using the A division pumps (A and S RHR pumps) going through the cross-tic. This is the limiting case because the HO-1001-18A valve remains open.
i
- a. OPEN valve HO-1001-368.
APPROVED O) ( . l b, CLOSE valve MO-1001-36A. 1 M AY 0 3 G88 ! 2/00584 0. C. O S R.
005 1000-1 Revision 12 1
- c. Throttle valve MO-1001-36B to establish an RHR flow of 9000 gpm as indicated on FR 1040-7 and verify valve HO-1001-18A is OPEN. Record the flow through the B 1000 and h
verification of valve HO-1001-18A OPEN on data sheet 005 1000-51.
- d. Record the RHR discharge pressures as indicated locally on P! 1001-71A and PI 1001-71B, on data sheet QOS 1000-51.
- e. STOP the A RHR pump and the B RHR pump,
- f. CLOSE valve HO-1001-368.
- g. CLOSE valve H0-1001-18A.
- 6. Verify flow through the B loop using the B division pumps (C and 0 RHR pumps).
N0fE Past experience has shown that unnecessary water hammer may be avoided if the H0-1001-360 valve is started open at the same time the RHR pump is started. This precludes the opening of the minimum flow valve, H0-1001-188, and prevents unnecessary pressure surges in the contaminated g spray piping,
- a. START the C RHR pump, ano at the same time, OPEN valve HO-1001-36B. Throttle valve HO-1001-368 to establish an approximate 130 psig inlet pressure to the heat exchanger as indicated on the 901-3(902-3) panel,
- b. START the O RHR pump and throttle the MO-1001-36B valve to maintain an approximate 130 psig inlet pressure to the heat exchanger as indicated on the 901-3(902-3) panel.
- c. Throttle the HO-1001-36B valve to establish an RHR flow of 9000 gpm as indicated from FR 1040-7 located on panel 901-3(902-3). Record tne flow on data sheet 005 1000-SI.
- d. Record RHR pump discharge pressures as indicated locally on P! 1001-71C and 1001-710 on data sheet 005 1000-51. Verify that the discharge pressure is greater than indicated on 005 1000-51,
- 7. Verify flow through the A loop using the B division pumps (C and 0 RHR pumps) going through the cross-tie. This is the limiting case because the HO-1001-188 valve remains open,
- a. OPEN valve MO-1001-36A.
APPROVED g
- b. CLOSE valve HO-1001-368. MAY 031968 2/00584 -a- !
- 0. C. O. S. R.
CCS 1000 1 Revision 12
- c. THROTTLt valve MO-1001-36A to establish an RHR flow of O 9000 gpm as indicated on FR 1040-7 and verify valve MO-1001-16B is OPEN. Record the flow through the B 1000 and verification of valve MO-1001-1BB OPEN on data sheet 005 1000 51.
- d. Record the RHR discharge pressures as indicated locally on P! 1001 71C and P! 1001 710 on data tr. set 005 1000-51.
-e. STOP the C RHR pump and the D RHR pump.
- f. CLOSE S 1001-36A.
g .- CLOSE O 1001-188.
- 8. CLOSE MO-1001-34A and 348.
- 9. STOP the RHR service water pumps, 1001 65A or 65B and 65C or 650, that are running. Verify valves MO-1001-5A and MO-1001-5B are closed.
- 10. Upon test-completion, verify the RHR and RHR service water systems
-are returned to normal in accordance with the valve line-up specified in step F.1. of QOP 1000-1.
. Reference 00P 1000-15.
- 11. Verify all necessary data is-recorded on checklist (CS 1000-51.
- 12. If two RHRS pumps do not deliver at least 9000 gem against a system head corresponding to a reactor vessel pressure of 20 psig with one minimum flow valve open, refer to 005 1000-02, RHR$/LPCI Mode Outage Report.
- 13. If an RHR pump is inoperable, refer to QOS 1000-01, One RHR Pump
'Out-of-Service Outage Report.
G. CHECKLISTS
- 1. QOS 1000-51, RHRS/LPCI Flow Rate Test Data Sheet H. TECHNICAL SPECIFICATION REFERENCES
- 1. Section-4.5.A.3.
- 2. Section 3.5.A 4/5.
- 3. Section 4.5.A.4/5.
APPROVED O .m (final) 0.C.O.S R. 2/00584 _ _ _ _ _ - _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _
005 1000-51 Revision 11 RHR/LPCI FLOW RATE TEST DATA SHEET September 1989 (OPERATIONS QUARTERLY) UNIT 9,*u t
- 4-w IK-L)
DATE 2_1L 9L OPERATOR R Or&fd 9 SHIFT ENGINEER N '* 4
- 1. RHR discharge piping filled and vented. 4
(!nitial) Flow recorded from FR 1040-7.
- 2. Flow into the A loop using A division pumps m
,P, ymg Pressure (osta)
A-1002 71 A., I A' ' I ( tn#"*' 'W ' B-1002 718 10tAl- Average Pressure . J /O psig 1 130 psig Total Flow 9000 * (gpm) O 3. Flow into the 8 loop using A division pumps
-M Pressure (osta) j A-1002 71A / e l B-1002 718 kcal Average Pressure . /5'o psig 1 130 psig Total-F1ow- t1vuu * (gpm)- )-
MO-1001-18A CPEN A- (Initial)
- 4. Flow into the B loop using 8 division pumps M Pressure (osto)
C-1002 71C l h I bod u d '* TFN ' 0-1002 710 fac+l Average Pressure . Epsig 1 130 psig Total Flow 9(%'d * (gpm) l
- 5. Flow into the A loop using B division pumps Pumo Pressure (osto) {r C-1002 71C /ve^l .
0-1002 710 /ved( ' Average Pressure . /W psig 1 130 psig g Total Flow 100 # * (gpm) HO-1001-18B OPEN /h (Initial) O- APPROVED 3/0068q APR 0 91990 Q.C.O.S.R. l
005 1000-$1 Revision 11 4 6. Roset ECCS fill system alarm. -4 (Initial)
- 7. RHR system returned to normal. 4 ~
(Initial) !
- 8. Visual leakage inspection performed. (/vod
(!nitial) Independent verification of operability status following test: Control Room / - <- f. Date / 11 91 hSignature O l
- Two RHR pumps shall deliver at least 9000 GPM against a system head corresponding to a reactor vessel pressure of 20 PSIG with one minimum flow valve open. Tech Spec 4.5.A 3. is met by ensuring average pressure 2,130 psig. The 130 psig limit takes l static and dynamic head losses into account.
Report any discrepancies to the Shift Engineer and refer to Tech Spec-Section 3.5.A.4/5 and 4.5.4/5. Nb (!nitial) TEST PROCEDURE: 005 1000-1 h (final) APPROVED
- APR 0 91990 3/00601 Q.C.O.S.R.
j Simulator C/Bo O ncs _
; Test Procedure Cover Sheet Test Number dos /ooo-f
- PTAO-105T1 O Test oete eer<ermee 2~ o 1 <
D e s c ri p t io n gy,, gg, peg gg7gg ,,,,gy, pz,,, ,,,7g 7 g ,7 g g of' gat??oNc EVst'V 30 D/Vs Discrepsneles section of Test Discrepancy Corrected Comments
!!em # Requiring Report # (initials)
Retest and Date 1 O Test Results h( 1. Test Completeri Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after correction of above discrepancies.
Retest Complete Date l Test Complete- / < -r ,6/ 7 Date 1 ~7 7/ SFCC Acceptance s ~' - /1 Date 3 -7 P [ Simulator Superviso s A eptance /A Date J-[(-9/ c.c.ca, n n a n se u___ . _ _
l 005 1000--
, Revision 16 RHR SERVICE WATER PUMP February 1990
( S.R, FLOW RATE TESTING OPERAi!ONS - EVERY 90 DAYS A. PURPOSE The purpose of this procedure is to outline the steps necessary to perform RHR service water purr; and valve operability testing required by the 19 service Testing Program. B. REFERENCES
- 1. QAP 350-1, Administration of the Inservice Testing Program.
- 2. Inservice Testing Program.
C. PRERE0VISITES
- 1. Contact appropriate personriel for vibration testing.
- 2. Obtain data sheet 005 1000 54 from the Shift Engineer, l D. PRECAUTIONS
- 1. An operator should be pretent when starting major pieces of equipment.
O r
- 2. Notify personnel, in the vicinity of active components, of the impending tests,.
- 3. Repeated starts and/or jogs of induction motors greatly reduce the life of the winding insulation, the heat produced by each acceleration or jog is'much more than that produced and dissipated by the motor under full load.
- 4. In the event of inadequate heat transfer across the RHR heat exchanger or inadequate RHR service water flow, consideration
, should be given to biofouling of the heat exchanger as the possible cause, If this appears to be the case, take the RHR service water pumps off and reverse flow in the heat exchanger and then see if the situation-improves. (OPEX 84-26) E. LIMITATIONS AND ACTIONS
- 1. Once every 90 days or af ter pump mairtenance, demonstrate that each RHR service water pump delivers 3500 gpm against a pump discharge pressure of 198 psig. (TS)
- 2. During performance of this surveillance an operator should visually inspect for leakage from RHR service water piping, pumps, and valves. Work requests should be initiated as appropriate.
O APPROVED 5/01400 1- AUG 2 31990 l- Q.C.O.S.R.-
005 1000 4 Revision 16
- 3. Acceptable flow rate resuits demorstrate cperability of valves &
1001-2A, B, C, and O. W
- 4. The vibration velocity measurement sna11 ce performed when test quantities have been achieved. Pump driver readings may be taken at this time. Pump readings shall be taken after a minimum of 5 minutes run tirre using approved quality assured instrumentation.
- 5. Pump performance will be evaluated as specified in reference B.I.
- 6. HO-1001-4A, B and HO-1001-185A, B are cycled under this procedure to satisfy EQ cycling requirements.
F. PROCEDURE NOTE Two pumps can be run at the same time provided that each pump is on a separate loop.
- 1. VERIFY that the tested pump oil levels are at an acceptable level and initial 005 1000-54
- 2. If testing "A" loop RHR service water pumps, proceed to Step F.3, if testing "B" loop RHR service water pumps, proceed to Step F.19.
- 3. VERIFY the following valve positions with 5-lock log book or by control roce indication:
- a. VALVE 1001-1A/B - open,
- b. VALVE 1001-3A/B (Position as per S-lock log).
- c. VALVE 1/2-1099 closec.
- d. VALVE 1/2-1099-1B - closed.
- e. HD 1001-4A -ckhk/ closed (depending on which direction the flow is in the heat exchanger).
- f. H0 1001-185A fo 3 / closed (depending on which direction the flow is in the'h~e T exchanger).
- g. H01001-186A-kosd)open(dependingonwhichdirectionthe flow is in the heat exchanger).
- h. HO 1001-187A - clo open (depending on which direction the flow is in the heat exchanger),
APPROVED 5/0140q AUG 2 3 W Q .C.O.S.R.
CCS 1000-.: Revision 16 ( '} 4. CYCLE the following valves one full 5trote: 'wJ
- a. MO 1001-4A.
- b. MO 1001-185A.
- 5. RECORD Static Inlet pressure as indicated locally by PI's IOO1-160A/B on Q05 1000-54.
- 6. OPEN valve H0 1001-5A to approximately 50% open.-
- 7. START the RHR Service Water pump 1001-65A/B.
- 8. VERIFY fans for room cooler 5745A/B START and initial 005 1000-54.
- 9. CHECK service water radiation monitor 1705-12 on panel 901-2(902-2). If monitor spikes abnormally, trip tne pump and inform the Shift Engineer.
- 10. Technical Specifications requires a minimum flow rate of 3500 GPM at a discharge pressure of > 198 psig as indicated by FI 1040-1A on panel 901-3(902-3) and locaT indicator P! 1001-77A/B, VERIFY this requirement is met by performing the following:
- a. THROTTLE H0 1001-5A to achieve a pump flow rate of 3500 GPM as indicated by FI 1040-1A and RECORD the corresponding discharge (qj pressure as indicated locally by PI 1001-77A/B on Initial the appropriate space on 005 1000-S4 QOS 1000-S4.
according to whether the pump achieves 3500 gpm at a discharge pressure of 1 198 psig or not.
- b. Acceptable Tech. Spec. Flow Rates and Discharge Pressures verifies the following:
(1) If running the "A" pump, the 1001-2A is fully OPEN and the 1001-2B is fully CLOSED. (2) If running the "B" pump, the 1001-2B is fully OPEN and the 1001-2A is fully CLOSED.
- 11. RECORD the following data on QOS 1000-54 (one data sheet for each /
pumo),
- a. Pump Running Inlet Pressure (P1) as indicated locally by -
PI 1001-160A/B.
- 12. Calculate the required Discharge Pressure (Pd) from equation:
Pd 290 psid + Pi. (q) APPROVED l AUG 2 31990 5/01400 ) O.C.O.S.R.
005 1000-4 Revision 16
- 13. THROTTLE H0 1001-5A to acnieve the discharge pressure (Pd) as calculated in step f.12 and indicated locally by PI 1001-77A/5 I 14 RECORD the adjusted Discharge Pressure (Pd) on 035 1000-54.
' NOTE Symetrical damping devices or l averaging techniques may be used to reduce instrument fluctuations to within 27. of the observed reading.
Hydraulic instruments may be damped by using gage snubbers or by throttling small valves in the instrument lines. If throttling small valves is used, , the operator shall alternately open I
- clost the valve several times to
.1fy unobstructed pressure communication while observing the instrument reading.
- 15. If 5 minutes has elapsed since the pump has started, RECORD the following data on 005 1000-S4. If not, wait until the 5 minutes has passed before recording data. (The waiting period is not required for pump driver vibration readings.)
- a. RHR heat exchanger outlet pressure as indicated by PI 1040-3A on panel 901-3 (902-3).
- b. Pump flow rate (Q) as indicated by FI 1040-1A on panel 901-3 (902-3).
- c. Vibratio. amplitudes as reported by the vibration testers.
- 16. Unless it is desireo to leave the RHR service water pump on, STOP the 1001-65A/B pump.
- 17. VERIFY the M0 1001-5A valve closes.
18, If testing "A" loop RHR service water pumps, return to Step F.3, if testing "B" loop RHR service water pun.ps, proceed to Step F.19. If all testing is complete proceed to step F.35.
- 19. VER!fY the following valve positions with S-lock log bcok or by control room indication:
- a. VALVE 1001-IC/D - open.
- b. VALVE 1001-3C/D (Position as per S-lock log).
- c. VALVE 1/2-1099 closed.
APPROVED 5/0140q 4- M23m O.C.O.S.R.
005 1000 4 4 Revision 16 i
- d. VALVE 1/2-1099-1B - closed.
- e. MO 1001-4B - open/:losed (depencing on which cirection ene flow is in the heat exchanger). ,
- f. 'HO 1001-185B - open/ closed (depending on which strection the flow is in the heat exchanger).
- g. MO 1001-186B - closed /open (depending en which direction the flow is in the heat exchanger),
- h. HO 1001-187B - closed /open (depending on which direction the flow is in the heat exebanger).
-20. CYCLE the following valves one full stroke:
- a. MO 1001-4B. /
- b. MO 1001-185B.
- 21. RECORD Static Inlet Pressure as indicated locally by PI's 1001-160C/D on 005 1000-S4
- 22. OPEN valve MO 1001-5B to approximately 50% open.
- 23. START the RHR Servics Water pump 1001-65C/0.
- 24. VERIFY: fans for room cooler 5745C/D START and initial 005 1000-54,
- 25. CHECK service water radiation monitor 1705-12 on panel ',
901-2(902-2). If monitor spikes abnormally, trip the purnp and inform the Shift Engineer.
- 26. Technical Specifications recuires a minimum flow rate of 3500 GPM at a discharge pressure of > 198 psig as indicated by FI 1040-1B on ,
panel 901-3(902-3) and locaT indicator PI 1001-77C/0. VERIFY this ' requirement is met by performing the following:
- a. THROTTLE HO 1001-5B to achieve a pump flow rate of 3500 GPM as indicated by FI 1040-1B and RECORD the corresponding discharge pressure as indicated locally by PI 1001-77C/0 on 005 1000-54.- Initial the accropriate space on 005 1000-54 according to whether the_pumn achieves 3500 gpm at.a discharge pressure of y,198 psig or no:.
- b. Acceptable lech. Spec. flow Rates and Discharge Pressures verifies the following:
(1) If running the "C" pump, the 1001-2C is fully OPEN and the 1001-20 is fully CLOSED. O APPROVED AVG 2 31990 5/090q Q.C.O.S.R.
1 CC5 1000-4 l Revisien 16 l (2) If running the 0" ourrp, tne 1001-2D 15 fully CPEN an;f & T the 1001-2C is fully CLOSED.
- 27. RECORD the following cata on 005 1000-54 (one data sheet for each pump).
- a. Pume Running Inlet Pressure (Pi) as indicated locally by PI 1001-160C/0.
- 28. Calculate the reautred Discharge Pressure (Pd) from eovation:
Pd 290 psid + Pl.
- 29. THROTTLE H0 1001-5B to achieve the discharge pressure (Pd) as calculated in step F.28 and indicated locally by P! 1001-77C/0.
- 30. RECORD the adjusted Discharge Pressure (Pd) on QOS 1000-54.
NOTE Symmetrical damping devices or averaging techniques may be used to rcJuce instrument fluctuations to L within 2% of the observed reading. Hydraulic instruments may be damped by using gage snubbers or by throttling small valves in the instrument lines, if throttling small valves is used, the operator shall alternately open and close the valve several times to verify unobstrt:ted pressure communication while observing the instrument readirg,
- 31. If 5 minutes has elapsed since the pump has started. RECORD the i following data on 005 1000-54. If not, wait until the 5 minutes has passed before recording data. (The waiting period is not required for pump driver vibration readings.)
- a. RHR heat exchanger outlet pressere as indicated by PI 1040-3B on panel 901-3 (902-3).
- b. Pump flow rate (Q) as indicated by FI 1040-1B on panel 901 3 (902-3).
- c. Vibration amolitudes as reported by the vibration testers.
- 32. Unless it is desired to leave the RHR service water pump on, STOP the 1001-65C/0 pumo.
- 33. VERIFY the M0 1001-5B valve closes.
APPROVED 5/0140q NC 2 3 N Q.C.O.S.R.
1
}
005 1001 4 Revision 16 O '
- 34. If testing "A" loop RHR service water pumps, return to $tep F.3, if testing "B" 1000 RHR service water pumps, return to Step i.19. If all testing is :omplete proceed to :tep F.35. l
- 35. VERIFY that all of the necessary data is recorded on data sheet j 005 1000-54
- 36. NOTIFY the Shift Engineer of any indications that the RHR service water pumps or associated auxiliary equipment may be less than i fully operable. '
- 37. If an RHR service water pump is inoperable, refer to 005 1000-04, One RHRS Service Water Pump Outage Report.
- 38. If two RHR service water pumps are inoperable in the same containment cooling loop, refer to 005 1000-05, RHRS Containment Cooling System Loop Outage Report.
G. CHECKI,ISTS
- 1. 005 1000-54, RHR Service Water Pump Flow Rate Testing Data Sheet.
H. TECHNICAL SPECIFICATION REFERENCES
- 1. Sections 3.5.B./4.5.B.
V T' ( APPROVED (final) hug 2 31990 5/0140a # Q.C.O.S.R.
i RHR SERVICE WATER PUMP FLOWRATE 005 1000-54 TESTING OATA SHEET Revision 14 February 1990 , UNIT $ t m u.l cob r PUMP # N^ OATE /h reA 9 /4 # 7 REASON FOR TEST: OPERATOR 12 6fdDD/ ' 7 Routine Quarterly
- Post-Maintenance TEST PROCEDURE: 00$ 1000-4 Alert Range Testing Establishing Reference Values PRETEST CHECKLIST Verify that pump-oll level is normal ,[ [N'U (Initials) (F.1)
HO-1001-4A/B and HO-1001-185A/B cycled properly Mr i (Initials) (F.4/F.20) RHR Service Water Pump Vault Cooler Fans OPERABLE: W /0 4 (Initials) (F.8/F.24) TECHNICAL SPECIFICATION RE0VIREMENTS tech. Spec. reautres a minimum flow rate (Q) of 2 3500 gpm and a discharge O- pressure (P ) of 1 198 psig. Initial the following where applicable. (F.10/F.26)d DISCHARGE PRESSURE (Pd ) FLOM RATE (Q) ACCEPTANCE CR!iERIA
/vc ec r-4% pstg 3500 gpm 2 198 psig at 3500 gpn The data taken at a flow rate of 3500 gpm fulfills the Tech. Spec. -requirements.
/IT~
Operator's initials (N/A if not applicable) The Tech. Spec. requirements of > - and 1 198 psig has NOT been met." 3500 Nd Operator's Initials 4 (N/A if not applicable) O APPROVED 24/0132n gg g 3 g Q,C.O.S.R.
005 1000-54 Revision 14 c ,,,, ,,,, g PUMP TEST DATA PARAMETER MEASURED Pump Inlet Pressure Static z o m (- (Prior to Pump = Start) PSIG (F.5/F.21) (locally) (P! 1001-160 A/B/C/0) - Pump Inlet Pressure (P1) L ##" (During Test) PSIG (F.11/F.27e (locally) (PI 1001-160 A/B/C/0) Differential
, ressure (P -P') 290 PSI d
(Set at-290 psLd) 4
. Pump Discharge
.l
- Pressure (P ) PSIG-
, (F.14/F.30)d (locally) (PI 1001-77. y yo,yz A/B/C/0) . Pump Flow Rate (0) . 3 iOO GPM ( F .15. blF . 31,' b ) - (90X-3 (FI 1040-3A/B) canel)' RHR Ht Exchanger Outlet Pressure /# PSIG (F.15.a/F.31.a) (90X-3)' (PI 1001-3A/B) canel) I h APPROVED-
-24/01329 ~ Q.C.O.S.R.
QOS 1000-S4 ! Revision 14 p-VfB4ATION TESTING (F.15;c/F.31.c) d VIBRATION TEST OATT MEASURE IN/SEC [ l POINTS APPROVED AUG231990 2 H Q.C.O.S.R. ,
~v i
A t 3 H ' v i A 4 H ! V A 5 _H ! v A 6 H i V i f.% i t _ _ _ ._ . sum .= 5 em ,e n .w a eN 4 in\ ! 3 . 4 $ I
- 2. I 4
-.9! 4 a /'
, p,., - i a N
. ,$ ,~
"LDi~ ,L .- 1
-W-
% f [.
),:G.
f._.;a -s'a ;
' i I f11= O /h
[,.;- f; ;
'I --
i These vibration points could be on either side, depending on accessibility. P6cton ectforming vibration testing (NAME) ( Vibration im trument 0.A. number /next cal, date ( / Vibration Accelerometer Q A. number /next cal dste /
;4/0132G .
RHR SERVICE HATER PUMP FLOHRATE 005 1000-S4 17 TESTING DATA SHEET Revision 14 February 1990 (v) , UNIT ,_5 ( PUMP # h DATE 3.D - 9 / REASON FOR TEST: OPERATOR l2 b/~d M 2 Routine Quarterly
- Post-Maintenance TEST PRM.; DURE: 00S 1000-4 Alert Range Testing Establishing Reference Values PRETESTCHECKLISJ Verify that pump oil level is normal M / h (Initials) (F.1)
MO-1001-4A/B and M0-1001-185A/B cycled properly d (Initials) (F.4/F.20) RHR Service Hater Pump Vault Cvoler Fans OPERABLE: A W 8 (Initials) (F.8/F.24) TECHNICAL SPECIFICATION REQUIREMENTS
,, Tech. Spec requires a minimum flow rate (Q) of 1 3F00 gpm and a discharge i pressure (P ) of 2 198 psig. Initial the following where applicable.
lV (F.10/F.26)d DISCHARGE PRESSURE (Pd ) FLOH RATE (Q) ACCEPTANCE CRITERIA psig 3500 gpm 2 198 psig at 3500 gpm The data taken at a flow rate of 3500 gpm A-( fulfills the Tech. Spec. requirements. Ope' rat 6r 's ini t i a l s (N/A if not applicable) The Tech. Spec requirements of > 3500 gpm and 2 198 psig har 7 been met.
~
k[f.~ Operator's initials (N/A if not applicable) O V APPROVED 24/0132q jg p 3 jggg Q.C.O.S.R.
i005 1000-54 Revision'14 TEST DATA PUMP TEST DATA PARAMETER MEASURED Pump Inlet Pressure Static fp - (Prior to-- I Pump Start) PSIG i (F.5/F.21) (locally) (PI 1001-160 A/B/C/D) Pump Inlet f) Pressure (P1) l vW (During Test) PSIG (F.11/F.27) (locally) i-(PI 1001-160 A/B/C/0)- , Otfferential . . Pressure (Pd -P') '290 PSI , ; (Set at 290 ps d)
;= a
, Pump 01scharge
- . : -- Pressure.(Pd ) PSIG b" (F.14/F.30) (locall (PI11001-77 A/B/C/0) l## -
Pump Flow Rate.(Q) 3b# GPH ( F .15.' b / F . 31. b ) (90X-3 (FI'1040-3A/8)- panel) : RHR Ht Exchanger Outlet Pressure /#/OPSIG- 4 (F.15.a/F.31.a) :(90X-3) (PI~1001-3A/B) canel)-
~!
-1 3
i h . APPROVED
-24/0132q Q.C.O.S.R.
00S 1000-54 Revision 14
- 4 b' /
- [*g 9 (J I VIBRATION TESTING (F.15.c/F.31.c) gvw 2 f VIBRATION TEST DATA V MEASURE IN/SEC POINTS APPROVED
, AUG 2 31990 l
^ !
2 Q.C.O.S.R. V A 3 H v A 4 H v : A 5 H v A 6 H
~
v g w. . - w q _._...._.._...._.__J Y 3 nb , 6 b 5 I 2. 7 -9 q fil ,h/ ,
. rt .m_._
% _+g tri . .. i .-.uf
( I t .
' '. l
/ *V b J._.4,hl]
.< ' a - 1 I.l V v/ E i
'i : , .
These vibration. points could be on either side, depending on accessibility. Derson performing vibration testing (NAME) O U Vibration instrument Q.A. number /next cat. date ___
/
Vibration Accelerometer Q.A. number /next cal, date / 24/0132q ,
l
- RHR-SERVICE WATER PUMP FLOWRATE 005 1000-54 TESTING DATA SHEET Revision 14 fl February 1990 ,
UNIT $ / tit u. c / PUMP #- b DATE' 3 7-7/ REASON FOR TEST: OPERATOR N. b#itT) DY '
. g Routine Quarterly
~~ Post-Maintenance TEST PROCEDURE: 00S 1000-4 Alert Range Testing Establishing Reference Values
-=
PJETEST CHECKLIST Verify that pump otl level is normal #f (Initials) (F.1) L MO-1001-4A/B and HO-1001-185A/B cycled properly (Initials) (F.4/F.20) RHR Service Water Pump Vault Cooler Fans OPERABLEi/#/I(Initials) (F.8/F.24)
~~ ~
-TECHNICAL SPECIFICAT10N' REQUIREMENTS
- -T.ech. Spec. requires a' minimum flow-rate (0) 6f 1 3500'gpm and a discharge r
., p. essure-(P ) Of 2 198 osig. Initial the following where applicable.
s (F.10/F.26)d i DISCHARGE-PRESSURE (P )d_ FLOH RATE (Q) ACCEPTANCE CRITERIA. psig .3500 gpm 2 198 psig at 3500 gpm The-data.taken at a flow rate of 3500 gpm fulfills-the~ Tech... Spec. requirements.. M-Operat'of s Initials
.N/A
( if not applicable) 1 The Tech.' Spec. requirements of > 3500 gpm
-and 2 198 psig has NOT been met."
. Nk Operator's Initials (N/A if_not appl _1 cable)
O APPROVED 24/0132q AUG 2 31990 Q.C.O.S.R.
005 1000-54 Revision 14 c8 3
~~
TEST DATA fgu PUMP TEST DATA PARAMETER MEASURED Pump Inlet Pressure Static (Prior to Pump Start) PSIG (F.5/F.21) (locally) (PI 1001-160 A/B/C/0) Pump Inlet Pressure (P1) (During Test) PSIG (F ll/F.27) (locally) (PI 1001-160 A/B/C/D) Differential Pressure (Pd -P') 290 PSI (Set at 290 ps'd)
, Pump Olscharge Pressure (Pd ) PSIG
(\--)/- (F.14/F.30) (locally) (PI 1001-77 A/B/C/0) - Pump Flow Rate (0) 39 4PM (F.15.b/F.31.b) (90X-3 (FI 1040-3A/B) panel) RHR Ht Exchanger Outlet Pressure IN PSIG (F.15.a/F.31.a) (90X-3) (PI 1001-3A/B) panel) 1 ('J) L APPROVED AUG 2 31990 24/0132q Q.C.O.S.R.
005 1000-54 i Revision 14 l
, 1 f y
. ( }j VIBRATION TESTING (F.15.c/F.31.c) )
)
M RATION TEST DATA MEASURE POINTS IN/SEC hjsW j l A APPROVED l i
;" AUG 2 31990 l
^
2 H Q.c.o.S.R. I v A 3 H v A 4 H V j A 5 H v A 6 H v , i l O l V ~-- l tw.. , as , w g ...= es un .w is n _ , _ . . . - i nN 4 3 i wu 6
- n n , ,,_
I L fil,H %I a < i
% .
- l ' ,m-i .r-,
a.d. ,- I
. , . 1 , '. ,l .J
'I t .I !
d / * *~ b
,.' ."b_
h '1v-l-i t ,h. l
.] Il (_,./ v/'
E i
'1 ' I i
These vibration points could be on either side, depending on accessibility. Person performing vibration testing (NAME) O V Vibration instrument Q.A. number /next cal, date / Vibration Accelerometer Q.A. number /next cal. date / l- 24/0132q l 9 y -
---tt
4 . . -. _. . . . _ . _ _ . _ _ - . _ . . . _ _ . _ . . , . . . _ ,
'i ., .}
r RHR SERVICE WATER PUMP FLOWRATE 005 1000-54 w ' TESTING. DATA SHEET Revision 14 February 1990-UNIT? 3/m 6 PUMP # DATE N 7 4 /- REASON FOR TEST:
' OPERATOR k b M D f> '/ NoutineQuarterly i
Post-Maintenince TEST PROCEDURE: -QOS 1000-4 Alert Range Testing-- Establishing Reference Values < PRETEST CHECKLIST Verify that pump oil level is normal A/CM (Initials) (F.1) MO-1001-4A/B and MO-1001-185A/B cycled properly' (Initials) (F.4/F.20)
- RHR Service Water Pump Vault Cooler Fans OPER^BLE: Af[A (Initials) (F.8/F.24) I TECHNICAL SPECIFICATION REQUIREMENTS Tech. Spec. requires a m(nimum flow rate (Q) ofJ2 3500 gpm and a discharge a pressure (P Initial the following where applicable.
-\ -(F.10/F.2-6)d) of 2 198 psig, DISCHARGE PRESSURE (Pd ) FLOH RATE (Q) ACCEPTANCE CRITERIA psig- 3500 gpm- 1 198 psig at 3500 gpm
/
The data taken at:a flow rate of 3500 gpm M fulfills the-Tech. Spec. requirements. Ope r'a ttfr 's Ini ti a l s 6
-.(N/A-if not applicable)-
The Tech.: Spec reflutrements of > 3500 gpm Mb and 2 198 psig:has NOT-been met."
=
. Operator's Initials (N/A.if not applicable) 1 b
APPROVED.
--24/01329 gg3g Q.C.O.S.R.
005 1000-5a Reviston 14 ,ey < 7 M4p} TEST DATA PUMP TEST DATA _ PARAHETER MEASURED Pump Inlet Pressure Static (Prior to Pump Start) PSIG (F.5/F.21) (locally) (PI 1001-160 A/B/C/D) Pump Inlet Pressure (P1) (During Test) PSIG (F.11/F.27) (locally) (PI 1001-160 A/B/C/0) ~ Differential Pressure (Pd -P.) 290 PSI (Set at 290 ps'd)
~
Pump Discharge 7- Pressure (Pd ) g PSIG N (f.14/F,30) (locally) (PI 1001-77 A/B/C/0) . Pump Flow Rate (Q) 3NOGPM (F.15.b/F.31.b) (90X-3 (FI 1040-3A/B) panel) RHR Ht E;;cnanger Outlet Pressure l70 PSIG (F.15.a/F.31.a) (90X-3) (PI 1001-3A/B) Danel) l g3 V APPROVED 24/0132q Q.C.O.S.R.
_ _ _ __m 003 1000-S4 Revision 14 []) vlBRATION TESTING (F.15.c/F.31.c) p VIBRATION TEST DATA MEASURE IN/SEC POINTS A APPROVED j i " AUG 2 31990 !
^
2 H Q.C.O.S.R. ! v A 3 H v A 4 _H v l A , l 5 H l v A 6 H v i t.... ! _._ s.
-_ s .. .-
4 3 . n\ - 1 i p . I hI l 6 I 5 l 2 ; / '
~ '
i b , ; - g , dlh
.1- # '
~
-.',.ps, fJ i
- l. ,l
%{;Q:'
- l r t'
_w_ 'tOI" p .- di J __# () w/ E t ! ). .!+.v1 l. I Ill 1 , These vibration points could be on either side depending on accessibility. Person performing vibration testing _ ( N A.HE ) Vibration instrument Q.A. number /next cal. date / Vibration Accelerometer Q.A. number /next cal. date / l 24/0132q '
00S 1000-54 Revision 14
~
POST' TEST CHECKLIST Visualinspectionforleakageperformed(E.2)M(/k (INITIALS) All control switches returned to normal e, per 005 005-51, step 44. (INITIALS)
/f4 TEST COMPLETED (TIME) OUE DATE 3*99/
Independent verification of Operability Status Following Test:_._ /D E / Control Room Date ACTION TAKEN o action required - surveillance acceptable and Technical Specification is met.
'l l[l Parameter (s) in the alert range - pump testing must be rescheduled to be accomplished every 45 days or until the alert condition is corrected.
Notify the Operating Engineer of increased surveillance requirement. l[l Parameter (s) in the required action range or the Tech Spec requirement o met. Equipment declared inoperable. Refer to Q05.1000-04. is no.t , FINAL REVIEW Review by the SCRE must be ccepleted immediately after completion of test. SCRE REVIEN # / Sign Date Time SHIFT ENGINEER REVIEW //d / Sign Date IST COORDINATOR REVIEN //d / Sign Date OPERATING ENGINEER REVIEH Sign
#k /
Date. ANII REVIEH MV /
-Sign Date TECH STAFF SUPERVISOR REVIEN #I /
Sign Date APPROVED (final) 24/0132q AUG 2 31990 Q.C.O.S.R.
Simulator CWe Or/es-Tost Procedure Cover Sheet Test Number aos /ooo-4 PTAO-105T1 Oi Date Performed //~/Y-9 0 Test Description A'#kW fgHf flou A'Are 72S7inG 0 &e g A rio Ms' GBA'Y 90 MW Discrepancies section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date O V l Test Results
- 1. Test Completed Satisfactorily 1
- 2. After correction of the above discrepancies, test
- results are satisfactoy. Retest is NOT necessary.
__ 3. Tests results UNSATISFACTORY. Retest the above after correction of above-discrepancies. Retest Complete Date Test Complete ro Date ll-lNo SFCC Acceptance _
,. , Date 3 -3' 'N Simulator Supervisor's Accehitbnce / A 4+% Date 3-8-9/
m e.e.w. es a n n e, V-
005 1000-6 Revision 10 RHR PUMP FLOW RATE TESTING October 1988 0~ OPERATIONS - EVERY 90 OAYS 5.R. A. PURPOSE The purpose'of this procedure is to outline the steps necessary to perform RHR pump and valve operability testing required by the Inservice Testing Program. B. REFERENCES
- 1. Inservice Inspection and Testing Program.
- 2. -QAP 350-1, Standard Pomp Testing Methods.
- 3. QAP 350-2, Standard Valve Testing Methods.
C. PREREOUISITES
- 1. L'arify that' the RHR system discharge piping is filled and v9nted prior to performing this test.
- 2. Contact appropriate personnel for vibration testing,
,. 3. Obtain data sheet QOS 1000-S6 from the Shift Engineer. (Data. sheet' t
-should have all reference data filled in unless reference values us j are to be determined.F
~
- 4. _ Verify motor oil levels are normal.
D. PRECAUTIONS
- 1. Maintain-RHR service water pressure equal to or greater than 20 psig higher than-RHR primary pressure.
- 2. Notify personnel, in the vicinity of active components, of.the Impending -test.
- 3. An operatct should be present when starting major pieces of equipment.
- 4. Repeated starts land/or' jogs of induction motors greatly reduce the
'llfe of the winding insulation.- The heat produced by each acceleration or jog is much more than that produced and dissipated ,y by.the motor under full' load.
I i O
^"Faov' OCT ~ ' 38 5/0131q O.C.O.S.P.
1 -- _-
00$ 1000-6 Revision 10 E. LIMITATIONS AND ACTIONS g
- 1. Perform this test once per 90 days, after pump replacement or as part of an increased surveillance program.
- 2. The vibration velocity measurement shall be performed when test quantitles have b. ten achieved. Pump driver readings may be taken at this time. Pump readings shall be taken after a minimum of 5 minutes run time using approved quality assured instrumentation.
- 3. Components displaying discrepancies shall be evaluated per QAP 350-1, Standard Pump Testing Hethods, or QAP 350-2, Standard Valve Testing Hethods.
- 4. During performance of this surveillance, an operator should visually inspect for leakage from the RHR piping, pumps, and valves. Work requests should be initiated as appropriate.
- 5. The flow rate measurement in this test verifies the operation of valves 1001-67A, 8, C, and 0, and valves 1001-142A, B, C. and O.
The verification that minimum flow check valves 1001-142A, B, C, and 0 open is based on system flow ar.d pressure resoonse when HO-1001-18A and 188 are cycled in steps F.4.c., F.4.d., F.5.e., and F.5.f. below. Their operability is also based on the RHR heat exchanger relief valves not lifting. F. PROCEDURE
- 1. Establish RHR service water flow through the RHR heat exchangers,
- a. Ver ty the following valve positions:
(1) VALVES 1001-1A, B, C, and 0 - open. (2) VALVES 1001-3A, B, C, and 0 - open. (3) HO-1001-4A and B - open/ closed. (4) H0-1001-185A and B - open/ closed. (5) H0-1001-186A and B - closed /open. (6) H0-1001-187A and B - closed /open. (7) VALVE 1/2-1099 closed. (8) VALVE 1/2-1099 closed.
- b. OPEN valves HO-iOOI-5A and 58 to approximately 507. open.
1
- c. START RHR service water pumps 1001-65A or B and 1001-65C or 0.
. , t n ,,: i .
5/01314 r,r-c' c,0. 7 -'
L 005 1000-6 Revision 10 p V
- 2. a. OPEN isolation valve (s) for local PI 1001-70A, B, C, and D.
6-
- b. Record RHR pump inlet (static) pressure with the pumps OFF on
. 005 1000-56 (one sheet for each pump) as indicated on local P! ts 1001-70A, B, C, and D.
- 3. Verify the following RHR system valve positions,
- a. HO-1001-7A, B, C and 0 - open.
- b. VALVES 1001-66A, B, C, and 0 - open,
- c. VALVES 1001-15A and B - open,
- d. HO-1001-16A and B - open,
- e. VALVES 1001-17A and B - open,
- f. MO-1001-19A and B - open.
g.- VALVES 1001-141A, B, C, and 0 - open.
- 4. Establish "A" RHR loop flow (suppression pool to suppression pool),
- a. OPEN valve HO-1001-34A.
O g NOTE If the RHR system pressure, as maintained by the jockey pump, drops off to zero when the H0-1001-34A is OPENE0, the MO-1001-36A or 37A may be leaking through to the torus. Thi5 will cause the RHR piping to drain and create a water hammer when the RHR pump ts started. If the RHR system pressure drops to zero, CLOSE the HO-1001-34A valve and vent the RHR loop piping as the jockey pump refills the system. When normal pressure is again restored, perform the OPENING of MO-1001-34A in rapid succession with the next step of
; this procedure, so as to get-the RHR nump running without creating a water hammer in the piping. - Because of the long stroke time of the MO-1001-34A i valve, it is necessary to allow the valve to OPEN partially before rapidly proceeding to the next step of this procedure.
If it is determined that a valve may be leaking through, write a work request 'o . t-_OV-- N to repair the valve. OCT ' ~ E D 5/0131q MO S P
005 1000-6 Revision 10
- b. Start the "A" RHR pump, and at the same time OPEN valve MO-1001-36A, Throttle valve MO-1001-36A to estaplish an approx. 160 psig discharge pressure.
NOTE Past experience has shown that unnecessary water hammer may be avoided if the MO-1001-36A valve is started open at the same time the RHR pump is started. This precludes the opening of the minimum flow HO-1001-18A valve, and prevents unnecessary pressure surges in the containment spray piping, NOTE In the next step, if the operator in attendance at the pump hears the heat exchanger relief valve lifting, re-open the H0-1001-36A to resent the relief valve and write a work request to check the MO-1001-18A valve or check valve 1001-142A(B) as appropriate. It is also important to maintain RHR service water pressure at 20 psid greater than the RHR pressure.
- c. Verify MO-1001-36B is CLOSE0, then verify proper operation of the HO-1001-18A valve and check valve 1001-142A(B) by slowly closing the MO-1001-36A valve until the system flow drops below 1200 gpm. Wait 15 seconds and then verify that the MO-1001-18A valve OPENS. Observe setem flow or pressure response when MO-1001-18A OPENS.
s
- d. RE-OPEN the MO-1001-36A valve and verify the MO-1001-18A valve CLOSES.
- e. Throttle valve H0-1001-36A to establish the pump discharge pressure of approximately 160 psig as indicated by local PI-1001-71 A(B).
- f. After a 5 minute run time, record the following data for the A RHR pump on QOS 1000-56. (Holding period of 5 minutes is not required for pump driver vibration readings.)
(1) Pump inlet pressure (Pj) as indi:ated locally on PI-1001-70A(B).
. . imu s OCT ' ,3]
5/01314 r. C. O. S. P
00$ 1000-6 Revision 10 (2) Calculate discharge pressure Po.aP+P1 , with-aP.157 psid. (3) Throttle valve MO-1001-36A to establish the pump discharge pressure, Pd , as established in step F.4 f(2). Record the pump discharge pressure as indicated by PI-1001-71A(B). (4) Pump flow rate as indicated in the control room on FI-1040-11A. (5) Pump vibration amplitude as raported by the vibration testers. , NOTE Symmetrical damping devices or averaging techniques may be used to reduce instrument fluctuations to within 2% of the observed reading. Hydraulic instruments may be damped by using gage snubbers or by throttling small valves in instrument lines. If throttling of small valves is used, the operator shall alternately open []- and close the valve several times to verify unobstructed pressure communication while observing the instrument reading, g.; START "B" RHR pVmp, then STOP "A" RHR pump, -
- h. Repeat steps F.4,C. through F,4.f. for the "B" RHR pump.
- 5. Establish "B" RilR loop flow (suppression chamber to suppression chamber).
- a. OPEN valve 6 1001-348.
- b. Gradually CLOSE valve MO-1001-36A while, at-t<1e same time.
OPEN valve 6 1001-368 to_ maintain approx. 160 psig system pressure,
- c. Start "C" RHR-pump, then STOP "B" RHR pump,
- d. CLOSE. valve HO-1001-34A.
O 'weaove OCT: ? E30 5/01314 O.C.O.S.R.
005 1000-6 Revision 10 NOTE In the next step, if the operator in attendance at the pump hears the heat exchanger relief valve lifting, re-open the MO-1001-368 valve to reseat the relief valve, and write a work request to check the HO-1001-188 valve or check valve 1001-142C(0) appropriate. It is also important to maintain RHR service water pressure at 20 p;id greater than the RHR pressure,
- e. Verify MO-1001-36A is CLOSED, then verify proper operation of the M0-1001-188 valve and check valve 1001-142C(D) by slowly closing tne MO-1001-368 valve until the system flow drops below 1200 gpm. Walt.15 seconds and then verify that the MO-1001-188 valve OPENS, Observe system flow or pressure response when HO-1001-18B OPENS,
- f. RE-OPEN the H0-1001-36B valve and verify the MO-1001-188 valve CLOSES,
- g. Throttle valve HO-1001-368 to establish the pump discharge pressure of approximately 160 psig, as indicated by local PI-1001-71C(0), g
- h. After a 5 minute run time, record the following data for the C RHR pump on QOS 1000-56:
(1) Pump inlet pressure (Pg) as indicated locally on PI-1001-70C(0). (2) Calculate discharge pressure Pd aP+Pi , with aP-157 psid. (3) Throttle valve H0-1001-368 to establish the pump discharge pressure, Pd , as established in step F.5.h(2). Record the pump discharge pressure as indicated by PI-1001-71C(D). (4) Pump flow rate as indicated in the control room on FI-1040-IlB. I.PFRG L Q OCT1 1:30 5/01314
005-1000-6 Revision 10 _( yi . (5)- Pump vibration amplitude as reported by the vibration testers. NOTE Symmetrical damping devices or _ averaging techniques may be used to reduce instrument fluctuations to within 2% of the observed reading. Hydraulic instruments may be-damped by using gage snubbers or by throttling
-small-valves in instrument lines. If throttling of small valves is used.
the operator shall alternately open and close the valve several times to verify unobstructed pressure communication while observing the instrument reaoing.
- 1. START "0" RHR pump, then STOP "C" RHR pump.
-j , Repeat steps F.5.e. through'F.5.h. for the "0" RHR pump. ,
- k. CLOSE the HO-1001-360 valve and STOP the 0" RHR pump.
j6-Q 1, CLOSE valve HO-1001-348. i
' 6 ,- -STOP the RHR service water pumps, 1001-65A or B and 65C or 0, that are running, 7.- Ver1fy the RHR system and RHR service. water system are returned--to normal.
CLOSE isolation' valves'for PI' 1001.-70A,_8, C,-and'0.
-- 8.
- 9. Verify all necessary data are. recorded on checklist QOS 1000-56.
1
- 10. _ Notify the Shift Engineer of any indications that the RHR pumps may be less than fully operable.
ll. !!f an RHR pump is inoperable, refer to QOS 1000-01, One RHR Pump -) Out-of-Service Outage Report. i
;G. CHECXLISTS-
- 1. QOS 1000-56,- RHR Pump Flow Rate Testing Data Sheet. y 1
H.- TECHNICAL SPECIFICATION REFERENCES ;
- 1. Section 3.5.A/4.5.A. s
- 2. Section 3.5.B/4.5.B. /J F RU v' t
(final) 5/0131q O C O. S P.
. . _ _ _ _ . _ ~ _ _ ._ _-_ . _ _ . _ _ _ ..
RHR PUMP FLOWRATE QOS 1000-56 ['.i TESTING OATA SHEET Revision 8 4 April 1990 UNIT S/MuMToR $N) PUMP # l/ DATE U- /1- 90 REASON FOR TEST: OPERATOR T Hi@uFfo E Routine Quarterly Post-Maintenance TEST PROCEDURE: QOS 1000-6 ,__ Alert Range Testing Required Action Range Testing Establishing Reference Values Verify that the RHR discharge piping is filled and vented. IM Verify that pump oil level is normal. 9/A IW/O Verify that MO-1001-18A(B) strokes. Observe OPEN / flow or pressure response. #M (initials) CLOSED / PUMP TEST DATA REFERENCE DATA - ENTER DRIOR TO TEST ACCEPTABLE ALERT REQUIRED PARAMETER HEASURED RANGE RANGE ACTION RANGE. _ Pump Inlet Pressure Static Low Value (Prior to test)- PSIG NA NA 3 PSIG HIN Pump Inlet A fressure (Durigg PSIG Low Value Test) (Pj) (locally) NA NA 3 PSIG MIN Differenital PSID NA NA NA Pressure (Set at 157 (Pe-Pj)) psid 01scharge PSIG f Pressure _--(P d ) .(locally) NA NA NA~- Flow Rate Hi to GPM Hi > GPM (90X-31 panel) d)6DGPM to GPM Lo to GPM Lo < GPM (See -Note (1) below)L $
$ i300 g,, curesy.nl:g (ccerue [ (Gop;) x.; re./ n (ud %-3, swe asnks br & Uf (ef. N p"f$
l0 k & Shoy Om crte 2t l40(sl3 O L\- APPROVED 24/0133q APR 2 81990 i Q.C.O.S.R.
005 1000-56 l Revision 8 l l O VIBRATION TEST OATA REFERENCE DATA-ENTER PRIOR TO TEST MEASURE IN/SEC ACCEPTABLE ALERT RANGE REQUIRED POINTS RANGE ACTION RANGE A M/ 1 H d4 V W4 NA NA NA A >J/4 2 H N/A V 4% NA NA NA A W NA NA NA 3 H tJ4 05 TO ut. IN/SEC HI(A TO d IN/SEC HI > 9 IN/SEC v au
- m sc ea 't e w g- m fu .' . "l
- :. . < n; ..
H AND V READINGS TAKEN AT 90' APART O, H IS IN LINE WITH lEEWEE! B B e a NJ SUCTION AND DISCHARGE LINE
' - - - -- - - - - ]
_ e= EEE "L Ly
\f 3 b____~ -- ,
- i , -
- - -\< ,
i s 1 m : i Person performing vibration testing d[A (Name/ Initials) ! Vloration instrument 0.A. number /next cal. date u/A / "/4 APPROVEO 24/0133a g g Q.C.O.S R.
_ ._ ._ _ ~ _ . _ . . . _ _ . . _ _ _ _ . _ - .__ _. 005 1000-S6-Revision 8-Visual Inspection for leakage performed
'N (initials)
All control-switches returned to normal per QOS 005-S1 per step 8. 41 (initials) Reset ECCS fill system alarm 41 (initials) Test Completed (Time) IN1 (N te) lbdO An RHR pump flow (Q) at a discharge pressure (Pd ) of 160 psig should be at least'4000 gpm. Minimum requirements for pump operability are met de.l (initials) because.Q 2 4000 gpm and Pd2 160 psig (data from (N/Attf not table on page 1 of QOS 1000-S6), appilcable) Pump operability is in doubt because Q < 4000 gpm. A (initials) LPCI flow Rate Test, QOS 1000-1, is to be (N/A if not performed. applicable) Independent Verification of Operability Status following Test: tJM Control Room Date. ACTION TAKEN: q lV[l No action required - survelliance acceptable. l(( Parameter (s) in the alert range - pump testing must be rescheduled to be accomplished every 45 days or until the alert condition is corrected. Notify the Operating-Engineer of increased surveillance requirement. l[] Parameter (s) in the requirsd action range or the Tech Spec requirement is l not-met. Equipment declared inoperable. Refer to QOS 1000-01. Review by the SCRE must be completed within 96 hours after completion of test. SCRE REVIEW / Sign Date Time
. SHIFT.EkGINEER REVIEW /
Sign Date IST COORDINATOR REVIEW / Sign Date OPERATING ENGINEER REVIEW / Sign Date LTECH STAFF SUPERVISOR REVIEW _
/
S19n Date APPROVED O. (final) APR 2 81990 24/0133q Q.C,0.S.R.
J Simulator Owo Or/cc
. Test Procedure Cover Sheet Test Number aeos /Soo-/
PTAO-105T1 O- oete eer'ormed 3 o Test Description g,g77,gy pg,e gpyy, ggggg,y7y yggy Discrepancies Section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date C\ V Test Results [ 1.. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above' after correction of above discrepancies.
Retest Complete Date Test Complete /)! r Date 329/ SFCC Acceptance [ / Date 3-27/ Simulator Supervi 's A plance - Date J 8-i/ C.E.CO. 96-1715 17*09
4 QCOS 1300-1 ex UNIT 1(2) (') REVISION 0 SAFETY RELATED ON HAND MONTHLY RCIC PUMP OPERABILITY TEST b, / . . b.LtA krDQL _._ M f MBULr l5 b'N TITLE d EFFECTIVE APPQ0}AL31GNATURE DATE A. PURPOSE Provide the necessary steps to perfor- Tech. Spec. Monthly RCIC pump run. Perform Tech. Spec. monthly operability surveillance on RCIC System motor operated valve, MO 1(2) 1301-61, STM TO TURB VLV. B. DISCUSSION
- 1. The following procedures may be performed in conjunction with this procedure, if they are required to be performed:
(^s - a. QCOS 1300-3, Monthly RCIC Motor Operated Valve Test. d b. QC05 1300-5, Quarterly RCIC Pump Operability Test
- c. QOS 005-4, IST Valve Position Indication.
- 2. Where brackets, ( ), are provided in the procedure, place a check to indicate 4tep completion.
C. REFERENCES
- 1. Technical Specifications 3.5 E/4.5.E, Reactor Core Isolation Cooling System.
- 2. Technical Specifications 3.2/4.2, Protective Instrumentation
- 3. Technical Specifications 3.7. A/4.7. A, Containrrent Systems, Primary Containment.
4 Technical Specifications 3.5.G/4.5.G, CCST Level.
- 5. M-50 (M-89), Diagram of RCIC Piping.
- 6. C00398 (GEK 9546), Instruction Operation and Maintenance, System 1300 Reactor Core Isolation Cooling.
(J 7. QAP 300-10, Operating Records,
- 8. QAP 300-T6. Suppression Chamber Level Operating Range.
2191a 1-
QCOS 1300-1 UNIT 1(2) REVISDN 0
- 9. QAP 350-1, A1 ministration of the Inservice Testing Program, 0
- 10. QC05 1300-2, RCIC Outage Report.
- 11. QC05 1300-3, Monthly RCIC Motor Operated Valve Test,
- 12. OCOS 1300-5, Quarterly RCIC Pump Operability Test.
- 13. OCOP 1300-1, RCIC Preparation for Standby Operation.
- 14. OCOP 1300-5, RCIC System Shutdown.
- 15. F5AR 4.5, RCIC System.
- 16. Eenigenburg Letter to R. Bax dated 10-28-85, Operational Guidelines for Motor Operated Valves.
- 17. Emergency Procedure Guidelines, Appendix B.
- 18. INP0 Finding (1987) IS-5-2
- 19. General Electric Service Information Lette r U. L) No. 336
- 20. Quad Cities Nuclear Station Procedure Writers Guide, Revision 1, January 31, 1990.
D. EOUIPMENT REQUIRED l' l None 1 E. PREREOUISITES l 1. The Shift Engineer has completed the following: l a, UNIT ,$ t h I (t ')
!(2)
- b. Reason for test (check appropriate item):
Normai Survei11ance ( P') Post Maintenance ( ) Partial for __, ( ) Other ( )
- c. Permission to start test:
,V/Y 3 D-9/ lO90 SE Signature Date/ Time 2191a QCOS 1300-1 UNIT 1(2)
REVISION O (D U 2. RCIC in standby line-uD WITH suction from CCST ( ) per QCOP 1300-1.
- 3. The Unit is off EGC control AND the RECIRC System is in ( )
manual flow control.
- 4. Radiation Protection personnel have been notified AND ( )
are supplying personnel to accompany plant operator during surveillance performance. F. PRECAUTIONS
- 1. Injection of RCIC into Reactor during power operation could cause a reactivity transient.
- 2. RCIC System operation below 400 gpm should be minimized to limit cycling of the Turbine Exhaust check valve.
- 3. RCIC System operation below 2200 rpm should be minimized because it may result in unstable system operation and equipment da nge.
(C-17)
- 4. Be prepared to stop manual operations if RCIC automatic start signal is received.
i -
- 5. Ensure personnel near RCIC turbine are aware of the impenuing test and the potential for steam leaking around the turbine.
G. LIMITATIONS AND ACTIONS
- 1. E a' component falls to perform or falls to meet Tech Spec requirements, THEN notify Shift Engineer.
- 2. LF RCIC becomes inoperable, THEN perform QC05 1300-2.
- 3. WHEN RCIC suction is from CCST, THEN talnimize the time that IIO"I( 2 )- 1301-60, MIN FLOW VLV is oper to prevent draining CCST to the Torus.
4 FIC 1(2)-1340-1, RCIC FLOW CONTROLLER LJsr be set at 400 gpm and in AUTO upon comp'etion of this test for RCIC to be opera:;le. S. RCIC automatic initiation is Reactor low low water level;
-59 inches. (C-2)
- 6. RCIC isolation signals are: (C-2)
- a. RCIC Turbine area hi;b temperature; 170*F.
- b. RCIC steam line righ flow; 3007 of rated steam flow with
.. ( approximately a : second time celay,
- c. Reactor Vessel low pre dure; 50 psig.
2191a 3-
1 QCOS 1300-1 UNIT 1(2) REVISION O
- 7. RCIC Turbine trips are-O\l l
l [ ] I NOTE Item G.5.a will close the TRIP THROTTLE VLV. Item G 6.b - G.6.e will close MO 1(2)-1301-60, MIN FLOW VLV and MO 1(2)-1301-61, STM TO TURB VLV. E RCIC trip was caused by Reactor high level, item G.6.b, THEN RCIC will auto restart at a Reactor water level <- F inches. All other trips require operator actions for resetting the trips. ( )
- a. Turbine overspeed; 5600 rpm. (Mechanical)
- b. High Reactor Vessel water level; +48 inches.
- c. Low pump suction pressure; 15 inches Hg abs,
- d. High RCIC Turbine exhaust pressure; 25 psig, g
- e. Automatic RCIC Isolation.
- 8. Motor Operated Valves Guidelines: (C-16)
- a. A maximuin of five starts within a one minute period, followed by a 30 minute cooling off time.
- b. The valve is fully operational during the cooling off period.
- c. When throttle valves are required to adjust flow or pressure, it may be necessary to wait a few seconds to abide by this guideline.
- 9. Torus temperature limitations and actions: (C-3)
- a. WHEN RCIC pump is operating for testing, THEN Torus temperature shall be continually monitored anc logged per QAP 300-10, every 5 minutes until testing is terminated.
- b. IF, F Torus temperature reaches 105'F during RCIC pump testing,THEN terminate pump testing A_fl0 reduce Torus temperature below 95'F within 24 hours.
- 10. CCST level shall be maintained greater than 9.5 feet.(C-4)
- 11. Operation of RCIC will add volume to the Torus pool. Maintain torus level within normal operating band per QAP 300-T6.
2191a 4-
I OC05 1300-1 UN!i 1(2) REV!stcN O H. ;ERFORMANCE ACCEPTANCE CR UERIA
- 1. MO 1(2)-1301-61, STM TO TURB VLV, was coerated .sne complete cycle.(i.e. full open and full closed as monitored by indicating lights). (C-1) i
- 2. RCIC pump ceveleped a flow rate of 2400 gpm at a discharge pressure of ,11250 psig (cischarge pressure correspo..ing to Reactor pressure of greater than 1150 psig). (C-1)
- 1. PROCEDURE
- 1. Verify an opera *.or in ottendance in the RCIC room to check for leakage of the RCIC piping, valves, turbine and pump during turbine operation.
2, Record TORUS LVL from panel LR 1(2)-1602-7. C 8' incnes
- 3. Verify FIC 1(2)-1340-1, RCIC FLOW CGNTROLLER Utpoint at 400 gpm A,fND in AUTO.
- 4. Open H0 1(2)-2301-15. TEST RTN VLV for HPCI.
- 5. Verify OPEN H0 1(2)-1301-48, PHP DISCH VLV.
C/ 6. Manually throttle open MO 1(2)-1301-53, CCSTTESTBYP,ggteg as applicable, to the following position to establish . 1150 to 1350 psig discharge pressure. gO
- a. Unit 1 (HO 1-1301-53): 17 turns.
- b. Unit 2 (MO 2-1301-53): 28 turns. ,
- 8. Start TURB VACU PHP, "/
- 9. Open MO 1(2)-1301-62. TURB CLC WTR VLV.
( ) CAuft0N RCIC System operation below 400 gpm should be minimi:ed to limit ;ycling of the Turpine Exhaust check valve. ACIC System operation below 2200 rpm should be minimi:ed becau',e it may result in unstable system operation and equipment damage. ( ) m
- 10. Open MO 1(2)-1301-61, STM TO TURB VLV to start d'
('") RCIC Turbine, h-2191a _ _ _ _ _ _ _ _ _ _ _
OC05 1300 1 UNIT 1(2) R!V!$10N O
- 11. Verifv RCIC flow comes up to FIC 1(2)-1340-1, O
RCIC FLOW CONTROLLER setpoint (400 gem). < syn
- 12. Throttle H0 1(2)-1301-53, CCST TEST BYP to establish 1250 to 1300 psig as indicated on PI-1340-7. PHP DISCH PRESS y AND RCIC pump flow of 2400 gpm on FIC 1(2)-1340 1, RCIC FLOW CONTROLLER.
- 13. Record and verify:
e
- a. Pump flow lj 0 $
gpm
- b. Ve ify pump flow greater than or eq.,al to 400 gpm. ( /i
- c. Pump suction pressure PI 1(2)-1340-2, PHP SUCT PRESS. AA psl9
- d. Pump discharge press. PI 1(2)-1340-7 PHP O!SCH PRESS. /269 psig Verify pump discharge pressure greater than e.
or equal to 1250 psig. ( j)
- f. Turbine exhaust press. P! 1(2)-1340-3, TURB EXH PRESS. 9 psig
- g. Turbine speed SI 1(2)-1340-501 TURB SPEED. fD rpm
- 14. Verify proper opera +1on of FIC 1(2)-1340-1, RCIC FLOH CONTROLLER:
- a. Vary FIC 1(2)-1340-1 AUTO setpoint from 400 to
'50 gpm AJ verify corresponding flow redut!'on. ( 4,
- b. Return f!C i(2)-1340-1 setpoint to 400 gpm g verify corresponcing flow increase. ( /)
- c. Transfer f!C 1(2)-1340-1 to MANUAL. ( /)
- d. Decrease flC 1(2)-1340-1 MANUAL signal ,
JA verify corresponcing flow reduction. ( ')
- e. Increase f!C 1(2) 1340-1 MANUAL signal A,3 verify corresponcing flow increase. ( #)
- f. Transfer f!C 'I2)-1340-1, RCiC FLOW CONTROLLER to AVIO AM sett nt of 400 gpm.
(/')
- 15. Repress e and hold for 15 seconds TURB TRIP pushbutton, c/
- 16. Verify closed MO 1(2)-1301-61, STM TO TURB VLV. ( )
;/
- 17. Close MO 1(2)-1301-53, CCST TEST BYP. ( ) i 2191a I
OCCS 1300 1 UNIT 1(2) REV!SICN 0
- 18. Close H0 1(2).1301-62. TURB CLG WIR VLV. ( df)
- 19. Stop TURB VACU PMP. ( [
- 20. Reset the turbine trip by depressing TURB RESET. ; 4
- 21. Close MO 1(2).2301 15. TEST RTN VLV for HPCI. ( e')
- 22. Record final TORUS LVL from LR 1(2) '602 7 AND verify ~~~~
wtthin normal operating band on QAP 300 76. (/ 7 Tn~;ne s
- 23. Record results of visual Instettien of RCIC during pump run.
. 30 C.*. . . . N!]. . l &"ef.' f.9 DX.^.'. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
i
- 24. Perform independent verification RCIC is in the strndby lineup:
Component Position IN!T13 NO 1(2).2301 15 Closed // MO 1(2).1301-53 Closed M MO 1(2).1301-62 Closed M. MO 1(2)-1301 61 Closed #
/
TURB VAC PMP switch AUTO M M_,. FIC 1(2)-1340 1 AUTO at 400 gpm GOVERNOR VALVE Open /N
- 26. E this turv9tilence was satisfactory , THEN;
- a. Surveillance perform d by N'& / 3 7
- f[
ygnature Date
- b. Survelliance reviewed by: /U/Y / ,,_
SCRE Signature Cate C. Surveillance approved by: /
$E Signature Date Comment 5:- /MO A 1 0
2191a 7
OC05 1300-1 UNIT 1(2) i REVISICN O
- 27. JJ, this surveillance was unsatisf actory, THIN:
O
- a. Dettription of Deficiencies / Comments: /Wh , ,
- b. Surveillance performed by, Nuclear Work Request (NWR) initiated: l (1) NWR initiated: YES No j
/
Signature Date
- c. Surveillance reviewed by, DVR initiated (T.S. LCO oniv):
(1) DVR initiated: Y(S NO
/
SCtt signaturi~ Date
- d. Surveillance approved Dy, RCIC Outage Report, QCOS 1300-2 initiated:
(1) RCIC Outage Report initiated. OC05 1300-2: h YES ,_,_ NO
/
SE Signature Date
- 28. Attach this co9pleted surveillance to 035 00C-53, Operations Monthly Surveillance Test Assignment Sheet QR to RCIC System Outage Report, as appropriate, J. ATTACHMENTS
- 1. None, 9
(final) 2191a . . _ . - -
Simulator Que Omes Test Procoduro Covor Shoet Tat Number acos Nu d f Date Performed I' } #/ / Test Descrlption Q,yg, ye my pyy y y y l Discrepaneles section of Test Discrepancy Corrected item # Commente, Requiring Report # (initials) Retest and Date O Test Results I 1. Test Completed. Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary. ,
- 3. Tests results UNSATISFACTORY. Retest the above after :
correction of above discrepancies. Retest Complete Date ! Test Complete / / Date 3 2 1'/ SFCC Acceptance e e- h/ Date 3 7 9/ Simulator Supervis r's A ceptance / Date J f-9/ c.c.cc, ei.ir n ir se l
- QCOS 1400-1
. UNIT 1(2) t REVISTON O O' SAFETY RELATED ON HAND l i
. QUARTERLY CORE SPRAY PUMP FLOW RATE TEST m i ,
C w tLANAcPd kwhTITLE NM+Ar~ J 1-1i "fD EFFECTIVE APPR0$LSTGNATURE DATE A. PURPOSE The purpose of this procedure is to provide the necessary steps to perform the IST and 7:ch Spec Quarterly (or after maintenance) pump
-operabillty test.
B, DISCUSSION 4 1 -QC05.1400-4, Monthly Core Spray Pump Operability Test may be performed in conjunction with this procedure.
- 2. A flow rate of 4500 gpm at-a discharge pressure of 216 psig is the calculated equivalent of the flow rate 4700 gpm discharging against c a Reactor pressure of 90 psig. The 200 gom increase in flow rate above Tech Spec requirements is used to account for possible the_rmal sleeve leakage.
3 Where brackets, ( ), are provided in the procedure, place a check to indicate step completion. C.- REFERENCES
- 1. Technical Specifications 3.5. A,l/4.5. A.I.b, Core Spray Subsystems and LPCI Mode of the RHR System.
- 2. -Techn_ical Specifications 3.5.G.1/4.5.G.1, Maintenance of Filled Olscharge Piping.
- 3. M-36 (M-78), Diagram of Core. Spray Piping.
- 4. OCOP 1400-1 Core Spray System Preparation for Standby Operation.
S. QCOP 1400-3, ECCS Fill System,
- 6. QC05 1400-3, Core Spray subsystem Outage Report.
- 7. QCOS 1400-8, Quarterly Core Spray System Power Operated Valve Test.
_8 . _Q COS 1400-4, Monthly Core Spray Pump Operability Test.
.t 2079a- __.. _ __,_ .._ .... _.
. _ _ ._ _ .. _ ___ ._ _ _ _. _ . _ .._- _ _ _ - _. . _ . . _ _ _ . . ~~
QCOS 1400-1 UNIT 1(2) REVISICN O
- 9. 005 005-54, Operation Quarterly Surveillance Test Assignment Sheet, g
- 10. QAP 350-1, Administration of the Intervice Testing Program.
- 11. QAP 350-59, IST Pump Surveillance Acceptance Criteria Summary Sheet.
- 12. Intervice Testing Program,
- 13. FSAR 6.2.3, Core Spray Subsystem.
- 14. Eenigburg Letter to R. Bar dated 10-28-85, Operational Guidelines for Motor Operated Valves.
- 15. NRC Bulletin 68,04 Potential Safety Related Pump Loss.
- 16. Letter from D. Butener to W. Koester 7-12-77 G-EBO-7-172 (Station Letter 77-2042).
- 17. Quad Cities Nuclear Station Procedure Writers Guide, Revision 1, January 31, 1990.
- 18. DVR 4-1-87-047,B Core Spray Header (40 psig.
D. EQUIPMENT REQUIRED
- 1. -IF H0 1(2)-1402-4A, CS BYP AND TEST VLV is reeutred to be tested for QC05 1400-8, THEN a calibrated stopwatch is required.
- 2. Calibrated vibration instrument.
- 3. Calibrated accelerometer.
E. PREREQUISITES
- 1. The Shift Engineer has completed the following:
- a. UNIT .5/ M h )
1(2)
- b. Reason for test (check appropriate item):
Normal Surveillance ([ Post Maintenance ( ) IST Alert Range ( ) Partial for ( ) Other ( )
- c. Permission to 5 art test:
fy ] 7A( j u S$V ff Signat i Date/ Time 2798 M # r
OC05 1400-1 UNIT 1(2) REVISION O
- 2. Core Spray System in standby line-up per QCOP 1400-1. ( [)
- 3. Personnel ready for vibration testing.
- 4. QAP 350-59 with IST Acceptable, Alert, and Required Action Range data is attached to this procedure. /)
- 5. E QCOS 1400-8, Quarterly Core Spray Power Operated Valve Test was scheduled to be performed, THEN QCOS 1400-8 was performed prior to the start of this surveillance. (g) 6.- E needed, THEN stopwatch ID no. and calibration due date recorded:
Stopwatch instrument ID no.: uW Cal due date: "C
- 7. Vibration instrument and accelerometer 10 no. and
-callbration due dates recorded:
Vibration. instrument ID no.: O Cal due date: NM Accelerometer 10 no : NI Cal due date: M F, SRECAUTIONS > p 1. E for any reason H0-1(2)-1402-4A/B CS BYP AND TEST VLV is opened ;
'A without pump running AND fill pressure is lost (pressure remains
< 40 psi), THEN system must be-refilled and vented per QCOP 1400-1.
't.
G. LIMITATIONS AND ACTIONS-
-1. At the completion of the surveillance the SCRE must immediately review the results of this test for compliance to Tech Spec and IST requirements.
~ '
- 2. Motor Operated Valves Guidelines: (C-14)
- a. .A maximum of five starts within a one minute period, followed by a 30 minutes cooling off time. '
b ._ The valve is operable during the cooling off period, c, -WHEN throttle valves are required to adjust flow or pressure, THEN it may be necessary to' wait a few seconds to abide by this gUdeline.-
- 3. E a-' component fails to perform or falls to meet Tech Spec or IST.
requirements, THEN notify the' Shift Engineer. 4 WHEN a Core Spray Pump is run in the minimum flow mode of operation for a time period exceeding 10 minutes,
- THEN notify the Technical Staff IST group to perform a vibration l; -
analysis to ensure no pump ~ degradation has occurred. Although the l pump shall not be' declared inoperable, the vibration analysis should L be performed within 72 nours. (C-15) 1^
- 2079a __._.2.-.-
QC05 140C-1 UN!f 1(2) REVISION O
- 5. During the performance of this test an operator should visually inspect for leakage of the Core Spray piping, pumps, and valves.
W
- 6. Motor vibration selocity measure w .s stall ce perfortned after cump reaches rated speed. A waiting pu iod of 5 minutes is reQuirea before taking pump vioration cata.
- 7. .l. instrement readings are fluctuating, THEN throttling the instru'nent valve may te required to dampen out the fluctuations. ine Sperator shall alternately open and close the valve several times to o rify unobstructed hydrault; signal to instrument while observir'g the instrument reading.
- 8. The following sections may be perfortred anytime af ter the appropriate step is completed but must te completed prior to final acceptance of this procedure.
- a. Acceptance criteria verification
- b. Calculation verification C. Vibration Amplitute Tables
- 9. If, only partial testing of Core Spray System is required, THEN:
- a. Ensure all prereaulsites are met.
- b. Steps in section 1. may be performed independently as O identified in the procedure, BUT the analysis steps perfortred ,
after testing must be complete 0. H. PERFORMANCE ACCEPTANCE CRITERIA
- 1. Each Core Spray Pump produced greater than or equal to 4500 gom discharge flow at a discharge pressure of greater than or equal to 216 psig. (C-1, C-II,C-16)
- a. Flow rate of .14500 gpm at 2216 psig discharge pressure verifies that 1(2)-1402-8A(B) strokes to its full open position for the IST program,
- 2. Each Core Spray Pump produced a discharge flow within IST acceptable range.
- 3. Each Core Spray Pump vibration aas within IST acceptable range.
- 4. Each C'.'? Spray Pump idle suction pressure was greater than IST Required Action range of 3 psig.
- 5. Each Core Spray Pump runnina suction pressure was greater than IST Recuired Action range of 3 psig.
O 2079a a, I
.. ~ _ - - - . - . . ~ . , . - -._ - _ - _ - ._ - . . -
OC05 1400 1 UN!T 1(2) REVISION 0
- 6. 1(2).1402 13A/B, 1(2)A/S CORE SPRAY PHP MIN FLOW SV is verified to 0- be fully open if 1(2)A/B Core Spray Pump discharge flow decreased by 1 100 gpm when MO 1402 38A/B, CS MIN FLCH VLV was opened.
- 7. 1(?) '402 8A/B,1(2)A/B CORE SPRAY O!SCHARGE STOP CK VLV is verified to ca.e fully opened when a flow rate of at least 4500 gem is achieved.
I. PRCCEDURE
- 1. IF Core Spray Subsystem A requires testing, IIiEN:
- a. Verify idle cump $Uttion pressure above IST alert range:
(1) Record idle purrp suction pressure P! 1(2).1402 40A, located at pump. Ek#" ps19 (2) Verify id'ie suction pressure greater than 3 psig. ( M pm cp of.) ,..cf,e L l 1 CAUTION IF 1(2).1402 13A, CORE SPRAY PHP MIN FLOW SV falls to open THEN, O RV 1(2).1402 28A, 1(2)A CORE SPRAY DISCH HDR RV may lift draining water to the Reactor Building Equipment Drain Tank (RBEDT), [ ]
- b. Start 1(2)A CS PHP.
- c. Verify H0 1(2)-1402-38A, CS PMP HIN FLOW VLV opens. ( /)
- d. Record 1(2)A CS PHP discharge pressure, as indicated on PI 1(2).1450-1A, CS HEADER PRESS. 305-psi 9 C ]
NOTE The next step is started at this point and could continue while performing the rest of this procedure. Perform a visua'; inspection of Core Scray i ( O e. Subsystem A for leats on piping, valves and pump. t. vu? " INIT!ALS l 2079a !
QCOS 1400-1 UNIT 1(2) REVISION 0 ( ) NOTE The next two steps should te done simultaneously. H01(2)-1402-38A, CS PHP MIN FLOW VLV will close when pump discharge flow increases. ( )
- f. Throttle olen H0 1(2)-1402-4A, CS BYPASS AND TEST VLV to estaplish a pump discharge pressure of approximately 260 psig as indicated on PI 1(2)-1450-1A, CS HEADER PRESS.
- g. Verify MO 1(2)-1402-3BA, CS PHP HIN FLOH VLV closes. ( /)
. h. Verify pump suction pressure above IST alert range:
(1) Record pump suction pressure P1 1(2)-1402-40A, located at pump. 4 God ' p519 (2) Verify suction pressure greater than 3 psig. ( )
- 1. Calculate o ss discharge pressure and independently verify result:
(1) Pd . OP+PI, with OP . 257 psid and Pt . Pump running suction pressure (previous step) (2) Pd . 257 + 3 . Rco psig hm s+ <p h i t ) ~ tw <, g Berfo(medby[~ Independent verification by:
- j. Throttle H0 1(2)-1402-4A, CS BYP AND TEST VLV to establish pump discharge pressure to pressure calculated in previous step as indicated on P! 1(2)-1450-1A. CS HEADER PRESS.
O 2079a OCOS 1400-1 UNIT 1(2) REVISION O fT k. Record the following AND verify IST ~~~ \-- criteria achieved:
. TECH SPEC T, S, PASS IST PASSED PARAHETER MEASURED LIMIT (!NITIAL) (INITIAL) 1(2) Pump A _269 psig Olscharge NA NA <?-'
Pressure PI 1(2)-1450-1A 1(2) Pump A 34 0 v gpm Olscharge Flow NA NA j' thy' F1 1(2)-1450-4A
- m. WHEN Core Spray Pump A has run for 5 minutes in the conditions established in the above table, THEN direct vibration tester to take vibration for Core Spray Pump A (refer to Attachment A for proper points) and record results in table below.
TECH IST SPEC ACCEPTABLE PARAHETER HEASUREO LIMIT
) Vibration A 4/w In/sec N/A k/V4 Point H In/sec N/A 1 V In/sec N/A V!bration A In/sec N/A Point H In/sec N/A 2 V In/sec N/A Vibration A In/sec N/A 4 Point E~~ In/sec N/A
/ . /
3 V V In/sec N/A V
- n. Throttle as necessary H0 1(2)-1402-4A, CS BYP AND TEST VLV to establish a flow rate 2 4500 gpm et 2 216 psig, O
d 2079a -7
OCOS I400-1 UNIT 1(2) REVISION O (1) Record g verify Tech. Spec. criteria achieved: TECH SPEC T. S. PASS 15T PASSED PARAMETER MEASURED LIMIT (!NITIAL) (IN!,lAL) 1(2) Pump A A / G. psig 216 psig Discharge Minimum NA Pressure Pt 1(2)-1450-1A 1(2) Pump A 4Wg gpm 4500 gpm Discharge Flow Minimum M" NA FI 1(2)-1450-4A ~# (2) Verify IST criteria fe- 1(2)-1402-BA, CORE SPRAY O!SCHARGE STOP CK VLV is met by verifying flow above is 2 1500 gpm 3 pressure above is 2 21E psig. A ( f)
- o. Verify operaellity of 1(2)-1402-13A, 1(2)A COPE SPRAY PHP MIN FLOW SV by:
(1) O J e_n and hold for 30 sec. MO 1(2)-1402-38A, / CS MIN FLOH VLV. ( /) (2) Record 1(2)A Core Spray Pump discharge flow as indicated on FI 1450 4A, CS HEADER FLOW. 440d gpm (3) Calculate pump flow decrease and independently verify result: , (a) Flow Decrease Flow (valve closed) - Flow (valve open) (b) Flow Decrease 4'fuv 4400
- /#d gpm Pergefmed by- Incependent Verification by:
(4) Verify IST criteria for 1(2)-1402-13A, 1(2)A CORE SPRAY PHP MIN FLOH SV is achieved y by a minimum of 100 gpm flow decrease above. ( V) (5) Close MO 1402-3BA, CS MIN FLOW VALVE. ( d
- p. E timing of MO 1(2)-1402 4A, CS BYP AND TEST VLV 1s reavired for completion of OC05 1400-8, THEN time MO 1(2)-1402 4A, CS BYP AND TEST VLv during tne performance of next step.
- q. Close MO 1(2)-1402-4A, CS BYP AND TEST VLV. (
2079a _ _ _ _ _ _ - _ _ _
l QC05 1400-1 l UNIT 1(2) J REVISION O ; l e r. Verify H0 1(2)-1402-38A, CS PHP MIN FLOW VLV k- opens as system flow decreases. ( /)
- 5. IF MO 1(2)-1402-4A was titred above, THrN record time on OCOS 1400-8.
- t. Stop 1(2)A CS PMP. (d
- u. Close MO 1(2)-1402-38A, CS PHP MIN FLOW VLV. (/
- v. LF over pressure condition (90 psig) in discharge piping exists after 1(2)A Core Spray Pump is stopped. THEN: (C 18)
(1) C_ rack open MO !(2)-1402-4A, CS BYP AND TEST VLV to slowly reduce pressure. (2) Cl_ose H0 1(2)-1402-4A, CS BYP AND TEST VLV when pressure reaches 90 psig, as indicated on PI 1(2)-1450-1A, CS HEADER PRESS. ( />
- w. E pressure cannot be maintained after performing cepressurization step above, THEN: (C-18)
(1) Open H0 1(2)-1402-4A, CS BYP AND TEST VLV. (2) Close H0 1(2)-1402-4A, CS BYP AND TEST VLV. (M4 (3) Fill and vent 1(2)A Core Spray Subsystem per QCOP 1400-1. ( M/I,
- x. If instrumentation dampening was used THEN, perform in independent verification that the fol Towing the following instruments are valved in service:
INITIAL (1) 1(2)B Core Spray FT 1(2)-1461-B Lo Side Shutoff Valve. MM (2) 1(2)B Core Spray FT 1(2)-1461-B Hi Side Shutoff Valve. N /b (3) 1(2)B Core Spray Pmp Dsch PT 1(2)-1460-8 Shutoff Viv. MN (4) 1(2)B Core Spray Suction PI 1(2)-1402-40-B pg Shutoff Valve. l
,G V
2079a - _ __. . _ _ _ _ . .
QC05 1600 1 UN!? 1(2) REVISION O
- y. Perform an independent verification of Core Spray System A in the standby lineup:
Component Position INITIAL MO 1(2)-larl 3BA Closed /
's M0 1(2) 1402-AA Closed 8 1(2)A CS PHP switch NORMAL /
- 2. Record results of visual inspection of Core Spray Subsystem A piping, valves and pump.
Rpf l>/ W
- 2. Er Core Spray Subsystem B requires testing, THEN:
- a. V_erify idle pump suction pressure above IST alert range:
(1) Record idle located at pump suction pressure P1 1(2)-1402-40B, /oc4c pump. psig (2) Verify idle suction pressure greater than 3 psig. ( ) h I ) CAUTION
!F 1(2)-1402-13B, CORE SPRAY PHP MIN FLOW SV fails to open THEN, RV 1(2)-1402-288, 1(2)B CORE SPRAY DISC HOR REV may lift draining water to the Reactor Building Equipment Drain Tank ( RBEDT).
( )
- b. Start 1(2)B CS PHP.
- c. Verify MO 1(2)-1402-38B, CS PHP MIN /
FLOW VLV opens. ( )
- d. Record 1(2)B CS PMP discharge pressure, as inoicated on PI 1(2)-1450-1B, CS HEADER PRESS. 3@
psig 9 2079a 10-
CCOS 1400-1 UNIT 1(2) REV!SION O g
)
NOTE The next step is started at this point and could continue while performing the rest of this procedure, l )
- e. Perform a visual inspection of Core Spray Subsystem B for leaks on piping, valves and A'A' pump. INit!ALS C 1 NOTE The next two steps should be done simu'taneously. MO 1(2)-1402-38B, CS PMP MIN FLOW VLV will close when pump :rischarge flow increases.
( )
- f. Thrcttle open H0 1(2)-1402-48, CS BYPASS AND TEST VLV to establish a pump discharge pressure of approximately 260 psig as indicated on PI 1(2) 1450-1B, CS HEADER PRESS.
- g. Verify MO 1(2)-1402-388, C$ PHP HIN FLOH VLV closes. (
- h. Verify pump suction pressure above IST alert range:
(1) Record pump suction pressure PI 1(2)-1402-40B, located at pump. /06('! psig (2) Verifysuctionpressuregreaterthahosig. ( )
- 1. Calculate pump discharge pressure and independently verify result:
(1) Pd . OP+Pi, with OP 257 psid and Pi . Pump running suction pressure (previous step) (2) Pd . 257 + 3 _ J68 psig Ppf fcWMed by: Yf V N IEcepencent Verification by: [
- j. Throttle 0 1(2)-1402-48, CS BYP AND TEST VLV to establish pump discharge pressure to t] pressure calculated in previous step as V indicated on PI 1(2)-1450-18, CS HEADER PRESS.
2079a _ _ _ _ _ - _ _ _ - _ - _ _ _ _ _ _ _ _ _ . _ _
QCOS 1400-1 UNIT 1(2) REVISION 0
- k. Record the follcwing A,g verify 13T criteria achieved:
TECH SPEC T. 5. PASS IST PASSED PARAMETER MEASURED LIMIT (!NITIAL) (INITIAL) 1(2) Pump 6 ~
;2 c. O psig Discharge NA NA M-Pressure PI 1(2)-1450-1B 1(2) Pump B 3/Ou gpm Discharge Flow NA NA N
F1 1(2)-1450 40
- 1. WWEN pump has run for 5 minutes in the conditions established in the above table, THEN direct vibration tester to take vibration for Core Soray Pump B (refer to Attachment A for proper points) and record results belon.
IlCH IST SPEC ACCEPTABLE PARAMETER MEASURED LIMIT Vibratton A N e In/sec N/A v il-Point H In/sec N/A 1 V In/sec N/A Vibration A In/sec N/A Point H _ In/sec N/A 4 2 V In/sec N/A Vibration A ,, In/sec N/A Point H i In/sec N/A -
\/ /
3 V V Inisec N/A {f
- m. Throttle as necessary H0 1(2)-1402-4B, CS BYP AND TEST VLV to establish a flow rate 2 4500 gpm at 1 216 psig.
G 2079a l
QCOS 1400-1 UNIT l(2) REVISION 0 (1) Pecord A10 verify Tech. Spec. criteria achieved: TECH SPEC T. S. PASS IST PASSED l PARAMETER MEASURED LIMIT (IN!TIAL) (!NITIAL) ; 1(2) Pump B .2 / k psig 216 psig Olscharge Minimum .7 NA Pressure PI 1(2)-1450-1B l(2) Pump B Wod gpm 4500 gpm
/8-i l
Discharge Flow Minimum NA FI 1(2)-1450-4B (2) Verify IST criteria for-1(2)-1402-88, CORE SPRAY DISCHARGE STOP-CK VLV 15 met by verifying flow above is > 4500 gpm ALD pressure above is 2 116 psig. (yV)
- n. Vertfy operability of 1(2)-1402-138, 1(2)B CORE SPRAY PMP MIN FLOW SV by:
(1) Open and hold for 30 sec. MO 1(2)-1402-388, . CS MIN FLOH VLV. ( ) (2) Record 1(2)B Core Spray Pump discharge-flow as indicated on FI 1450-48, CS HEADER FLOW. 4375< gpm l-(3) Calculate pump flow decrease and incependently verify result: (a) Flow' Decrease Flowivalve closed) - Flow (valve open) (b) Flow Decrease 4' G d - 'O 7 >
/ q PerfgrAed by: Independent verification by:
({ (4) Verify IST criteria for 1(2)-1402-138. 1(2)B CORE SPRAY PHP MIN FLOW SV is achievud by a minimum of 100 gpm flow' decrease abcVe. (
-(5) Close MO 1402-388, CS MIN FLOW VALVE. (
- o. IF timing of MO 1(2)-1402-48, CS BYP AND TEST VLV '
II required for completion of OCOS 1400-8, THEN time
- MO 1(2)-1402-48, CS BYP AND TEST VLv during tne performance of next step.
2079a ..... - . _ . - . - - .. . . . . . - - - . - . - . - - . . - . ~ . _ . - . . - . - . - . - . . ,--
l QCOS 1400-1 , UNIT 1(2) i REVISION O
- p. Close H0 1(2)-1402-48, CS BYP AND TEST VLV.
Verify H0 1(2)-1402-380, CS PHP HIN FLOW VLV ( [$ g q. opens as system flow decreases. ( />
)
- r. IF H0 1(2)-1402-4B was timed above, THEN record time on OCOS 1400-8.
- s. Stop 1(2)B CS PHP. (/
- t. Close MO 1(2)-1402-388. CS PMP MIN FLOW VLV. ( />
- u. E over pressure condition (90 psig) in discharge piping exists after 1(2)B Core Spray Pump is stopped, THEN: (C-18)
(1) Crack open MO 1(2)-1402-48, CS BYP AND TEST VLV to slowly reduce eressure. (2) Close MO 1(2)-1402-48, CS BYP AND TEST VLV ' when pressure reaches 90 psig, as indicated on PI 1(2)-1450-18, CS HEADER PRESS. (
- v. E pressure cannot be maintained af ter performing depressurization step above, THEN: (C-18)
(1) Op.e_n MO 1(2)-1402-48, CS BYP AND TEST VLV. h (2) Close_ MO 1(2)-1402-48, CS 3YP AND TEST VLV. ( (3) Fill and vent 1(2)B Core Spray Subsystem per QCOP 1400-1. Nfl),
- w. E instrumentation dampening was used THEN, perform an independent verification tnat the following instruments are valved in service:
INITIAL (1) 1(2)B Core Spray FT 1(2)-1461-8 to Side Shutoff Valve. M (2) 1(2)B Core Spray FT 1(2)-1461-B Hi Side Shutoff Valve. N (3) 1(2)B Core Spray Pmp Dsch PT 1(2)-1460-B Shutoff Vlv. MN. (4) 1(2)B Core Spray Suction PI 1(2)-1402-40-B Shutoff Valve. M/f-9 ' 2079a .
i l ! QCOS 1400-1 l UN!T 1(2) i i REVISION 0 f E. x. Perform an independent verification of Core 1 Spray fystem B in the standby lineup: I Component, Position IN!T!AL } i. MO 1(2)-1402-38B Closed 4 , j H0 1(2)-1402-4B Closed 6 [. 1(2)B CS PHP switch NORMAL
- i 2. Record results of visual inspection of
) Core Spray Subsystem B piping, valves and pump.
- 7'~t 3 7 ~ - SW i
L-i
- 3. - Verify all acceptance-criteria verification, vibration amplitude tables a!L0, calculation verification steps gf b are complete. eV #.
- 4. E this surveillance'was satisfactory, THEN:
- a. Surveillance performed by: I/ /5'03/
/ d41gnatury Date
\
b.: Surveillance reviewed by: M d' -/ SCRE Signature Date
- c. Surve111&nce approved by: - d' .__ /
r .SE Signature Date Comments: NOnt 5.: E this surveillance was unsatisfactorye THEN:
- 4. Description of Deficiencies / Comments: bk~
4
- b. Surveillance performed by A_ND Nuclear Work Request
- (NHR)-- 1 ni tia ted:
(1)- -NWR initiated:- YES' NO ,
/
Signature Date O 2079a -....a ._:.-...---..-- . - , . - . . _ - , . - . - - _ _ . - - - . - . _ . . . - . _ _ , , , , - - . . . .
OCOS 1400-1 UNIT 1(2) REVISION 0
- c. Surveillance reviewcd by A,ND: g (1) DVR initiated (T.S. LCO only): YES NO (2) E IST requirement falls into Alert Range THEN schedule component for increased testing frequency:
Increase Frequency: YES NO (3) H IST requirement falls into Required Action Range, THEN declare component inoperable. Co,nponent Inoperable: YES NO
/
__ SCRE Signature Dat-
- d. Surveillance approved by ,AND Core Spray Subsystem Report, QC05 1400-3 initiated:
(1) Core Spray Subsystem Outage Report initiated, QC05 1400-3: YES _., , 10
/
SE Signature Date
- 6. A.ttach this completed surveillance to QOS 005-54, Operatic'-
Quarterly Surveillance Test Assignment Sheet 0,,R to Core Spray Subsystem Outage Report, a appropriate. J. ATTACHMENTS
- 1. Attachment A, figure 1 Core Spray Pump Vibration Points.
( l O 2079a - .-
. _ - - _ . - - - - - . ~ - . . . - - . . - . - . _ . . - . ...-- . -. - . ... .. _.
OCOS 1400-1 UNIT l(2) REV!$10N O ATTACHMENT A FIGURE 1 CORE $ PRAY PUMP VtBRATION POINTS cou e u na g , 9 wir una w D f g gg t H AND V READINGS YAKEN AT E E W W Wh 90' APART l l O g' .
;a EL"2 H IS IN UNE WITH SUCTION AND
-mm DISCHARGE UNE l 3 mo .a w on Ng'pui j
*=:P ,=
l l O (fIna1) 2079a 17
Simulator Go Or<a Tost Preceduro Covor Sheet Test Number acos noo - e PTAO-105T1 Date Performed 3 89/ j D e s c riptio n gy,, y, ygy gg pg gy Discrepancles section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date O _ Test Results Y 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy, Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after-correction of above discrepancies.
Retest' Complete Date Test Complete [ + - -- Date 3 fr '7/ SFCC Acceptance #
! / Date 3
- J'- 7 / ,
Simulator Supervi 's A ceptance d E >fA*~- - Date ,37-9/
- c. m . ..., m ,,... Of ;
1
L L QCOS 1400-9 i UNIT 1(2) , REVISTON O 4 SAFETY RELATED ON HAND FLUSHING CORE SPRAY LINES INTO THE REACTOR 1 . h MM % 4.r-Illi) . % kYlllr %/l'?0 APPRgL'$1GNATURE TITLE Q EFFECTIVE DATE A. PURPOSE i The purpose of this procedure is to provide the steps necessary to flush the Core Spray lines into the Reactor and to test the operability of the Core Spray Check Valves during cold shutdown. B. DISCUS $f0N
- 1. QOS 005-4, IST --
- !alve Position Indication Surveillance may be performed if requi ed.
2.- Where brackets, ( ) are-provided in the procedure, place'a check to indicate--step compl9 tion. IC. REFERENCES
- 1. Technical Specifications 3.5 A./4.5.A., Core Spray Subsystems and '
LPCI Mode of the RHR System,
-2.- Technical Specifications 3.5 G./4.5.G., Maintenance of Filled Discharge ~ Piping.
- 3. M-36 (M-78), Diagram of Core-Spray Piping.
- 4. OCOP 1400-1, Core Spray System Preparation for Stanaby Operation.
- 5. QCOP-1400-3. ECCS Fi11: System.
- 6. QCOS 1400-3, Core Spray Subsystem Outage Report.
- 17. 005'005-S16, Oserations-Department Cold-Shutdown Test Assignment Sheet. ,
- 8. 0AP: 350-510,. IST Valve' Surveillance Acceptance Criteria Summary Sheet.
- 9. QAP 350-1, Administration of the Inservice Testing Program.;
.. 10. FSAR 6.2.3., Core Spray Subsystem.
.. . . 11. Inservics Testing Program.
--2083'a <
.-+-.m,_ ..-,,-,..,_,-...-.e .,-..,,c.- , , . . , . . . - -,..-,.3 r .. ...e-,--.-m._, _,.-.___,,mrew,e----e.- .,--r-rw.s-y n-, , . n .-v - 3 .- g
OC05 1800-9 UNIT 1(2) REVISICN 0
- 12. Eentsburg Letter to R. Bai cated 10-28-85, Operational Guidelines for Motor Operated Valves.
- 13. DVR 4-1-87-047, B Core Spray Header <40 psig.
- 14. NRC Bulletin SB-04 Potential Safety Related Pump Loss.
- 15. Quad Cities Nuclear Station Writers Guide, Revision I, January 31, 1990.
D. EOUIPMENt REOUIRED None. E. PREREQUISITES
- 1. The Shift Engineer has completed the following:
- a. LNIT 3/H1 '
)(2)
- b. Reason for test (check appropriate item):
Normal Surveillance ( )(') Post Maintenance ( ) Partial for __ ( ) O Other ( )
- c. Permission to start test:
/ **
, 3'Y'#7(l 0 SE Sig. de Date/ Time
- 2. Reactor water level betkeen 20 - 30 inches. ( /)
- 3. Reactor in Cold Shutdown condition. ( /)
- 4. Suppression Chamber level greater than 10 feet. ( v')
- 5. Core Spray System in standby lineup per QCOP 1400-1. ( v[ ,-
- 6. At least one Reactor Recirculation Pump running. ( />
- f. PRECAUTIONS None, G. LIMITATIONS AND ACTIONS
- 1. At the comoletion of the surveillance the SCRE must innectatelv revlea the results of this test for compliance to Tech Spec and IST requirements.
2083a 1
OCOS 1400-9 UNIT 1(2) REVISION O
- 2. Motor Operated Valves Guidelines: (C-12)
{
- a. A maximum of five starts within a one minute period, followed by a 30 minutes cooling off time.
- b. The valve is operatie during the cooling off period.
- c. WHEN throttle valves are required to adjust flon or pressure, THEN it may be necessary to wait a few seconds to abide by this guideline.
- 3. Do N_0_T perform this test if water addition to the steam lines will adversely affect scheduled tests (e.g. LLRT) or maintenance. '
- 4. WHEN a Core Spray Putnp is run in the minimum flow mode of operation for a time period 6xceeding 10 minutes, THEN notify the Technical Staff IST group to perform a vibration analysis to ensure no pure degradation has occurred. Although the pump shall not be declared iroperable, the vibration analysis should be performed within 7? hours. (C-13)
- 5. This test is perfctmed in cold shutdown, but N_0,T more frequently than once every 3 months. (C-9)
- 6. If reactor pressure is less than 325 psig, THEN:
bd a. H01(2)-1402-25A/B, CS PMP OUTBD DISCH VLV can be opened regardless of MO )(2)-1402-24A/B, CS PHP INB0.0!SCH VLV position. ' AND.
- b. H0 1(2)-1402-24A/B, CS PHP INBD DISCH VLV can on1J be open if H0 1(2)-1402-25A/B, CS PMP OUTBD DISCH VLV is T311 closed.
- 7. ,If only partial testing of Core Spray System is required, THEN:
- a. Ensure all prerequisites are met.
- b. Steps for Subsystem A OR B in section I. may be performed independently as identI7ied in the procedure, B_U,T the analysis steps performed after testing must be completed.
H. PERFORMANCE ACCEPTANCE CRITER!A
- 1. Core Spray lines were flushed to the Reactor Vessel.
- 2. Core Spray discharge flow of at least 4700 gpm (4500 gpm Tech Scec requirement plus 200 gpm added for posstole thermal sleeve leakage) was achieved to demonstrate tr.at A0 1(2)-1402-9A(B). CS CHECK VLV stroked to its full open position. (C-i, C-10)
O (O 2083a . .. -
QCOS 1400-9 UNIT 1(2) REVf510N 0
- 1. PROCE00RE
- 1. I_F, Core Spray Subsystem A requires tetting, THEN:
- a. Lower reactor water level to approximately 20 inches @ record. 11 inchei
- b. $ tart 1(2)A CS PUHP,
- c. Verify MO 1(2)-1402-38A, CS PHP HIN FLOW VLV opens. (V )
( ) NOTE The next step is to prove the operability of AO 1(2)-1402-9A, CS CHECK Vi.V . The next step must be performed in rapid succession to prevent raising Reactor water level unnecessarily.
, I i
- d. A0 1(2)-1402-9A, CS CHECK VLV: g (1) Throttle gpfen HO 1(2).1402-2SA, CS SMP OUTBD DISCH VLV to establ%sh a flow rate at least 4700 gpm at indicated on FI l(2)-1450-4A, CS iiEADER / LOW.
(2) Record W 1)A CS PHP discharge flow, as indicJted on FI 1(2)-1450-4A, C5 HEADER FLOW. .D 6 O gpm (3) Immediatel y 5, lose H0 1(2)-1402-25A. ( VI (4) Verify open H0 1(2)-1402-38A, CS NIN FLOH VLV.
- e. Record final reactor wuer level. N t 11c he s
- f. Verify final reactor water leval is greater than ,
initial level A,!Q record difference. T inches 9 Verify A0 1(2)-1402-9A, CS CHECK VLV opened fully / by purup flow recordeo above > 4700 grm. ( V)
- h. 5,f2p 1(2)A CS PUMP.
- i. Close H0 1(2)-1402-3aA, CS HIN FLOW YLV. ;
2083a -
QC05 1400-9 UNIT 1(2) REVISION O
/
- j. E over pres',ure condition (90 psig) in discharge
( piping exists /,fter 1(2)A Core Spray Pump is stopped, THEN; (C-12) l (1) Crack open 60 i(2)-1402-4A, CS BYP AND TEST VLV to sh wiv teduce pressure. (2) Close MO 1(2)-1402 4T CS BYP AND TEST VLV E wnen pressure reachu 90 psig, as indicated on / PI 1(2)-1450-1A, CS HtADER PRESS. ( V) k, E pressure cannot be maint0lm d after performing depressurization step abov6, THENc (C-12) (1) Open MO 1(2)-1402-4A, CS 3YP AND TEST VLV. (2) Close MO 1(2)-1402-4A, CS BYP AND TEST VLV. WO (3) Fill and vent 1(2)A Core Spray Subsystem per QCOP 1400-I. (/0)
- 1. Perform independent verification 74 Ore 5 pray System A in the standby lin w u Component Position INITIAL
( MO 1(2)-1402-2SA Closed / M 1(2)-1402-38A Closed d?
+
4 1(2)-1402-4A Closed ## 1(2)A CS PMP switch NORMAL /@n
- 2. E Core Spray Subsystem B requires testing, THEN:
- a. Lower reactor water level to approximately 20 inches @ record. 20 inches b SjjLrj ((2)B CS PUMP.
i Vt.r ' ' MO 1(1)-1402-38B CS PMP MIN FLOH VLV opens. ( O 20B3a l
QCOS 1400-9 UNIT 1(2) REVISION O ( ) N.21 The next step is to prove the operability of A0 1(2).1402 9B, CS CHECK VLV. The next step must be performed in rapid succession to prevent raising Reactor water level un1ecessarily. [ ]
- d. A0 1(2).1402-98, CS CHECK VLV:
(1) Throttle open M0 1(2).1402 25B, CS PMP OUTBD DISCH VLV to establish a flow rate at least /- 4700 gpm as indicated on FI 1(2)-1450-4B, CS HEADER FLOH. (2) Record 1(2)B CS PHP di charge flow, as indicated on FI 1(2)-1 50-4B, CS HEADER FLOH. 5700
- gpm ,
(3) Immediate1v close M0 1(2)-1402 258. ( VI (4) Verify open M0 1(2)-1402-388 CS MIN FLOH VLV. 1 /
- e. Record final reactor water level. AL
, inches Verify final reactor water level is greater than f. initial level AND record difference. 4 inches
- g. Ver m A0 1(2)-1402-9B, CS CHECK VLV opened fully /
_by pump flow recorded above 1 4700 gpm. ( '/5
- h. Stop 1(2)B CS PUMP.
- 1. Close MO 1(2)-1402-388, CS MIN FLOW VLV. (t/5
- j. 1F over pressure condition (90 psig) in discharge piping exists after 1(2)B Core Spray Pump is stopped, THEN: (C.12)
(1) Crack osan MO 1(2L !402-48, CS BYP AND TEST VLV to slow;'t ieduca pressure. (2) Close MO 1(2)-1402 48, CS BYP AND TEST VLV when pressure reaches 90 psig, as indicated on / PI 1(2)-1450-18, CS HEADER PRESS. (V) 2083a '
QCOS 1400-9 UNIT 1(2) REVISION 0-O k. IF pressure cannot be maintained after performing O depressurization Step above, THEN:-(C-12) , (1)- Open M0 1(2)-1402-48 CS BYP-AND TEST VLV.
~
(2)- Close M0'1(2)-1402-48, CS BYP AND TEST VLV. (MN
-( 3) Fill-and vent 1(2)B Core Spray Subsystem per QCOP 1400-1. (8db
- 1. Perform independent verification of Core Spray System B in the standby lineup:
Component Position INITIAL H0 1(2)-1402-25B Closed HO 1(2)-1402-3BB Closed /h
^
MO .l(2)-1402-4B Closed _
-1(2)B CS PMP switch NORMAL _
3 Return the Reactor water level to level as specified by SE or SCRF,. ([ 1
- 4. ' Return Suppression Chamber water level to level directed by Shift Engineer as appropriate for present plant conditions. ( )
- 5. LF, F this surveillance was satisfactor ,=THEN: ,
- a. Surveillance performed by ._ e / "$ ' P * / /'
(ygnature Date b, Surveillance reviewed by: /-
-SCRE Signature Date. ~
c '. Surveillance approved by: / _SE Signature Date Comments: A./v/G C-
- 6. _If., this surveillance.was unsatisfactory, THEN:
- a. ' Description of Deficiencies / Comments: 2/A 2083a __ - _ __ -_ - -- _ _ _ _ - - _
QCOS 1400-9 UNIT 1(2) REVISION 0
- b. Surveillance performed by A.!LD Nuclear Work Request (NHR) Initiated:
(1) NWR initiated: YES NO
/
Signature Date
- c. Surveillance reviewed by AJ:
(1) DVR initiated (T.S. LCO only): YES NO
/
SCRE Signature Date d, Surveillance approved by AND Core Spray Subsystem Outage Report, QC05 1400-3 initiated: (1) Core Spray Subsystem Outage Report initiated, QC05 1400-3: YES , NO
/
SE Eignature Date 7, Attach this completed surveillance to 00S 005-516, Operations Department Cold Shutdown Test Assignment Sheet 0,3 to System Outage Report, as appropriate, J. ATTACHMENTS None. P s O tfinal) 2083a -B-
Simulator dm Oner Tost Procedure- Cover Sheet Tect Number acos asoo-/ O' Test Date Performed 3 U '/ / Description MortrHLy RfC/ ('#Mf OfEM6(6/Ty TEST Discrepancies- section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date Ih Test Results
- 1. Test Completed Satisfactorily
- 2. After correction of the above discrapancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after-correction of gbove discrepancies.
Retest Complete Date Test Complete / s ~ k' Date J 74/ SFCC Acceptance s /de.--- - Date .3 7 'f / v..- g 7 Simulator Supervisor's Acceptance ~ Date JP CP/ c.c.co, se. n u u-ea
QC05 2300-1 UNIT 1(2) _l REVISION 0 SAFETY'RELATED ON HAND-MONTHLY HPCI PUMP OPERABILITY TEST _
. 57R710hl AMWAGEL l'/f 9f TITLE EFFECTIVE APPROVAL SIGNMUR[ ~
DATE A. PURPOSE Provide the necessary steps to perform Tech. Spec. Monthly HPCI' pump run.
.B. : DISCUSSION
-1. QCOS 2300-3, Monthly HPCI Motor Operated Valve Test, may be performed in--conjunction with this test.
.2.- .!F QC05 2300-5,- Quarterly HPCI Pump Operability Test, is performed, IIIEN this monthly test is not required since the quarterly test fulfills monthly Tech Spec requirements.
3,- khere brackets, ( ). are provided in the procedure, place a check to indicate- step completion.
.C. REFERENCES
- 1. -Technical Specifications 3.5 C/4.5.C, HPCI Subsystem.
L2; Technical Specifications 3.2/4.2, Protective Instrumentation.
'3.- -Technical Specifications 3.5.G/4.5.G, Maintenance of Filled Discharge Pipe.
{ 4; Technical Specifications'3.7.A.6/4.7 A.6,' Containment Systems, .- Drywell- Suppression Chamber Differtntial Pressure.
- 5. . M-46-(M-87), Diagram of HPCI-Piping.
6.- C00407.(GEK 9597), Equipment Manual, Volume IV. 7.- C00480 (GEK 32367A).-Process Instrument Subsystem of the t'igh Pressure Coolant Injection System.
-8. C001078 (GEK 15545),.HPCI Turbine Manual.
'2318a- ,
l
~ . . . . .
QCOS 2300-1 UNIT 1(2) REVISION O O
- 9. 0AP 300-10, Operating Records.
- 10. QAP 300-T6, Suppression Chamber Level Operating Range.
- 11. QC0A 2300-8, HPCI Turning Gear Fails to Start or Engage Automatically on a Coastdown.
- 12. QCOS 2300-2, HPCI Outage Report.
- 13. QCOS 2300-3, Monthly HPCI Motor Operated Valve Test.
- 14. QCOS 2300-5, Quarterly HPCI Pump Operability Test.
- 15. OCOS 2300-6, Quarterly HPCI System Power Operated Valve Test.
- 16. QCOP 2300-1, HPCI Preparation for Standby Operation.
- 17. QCOP 2300-4, HPCI System Shutdown.
- 18. QHPH 2300-1, HPCI Refuel Preventive Maintenance.
- 19. 00P 1600-3, Drywell Pressure Relief Through Reactor Building Ventillation System.
- 20. QOP 1600-21, lA and 2A Drywell and Torus 01fferential Pressure Control System Start-Up.
- 21. (X)P 1600-22, IA and 2A Orywell and Torus Differential Pressure Control System Shutdown.
- 22. FSAR 6.2.5, HPCI System.
- 23. INPO Finding (1987) TS-5-2.
- 24. K. Graesser Letter to N. Kalivianakis dated 12-4-85, ECCS Pump Minimum Flow Valves.
- 25. IE Information Notice No. 82-26, RCIC and HPCI Turbine Exhaust Check Valve Failures.
- 26. Eenigenburg Letter to R. Bax dated 10-28-85, Operational Guidelines for Motor Operated Valves.
- 27. Quad Cities Nuclear Station Procedure Hriters GL'de, Revision 1, January 31, 1990.
D. EOUIPMENT REQUIRED None. O 2318a OCOS 2300-1 UNIT 1(2) REVISION O A:
!Q E. PREREQUISITES
- 1. The Shift Engineer has completed the following:
- a. UNIT S/e n [t )
1(2)
- b. Reason for test (check appropriate item):
Normal Surveillance ( Y) Post Maintenance ( ) Partial for ( ) Other ( )
- c. Permission to start test:
/
ihe SESignapre 3?-9ft Dk)L Date/ Time
- 2. HPCI in standby line-up per QCOP.2300-1 ANO suction is from CCST.
(d fi 3. Torus water level is at the low end of operating band per L/ QAP 300-T6.. Suppression Chamber Level Operating Range. ( vT 4, The Unit is off EGC control. ( /)
/5 Hydrogen _ Water Chemistry System shutdown at least /
L/ 30 minutes prior to the performance of this test. ( /)
- 6. ' Radiation Protection personnel have been notified AND are supplying personnel to accompany operator during- /
survelliance performance. ( V) F. PRECAUTIONS
- 1. Injection of HPCI into Reactor during power operation could cause a reactivity transient.
- 2. System operation below 5000 gpm should be' minimized to limit cycling of turbine exhaust check-valve. (C-25).
- 3. Be prepared to stop manual cperations if HPCI automatic start-signal-is-received.
- 4. On manual restart after turbine trip, do NOT reset the_ turbine stop valve until turbine speed is below 800 rpm (20% of rated speed).
(C-7). t-
- 5. On turbine trip, manual or automatic, do NOT stop the auxiliary oil pump until turbine slows to turning gear speed (i.e. 10 rpm). (C-7).
2318a .
QCOS 2300-1 UNIT 1(2) REVISION O
- 6. Ensure personnel near the HPCI turbine are aware of the impending O
test and the potential for steam leaking around the turbine.
- 7. Operation of HPCI will cause a slight increase in Torus pressure.
This in turn will increase Drywell pressure by operation of the Drywell/ Torus dP control system. If desired, shutdown the dP control system in accordance with QOP 1600-22 in order to avoid excessive pressure in the Drywell. (C-4) G. LIMITATIONS AND ACTIONS
- 1. E HPCI becomes inoperable, THEN perform QCOS 2300-2.
- 2. WHEN HPCI suction is from CCST, THEN minimize the time that MO 1(2)-2301-14, MIN FLOH BYP VLV is open to prevent draining CCST to Torus.
- 3. E MO 1(2)-2301-14, MIN FLOW BYP VLV, falls to open for pump minimum flow protection, THEN immediately trio HPCI turbine Ay perform QCOS 2300-2. (C-24)
- 4. E MO 1(2)-2301-!4, MIN FLOW BYP VLV, fails to ciose where required, THEN g utdown HPCI per QCOP 2300-4 Aj perform QCOS 2300-2 (C-24)
- 5. FIC 1(2)-2340-1, HPCI FLOW CONTROLLER must be set at 5600 gpm and in AUTO upon completion of this test for HPCI to De operable.
- 6. Maintain eccentricity AND vibration indications within the following:
- a. E eccentricity exceeds 10 mils when on turning gear, THEN investloate the cause before proceeding with the test.
- b. E eccentricity exceeds 5 mils when on turning gear, THEN remain on turning gear until eccentricity is less than 5 mils.
- c. E vibrations exceed 5 mils, THEN notify SE AND Tech Staff System Engineer for vibration evaluation,
- d. E vibrations exceed 13 mils, THEN immediately trip the HPCI turbine, notify SE, AJ perform QCOS 2300-2.
- 7. HPCI lube oil temperature limits are:
l a. Bearing discharge TI 1(2)-2340-9, HPCI TURB OIL BRG TEMP points 2,3 and 4. (1) 180*F maximum (140*F - 160*F normal),
- b. Maximum oil temperature rise acress any bearing of 50*F.
l 2318a QCOS 2300-1 UNIT 1(2) REVISION O O l 3 NOTE
.I,[ an automatic initiation signal is present and the isolation signal is reset, THEN MO 1(2).2301-4, STEAM ISOL VLV and M0 1(2).2301 5, STM ISOL VLV will automatically open.
[ ]
- 8. HPCI isolation signals are: (C.2).
- a. HPCI Turbine area high temperature; 170'F. (Manual reset on 901(2).3).
- b. HPCI steam line high flow; 300% of rated steam flow with approximately a 3 second time delay. (Manual reset or, 901(2).3),
- c. Reactor Vessel low pressure; 100 psig. (Automatic reset on increasing pressure).
- 9. HPCI Turbine trips are: (C-7)
[ } NOTE Item G.7 a - G.7.f will close the HPCI TURB STOP VLV, Item G.7 b - G.7.e will-close MO 1(2)-2301 8, HPCI PMP DISCH VLV and HPCI TURB STOP VLV. WHEN HPCI isolation signal (s) AN_0 Turbine trip signal (s) is cleared AM an HPCI initiation signal is present, THEN HPCI will automatically restart. [ ]
- a. Turbine overspeed; 5100 rpm.-
- b. High Reactor Vessel' water level; +48 inches,
- c. Low Booster Pump suction pressure; 15 inches Hg vac.
- d. High HPCI Turbine exhaust pressure; 100 psig.
- e. Remote Turbine Trip; Pushbutton.
Local Manual Trip Lever. f. 2318a 5-
1 QCOS 2300-1 UNIT 1(2) REVISION O O
- 10. Drywell/ Torus dP may be decreased to less than 1.20 psid for a maximum of 4 hours during required operability testing of the HPCI pump.(C-4)
- 11. Motor Operated Valves Guidelines: (C-26)
- a. A maximum of five starts within a one minute period, followed by a 30 minute cooling off time,
- b. The valve is fully operational during the cooling off period.
l c. When throttle valves are required to adjust flow or pressure, l it may be necessary to wait a few seconds to abide by this I guideline.
- 12. Torus temperature limitations and actions: (C-4)
- a. WHEN HPCI pump is operating for testing, THEN Torus I temperature shall be continually monitored and logged per QAP 300-10, every 5 'nutes until testing is terminated,
- b. E Torus temperature reaches 105'F during HPCI pump testing, i THEN terminate pump testing AND reduce Torus temperature below l 95'F within 24 hours.
l 13. CCST level shall be maintained greater than 9.5 feet. (C-3)
- 14. Operation of HPCI will add volume to the Torus pool. Maintain normal torus level per QAP 300-T6.
- 15. Performance acceptance criteria verificatiot, must be completed prior to final acceptance of this procedure.
- 16. At the completion of the surveillance the SCRE must immediately review the results of this test for compliance to Tech Spec and IST r egi eemen t s .
- 17. E mponent falls to perform or falls to meet Tech. Spec.
re. .ments, THEN notify Shift Engineer. H. PERFORMA,(JCCEPTANCE CRITERI A
- 1. HPCI pump developed a flow rate of 25000 gom at a discharge i
pressure of 21250 psig (discharge pressure corresponding to Reactor pressure of greater than 1150 psig). (C-1) O I 2318a QCOS 2300-1 UNIT 1(2) REVISION 0 0 I. PROCEDURE ( ) NOTE Eccentricity is monitored at panel 901(2)_7, recorder 1(2)_5640-60, ECCENTRICITY AND VIBRATION at PNT 15 HPCI TURBINE ECCENTRICITY. Vibration is monitored at panel 90)(2)_7, recorder 1(2)_5640-60, ECCENTRICITY AND VIBRATION at PNT 13, HPCI TURBINE VIBRATION BRG NUM i and PNT 14, HPCI TURBINE VIBRATION BRG NUM 2. ( )
- 1. Place HPCI Turbine on turning gear as follows:
[ ] NOTE The Turbine Low Speed Indication at Panel 901(2)_3 operates only if the auxiliary oil pump is ON. The Turbine Low Speed Indication at
/N Panel 901(2)-3 will go out if the HPCI Turbine is engaged and the AUX
( OIL PHP is ON. The indication will not operate if only the EMER,_ OIL PHP is ON. L 3
- a. Verify HPCI Turning Gear ENGAGED itght QN.
- b. Verify TURNING GEAR MTR control switch is in NORKAL,
- c. Start the AUX OIL PUMP.
- d. IF Turning Gear Motor does Ngi start automatically, THEN deDress TURNING GEAR RESET button.
- e. [F Turbine fatis to go on Turning Gear, THEN refer to QC0A 2300-8.
- f. WHEN Turning Gear Motor starts, THEN start EMERG OIL PUMP AND stop AUX OIL PHP.
- g. Verify Turning Gear engaged properly by PNT 15 HPCI TURBINE ECCENTRICITY at recorder 1(2)-5640-60, ECCENTRICITY AND VIBRATION on panel 901(2)_7 increases above zero.
1 l 2318a -7
QCOS 2300-1 UNIT 1(2) REVISION 0
- 2. Verify HPCI Turbine has been on turning gear for at least 3 hours -
0 OR eccentricity less than 5 mils,
- 3. Verify an operator in attendance in the HPCI rcom t'o check for leakage of the HPCI piping, valves, turbine and pump during turbine operation.
4, Record TORUS LVL. O.E
- inches L 5. Verify FIC 1(2)-2340-1, HPCI FLOW CONTROLLER setpoint at 5600 gem l MLO in AUTO.
l l
- 6. E normal service water supply to HPCI Room Cooler is N, LOT in operation, THEN start Unit 1(2) Diesel Generator Cooling Hater Pump to supply water to Room Cooler. N' Started (Y/N)
L 7. E desired, place the local switch for the HPCI Room Cooler in MANUAL for continuous operation throughout this test.
- 8. Start GLAND SEAL LEAKOFF BLOWER.
l 9. Open H0 1(2)-2301-15, HPCI TEST RTN VLV. l
- 10. Verify MOTOR SPEED CHANGER at LSi (Low Speed Stop). O
- 11. Verify HOTOR GEAR UNIT at HSS (High Speed Stop).
l 12. Close A0 1(2)-2301-64, ORAIN VLV and A0 1(2)-2301-65, ORAIN VLV.
- 13. Start AUX OIL PHP by placing control switch to MANUAL.
- 14. Open H0 1(2)-2301-3, HPCI TURB STH SPLY VLV.
- 15. Verify H0 1(2)-2301-14, MIN FLOW BYP VLV opens.
- 16. Verify following alarms:
- a. HPCI-TURBINE TRIPPE0
- b. HPCI PUMP LOW FLOH
- 17. Depress HPCI IURB TRIP RESFT pushbutton to open HPCI Turbine Stop Valve.
- 18. Verify HPCI TURBINE TRIPPED alarm clears.
l 2318a I QCOS 2300-1 UNIT 1(2) REVISION O N V 19. Orain moisture from the inlet steam line as follows:
- a. Open drain valves A0 1(2)-2301-64, ORAIN VLV ANC A0 1(2)-2301-65, DRAIN VLV for approximately I~~;econds 0 AND THEJ close A0 1(2)-2301-64, DRAIN VLV l A q A0 liN301-iI DRAIN VLV.
( ) CAUTION HPCI System operation below 5000 gpm should be minimized to limit ;;ycling of the Turbine Exhaust check valve.(C-25) ( )
- 20. Roll Turbine as follows:
- a. Increase Turbine speed by turning MOTOR SPEED CHANGER to SLOW '
RAISE in small increments.
- b. Verify Turning Gear is disengaged as speed increases.
- c. E Turning Gear does not disengage, THEN manually disengage it
[O by pulling cown on the local hand lever at Turning Gear.
- d. Stop increasing speed at 1900-2100 rpm on 1(2)-2300-TI-1, HPCI TUR8 SPEED.-
- 21. Stop TURNING GEAR MTR AND return control switch to NORMAL.
- 22. Open MO 1(2)-2301-10 TEST RETURN VLV.
- 23. Verify H0 1(2)-2301-14 MIN FLOW BYP VLV closes.
- 24. - Increase Turbine speed until the flow setpoint of 5600 gpm is reached by turning MOTOR SPEED CHANGER to SLOW RAISE.
- 25. Verify MOTOR GEAR' UNIT is controlling Turbine speed by:
- a. Observina no change in Turbine speed as MOTOR SPEED CHANGER is run in SLOW RAISE.
- b. Continue running MOTOR SPEED CHANGER in SLOW RAISE for additional 3 seconds after reaching HSS.
- 26. Stop EMERG OIL PUMP, O
2318a OCOS 2300-1 UNIT 1(2) REVISION O
- 27. Stop AUX OIL PHP by placing control switch to AUTO.
O
- 28. Verify proper operation of FIC 1(2)-2340-1, HPCI FLOW CONTROLLER:
- a. Reduce FIC 1(2)-2340-1 AUTO setpoint by approximately 100 gpm AJ verify corresponding flow reduction. ( 7)
- b. Return FIC 1(2)-2340-1 setpoint to 5600 gem A_g verify corresponding flow increase. ( #,,)
- c. Transfer FIC 1(2)-2340-1 to MANUAL. ( /)
- d. Decrease FIC 1(2)-2340-1 MANUAL signal by approximately 100 gpm AND verify corresponding ,
flow reduction. (V) Increase FIC 1(2)-2340-1 MANUAL signal e. A,ND verify Corresponding flow increase. ( /)
- f. Transfer FIC 1(2)-2340-1, HPCI FLOH CONTROLLER to AUTO A.@ setpoint of 5600 gpm. ( " -)
- 29. Slowly throttle H0 1(2)-2301-10, TEST RETURN VLV to establish 1250 to 1275 psig as indicated on PI-2340-2, HPCI PHP DISCH PRESS, ( /) h
( ) NOTE Eccentricity is monitored at panel 1(2)-5640-60, ECCENTRICITYANDVIBRATIONatPNT@201(2)-7, recorder HPCI TURBINE ECCENTRICITY. Vibration is monitored at panel 901(2)-7, recorder 1(2)-5640-60, ECCENTRICITY AND VIBRATION at PNT_13T HPCI TURBINE VIBRATION BRG NUM i andPNTi4)HPCITURBINEVIBRATIONMGNUM2. f [ ] O 2318a QCOS 2300-1 UNIT-1(2) REVISION O O 30. Record: iECH SPEC 1. S. PASS PARAMETER MEASIIRED LIMIT (INITIAL) HPCI Turetne */ ( S' psig Inlet NA NA Pressure PI 1(2)-2340-4 HPCI Pump S ro o gpm 5000 gpm 01scharge Flow Minimum FI 1(2)-2340-1 AND
/W
. HPCI Pump ! IL aru psig 01scharge 1250 psig Pressure PI 1(2)-2340-2 Minimum HPCI Pump A% pstg-Inlet NA NA Pressure PI 1(2)-2340-7 HPCI Turb1ne 4cm rpm Speed NA NA 1(2)-2300-TI-1 HPCI Turbtne f- pstg Exhaust NA NA Pressure PI 1(2)-2340-5 HPCI-Bearing ,2a miis E mils Vibration BRG BRG NA NA NUM1 NUM2 1(2)-5640-60 1
- 31. Shutdown the HPCI Turbine as follows:
- a. Start AUX OIL PMP by placing switch to MANUAL. #
- b. Start GLAND SEAL CLG HTR PHP. /
./
- c. Open MO 1(2)-2301-49, CLG RTN TEST VLV.
- d. Close MO 1(2)-2301-48, CLG RTH NORM VLV.
- e. ' Depress REMOTE HPCI TURB TRIP pushbutton .
- f. Close MO 1(2)-2301-3, HPCI TURB STM SPLY VLV. (d
- g. Verify close MO 1(2)-2301-14, MIN FLOW BYP VLV. ( /)..
- h. viose MO 1(2)-2301-10, TEST RETURN VLV. ( /)
, 2318a .. . .
l QCOS 2300-1 UNIT 1(2) REVISION O
- 1. Verify e MOTOR SPEED CHANGER at LSS (Low Speed Stop).
j, Open A0 1(2)-2301-64, ORAIN VLV and - A0 1(2)-2301-65, ORAIN VLV. ( V) ( ) NOTE HPCI turbine should remain on turning gear for a minimum of 3 hours after shutdown, ( ) k, WHEN HPCI Turbine speed reaches zero, / THEN depress TURNING GEAR RESET pushbutton / g verify HPCI Turbine goes on turning gear.
- 1. IF HPCI does NOT go on turning gear, THEN perform QC0A 2300-8,
- m. Start EMERGENCY Olt PUMP.
- n. Stop AUX OIL PHP by placing control switch to AUTO (
h ( ) NOTE A minimum of 10 minutes should elapse from time of shutdown prior to performing the next step. ( ) o, Stop GLAND SEAL LEAKOFF BLOHER AND place control switch to AUTO position 7 (vi
- p. Monitor eccentricity as indicated on 1(2)-5640-60, ECCENTRICITY AND VIBRATION recorder PNT 15. HPCI TURBINE ECCENTRICITY is less than 10 mils.
Q. Stop the lube oil cooler system as follows: N 2318a QCOS 2300-1 UNIT 1(2) REVISION O (: ) NOTE Gland Seal Leakoff 310we should be shutdown prior to performing the next step, l 3 (1) HHEN HPCI oil cooler outlet temperature drops below 120*F as indicated on TR 1(2)-2340-9, HPCI TURB AND DH TEMPS, Pt. 1, THEN stoD GLAND SEAL CLG HTR PHP. ( A < (2) Close MO 1(2)-2301-15,- TEST RTH VLV. (d (3) Close MO 1(2)-2301-49, CLG RTN TEST VLV. (d
-(4) Open MO 1(2)-2301-48, CLG RTN-NORM VLV, (
- r. WHEN 3' hours has elapsed since HPCI placed on turning gear, THEN:
(1) Stoo EMERG OIL PUMP NA,NO place switch to AUTO. ( vi (2) Verify HPCI turning gear off as indicated by ,
. green OFF indicating light on TURNING GEAR MTR. ( V)
-- ( 3 ) E HPCI turning gear falls to stop, THEN:
(a) Place HPCI TURNING GEAR MTR control swttch'to PULL-TO-LOCK position. (b) After several minutes place to NORMAL position. (Mk (c) Verify HPCI turning gear off as indicated by-green OFF indicating light on TURNING GEAR MTR. ( NM,-
- 32. Stoo diesel generator cooling water pump if started. (Ad 33, IF local control switch for HPCI Room Cooler was placed to' MANUAL, THEN return switch to AUTO. (N
- 34. Record final TORUS LVL and verify within QAP 300-T6. / A-inches
- 35. E containment pressure is excessive, THEN vent containment in accordance with 00P 1600-3, Drywell O Pressure Relief through the Reactor Building Ventilation System, as necessary to reduce containment pressure to normal.
2318a . _ _ _ _ _ _ _ - _ - _ _ - _ - _ _ _ _ _ _ _ _ _ _
M QCOS 2300-1 UNIT 1(2) REVISION O Record results of visual inspection of HPCI during pump run. O 36.
$1W ,U W
- 37. Perform independent verification HPCI in the standby lineup per QCOP 2300-1 by following:
Component Position INITIAL MO I(2)-2301-3 Closed M i MO 1(2)-2301-14 Closed M~ MO 1(2)-2301-10 Closed [87 M0 1(2)-2301-15 Closed /4
)
MO 1(2)-2301-49 Closed /k MO 1(2)-2301-48 Open e A0 I(2)-2301-64 Open 8 A0 1(2)-2301-65 Open l l AUX OIL PHP switch AUTO /8'} GLAND SEAL BLOWER switch AUTO GLAND SEAL CLG PHP switch STOP /$- FIC 1(2)-2340-1 AUTO at 5600 gpm TURNING GEAR HTR switch NORMAL EMERG OIL PUMP switch AUTO /
- 38. If the Drywell/ Torus dP control system was shutdown to test HPCI, THEN start the dP control system in accordance with 00P 1600-21, IA and 2A Orywell and Suppression Chamber Differential Pressure Control System Startup.
l l I I O I 2318a QCOS 2300-1 UNIT 1(2) REVISION 0 O" 39. If, this surveillance was satisfactory, THEN:
- a. Surveillance performed by: u - / 3 '78[
,/ SPgnature Date
- b. Surveillance reviewed by: /ud /
SCRE Signature Date
- c. Surveillance approved by: /
SE Signature Date Comments: IOb
- 40. E this surveillance was unsatisfactory, THEN:
- a. Description of Deficiencies / Comments: MI
- b. Surveillance performed by, Nuclear Hork Request (NHR) initiated:
Q V (1) NHR initiated: YES NO
/
Signature Date
- c. Surveillance reviewed by, DVR initiated:
(1) DVR initiated (T.S. LCO oniv):YES NO
/
SCRE Signature Date
- d. Surveillance approved by HPCI Outage Report, QCOS 2300-2 initiated:
(1) HPCI Outage Report initiated, QCOS 2300-2: YES , NO
/
SE Signature Date
- 41. Attach this completed survelliance to 005 005-53, Operations Monthly Surveillance Test Assignment Sheet OR to QCOS 2300-2, HPCI Outage Report, as appropriate, J. ATTACHMENTS None.
(final) 2318a - - _ _ _ _ _ _ _ _ _ _ _ _ _ _
Simulator OWo O/r/cr Tost Procedure Cover Sheet Test Number ecos 230o-/3 PTAO-105T1
'O V Test Date Performed 3 U 9/
Descriptlon Qgf gygg ggg fy, g gg7 2 Discrepancies Section of Test Diseropancy Corrected item # Comments Requiring Report # (initials) Retest and Dato i
-i Test Results I 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfcetoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after correction of above discrepancies.
Retest Complete Date Test Complete / A- - 'h Date 3 - 7 '1 / SFCC Acceptance / - .- y/ Date 3'70' Simulator Supervisor's A ceptance /.4 e Date Jf-9/ I c.c.co. ee-i2is i2-se
QCOS 2300-13 UNIT 1(2) REVISION O
\
SAFETY RELATED ON HAND } HPCI SYSTEM MANUAL INITITATION TEST A . S W M M n?!}.,, _ jfl9f9l > APPROVAL SIGNATURE TITLE EF FEC TIVE DATE A. PURPOSE Provide steps for-the testing of HPCI to demonstrate the capability of HPCI System to respond to a quick startup from an initiation signal, B. DISCUSSION
- 1. This test will perform a manual initiation _of the HPCI System with conditions estabitsbed to provide a discharge flow path returning to the CCST instead of the Reactor.
- 2. This~ test need only.be performed once per cycle unless Operating Department Management deem more frequent testing is necessary.
A G- 3.. Where brackets, ( , ), are provided in the procedure, place a check to indicate step completion. ; C. REFERENCES 1 l '. Technical Specifications 3.5.C/4.5.C. HPCI Subsystem.
- 2. -Technical Specifications 3.2/4.2, Protective Instrumentation.
3 . .- -Technical Specifications 3.5.G/4.5.G, Maintenance of Filled Discharge Pipe. 4._ Technical Speelfications 3.7 A/4.7 A,_ Containment Systems, Primary
-Containment.
5.- -M-46 (M-87), Olagram of H,P. Coolant Injection Piping.
- 6. C00407 (GEK 9597), Equipment Manual, Volume IV.
-7. C00480 (GEK 32367A), Process Instrument-Subsystem of the High Pressure Coolant injection System.
O 2210a QCOS 2300-13 UNIT 1(2) REVISION O
- 8. QAP 300-10, Operating Records.
- 9. QAP 300-T6, Suppression Chamber Level Operating Range.
l 10. QCOA 2300-8, HPCI Turning Gear Falls to Start or Engage Automatically on a Coastdown.
- 11. QCOS 2300-1 Monthly HPCI Pump Operability Test.
- 12. QCOS 2300-2, HPCI Outage Report.
- 13. QCOS 2300-5, Quarterly HPCI Pump Operability Test
- 14. QCOP 2300-1, HPCI Preparation for Standby Operation.
- 15. QCOP 2300-4, HPCI System Shutdown.
- 16. QOP 1600-22, l A and 2A Orywell and Torus Differential Pressure l Control System Shutdown.
- 17. QOP 1600-3, Drywell Pressure Relief Through Reactor Building Ventilation System.
- 18. QOP 1600-21, l A and 2A Drywell and Torus Differential Pressure Control System Startup.
- 19. QNPN 2300-1, HPCI Refuel Preventive Maintenance
- 20. FSAR 6.2.5, HPCI System.
- 21. General E'actric Service Information Letter (SIL) No. 336
- 22. IE Information Notice No. 82-26, RCIC and HPCI Turbine Exhaust Check Valve' Failures.
- 23. Eenigenburg Letter to R. Bax dated 10-28-85, Operational Guidelines for Motor Operated Valves.
1
- 24. K. Graesser Letter to N. Kalivianakis dated 12-4-85, ECCS Pump Hinimum Flow Valves.
- 25. Qu6d Cities Nuclear Station Procedure Writers Guide, Revision 1, January 31, 1990.
D. EQUIPMENT REOUIRED
- 1. Callbrated Stopwatch.
E. PRERE0VISITES
- 1. The Shift Engineer has completed the following:
- a. UNIT 1(2) 2210a QCOS 2300-13 UNIT 1(2)
REVISION O n
- b. Reason for test (check appropriate item):
Normal Surveillance ([ Post Maintenance ( ) Partial for Other ( )
- c. Permission to start test:
m, /' Y.29// 6%
' d i Signard'e Date/ Time
- 2. HPCI in standby.line-up her QCOP 2300-1 except for y MO 1(2)-2301-10, TEST RETURN VLV. (V) L
- 3. Torus water level.is at-the low end of operating band per
( [) QAP 300-T6. Suppression Chamber Level Operating Range.
- 4. The Unit is off EGC control. ( /)
- 5. HPCI Turbine is tripped. ( V -)
( 6. Verify steam pressure to HPCI Turbine from PI 1(2)-2340-4, HPCI TUR8 INLT PRESS.is 920-1005 psig. (/)
- 7. Stopwatch 10 no.: 7/ Mb Next Cal date: .
4jtrfsst & v
- 8. Radiation Protection personnel have been notified A_,f0 are supplying personnel to accompany operator during surveillance performance. (g) 9.. An operator in attendance.at 250 VOC Reactor Building .
MCC 1A(2A). (MN). F. ' PRECAUTIONS
- 1. HPCI~will be inoperable for an automatic initiation during.this test. E the.Immediate action requirements of QC05 2300-2 are fulfilled prior to this test, THEN the four. hour Emergency Notification System (ENS) phone call and DVR/LER are not required.
-2. Manu'al injection using HPCI, QCOP 2300-6 is still possible during
.this procedure because M0 1(2)-2301-8 HPCI PHP OISCH VLV can be.
operated from its control switch after closing the MO 1(2)-2301-8 breaker, Injection of HPCI Into Reactor during power operation could cause a p) 4 3. reactivity transient. 2210a QCOS 3300-13 UNIT 1(2) RPliSION O
- 4. System operation below 5000 gpm should be minimized to limit cycling of turbine exhaust check valve (C-22)
- 5. Operation of HPCI will cause a slight increase in torus pressure.
This in turn will increase drywell pressure by operation of the Drywell/ Torus dP control system. If desired, shutdown the dP control system in accordance with QOP 1600-22 in order to avoid excessive pressure in the drywell. (C-16)
- 6. Be prepared to stop manual operations if HPCI automatic start signal is received.
- 7. On manual restart after turbine trip, do N_0T reset the turbine stop valve until turbine speed is below 800 rpm (207, of rated speed).
(C-7)
- 8. On turbine trip, manual or automatic, do MT stop the auxiliary oil punip until turbine slows to turning gear speed (i.e. 10 rpm) (C-7)
- 9. Ensure personnel near the HPCI turbine are aware of the Impending test and the potential for steam leaking around the turbine.
G. LINITATIONS AND ACTIONS
- 1. E HPCI becomes inoperable, THEN perform QCOS 2300-2,
- 2. WHEN HPCI suction is from CCST, THEN minimize the time that M0 1(2)-2301-14, HIN FLOH BYP VLV is open to prevent draining CCST to Torus.
- 3. FIC 1(2)-2340-1, HPCI FLOW CONTROLLER must be set at 5600 gpm and in AUTO upon completion of this test for HPCI to be operable.
- 4. Maintain eccentricity @ vibration indications within the following:
- a. E eccentricity exceeds 10 mils when on turning gear, THEN investicate the cause before proceeding with the test.
- b. E eccentricity exceeds 5 mils when on turning gear THEN remain on turning gear until eccentricity is less than 5 mils,
- c. E vibrations exceed 5 mils, THEN notify SE @ Tech Staff System Engineer for vibration evaluation,
- d. E vibrations exceed 13 mils, THEN immediately trip the HPCI turbine, notify SE and Tech Staff System Engineer, A,g perform OCOS 2300-2.
- 5. HPCI lube oil temperature limits are:
- a. Bearing discharge TI 1(2)-2340-9, HPCI TURB OIL BRG TEMP points 2,3 and 4.
2210a OCOS 2300-13 UNIT 1(2) REVISION O (1) 180'F maximum (140'F - 160*F normal).
- b. Maximum oil temperature rise across any bearing of 50'F.
( ) N0li 1F an automatic initiation signal is present and the isolation signal is reset, THEN H0 1(2)-2301-4, STEAM 150L VLV and H0 1(2).2301 5, STM 150L VLV will automatically open. ( ) 6, HPCI isolation signals are: (C.2)
- a. HPCI Turbine area high temperature; 170'F. (Minual reset on 901(2).3)
- b. HPCI steam line high flow; 300% of rated steam flow with approximately a 3 second time delay.
(Manual reset on 901(2)-3)
- c. Reactor Vessel low pressure; 100 psig. (Automatic reset on increasing pressure) t
- 7. HPCI Turbine trips are: (C-7)
( ) NOTE Item G.7.a - G.7.f will close the HPCI TURB STOP VLV. Item G.7.b - G.7.e will close HO 1(2)-2301-8, HPCI PHP DISCH VLV and HPCI TURB STOP VLV. WHEN HPCI isolation signal (s) AND Turbine trip signal (s) is cleared AND an HPCI initiation signal is present, THEN HPCI will automatically restart. ( )
- a. Turbine overspeed; 5100 rpm.
- b. High Reactor Vessel water level; +48 inches.
- c. Low Booster Pump suction pressure; 15 inches Hg vac,
- d. High HPCI Turbine exhaust pressure; 100 psig.
() e. Remote Turbine Trip: Pushbutto.
- f. Local Manual Trip Lever 2210a -5
QC05 2300-13 UNIT 1(2) REVISION O
- 8. Torus temperature limitation 3 and actions: (C-4) 9
- a. WHEN HPCI pump is operating fer testing,
'THEN Torus temperature shall De cont 5nually monitored ind logged per QAP 300-10, every 5 minutes until testing is terminated,
- b. .!F Torus temperature reaches 105'F during HPCs pump testing, THEN terminate pump testing AND reduce Tcrus temperature below 95'F within 24 hours.
- 9. CCST level shall be maintained greater than 9.5 feet.(C-3)
- 10. Operation of HPCI will add volume to the Torus pool. Maintain ~
normal torus level per QAP 300-75. l I 11. IF H0 1(2)-2301-14, HIN FLOW BYP VLV, fails to open f or pump minimem f fow protection, THEN irnmediately trio HPCI turbine AND perform QCOS 2300-2. (C-24)
- 12. IF MO 1(2)-2301-14, MIN FLOW BYP VLV, falls to close where required, THEN shutdown HPCI per QCOP 2300-4 A,jl0 perform QCOS 2300-2 (C-24)
- 13. This test should normally be performed during the startup af ter eacti refueling outage at plant conditions when more than two (2) bypass valves are open or when the generator is on-line at greater than g
90 MWe.
- 14. Restoration steps after the Turbine is shutdown to standby may be performed independently A)LD may be performed in conjunction with the shutdown to standby step.
- 15. At the completion of the tervelliance the SCRE Sust. immediately review the results of this test for conpliance to Tech Spec requirements.
- 16. JF a component fails to perfor n or falls to meet Tech. Spec.
requirements, THEN notify shift Engineer.
- 17. Drywell/ Torus differential pressure may be decreased to less than 1.20 psid for a maximam of 4 hours during required operability testing of the HPCI pump. (C-4)
H. PERFORMANCE ACCEPTANCE CRITERIA l 1. HPCI Turbine starts and reaches flow setpoint of 5600 gpm within 45 l seconds when given a Manual Initiation ' signal. (C-20) i 1 2210a i I
OC05 2300-13 UNIT 1(2) ._ REVISION O e I. PROCEDURE
- 1. Verifv MO 1<2)-2301-10, REST RETURN VLV, is in mtdoosition as Ivt from perforining QC03 2300-5 at least 72 hours ago. ( V , ')
- 2. yerify an ope cator to attefidanco In the HPC.! rco EE to check for leakage of the HPCI piping, valves, 3
turbine and p ec during turbine operation. (M 3, Pecord TORUS LVL from LR 1(2)-1602-7, TORUS PRESS F f ANO LVL. /.4 inches 4 V_er m FIC 1(2)-2340-1, h8CI FLOW CONTROLLER _ setpotnt at 5600 gpm Ag in AUTO. ( )
- 5. LF normal service wat2r supply to HPCI Room Cooler is :'
NOT in operation, THEN start Unit 1(2) Diesel Generator
/U
~
Cooling Hater Pump to supply watr'r to Room Cooler, ,, Started (Y/N)
- 6. IF desired, place the local switch for th HPCI Room -
C6cler in StiAl for continuous operaticn throughout ' this test. 9
- 7. Qpen e H0 1(2)-2301-15, TEST RTN VLV. ( v)' k
[ ] NOTE Conditions will be established for the remainoyr of this test which - will prevent the automatic opening of H01(2)-2:01-8, HPCI PHP DIScit VLV and the automatic closing of H01(d-2301-10 TEST RETURN VLV and H0 1(2)-2301-15. TEST RTH VLV upon receipt of a y HPCI initiation signal either MANUAL 03 AUTOKATIC. - ( ) (
- 8. E MANUAL OR AUTCNATIC INITIATION of HPCI is required r during this tert ,Ty_pf: -.
~
- a. Close breaker for H0 1(2)-2301-15, TEST RTN VLV
/
at 250 VDC Reactor Building MCC 1A(2A) A,N_D verify gut H0 1(2)-2301 15, TEST RTH VLV. T f
- b. Close breaker for MO 1(2)-2301-8, HPC1 PHP OISCH VLV [
at 250 VDC Reactor Building NCC 1A(2A) AE L verify o_ge,n, MO 1(2)-2301 8, HPCI PHP DISCH VLV. e i 2210a L
OCOS 2300-13 UNIT 1(2) ~ REVISION O
- 9. Open_ the following breakers to prevent the associated G
valve movement during the remainder of the test:
- a. HO 1(2)-2301-8. HPCI PHP DISCH VLV at 250 VDC Reactor Building MCC 1 A(2A), b * "* ( ~/~ .[<r(
7
)
MO 1(2) 2301-10, TEST RETURN VLV at lA m b ""
- b. '
250 VDC Reacor Building MCC IA(2A), , ( )
- c. MO i(2)-2301.15, TEST RTN VLV at 250 VDC Retctor Building MCC 1A(2A),j b st; M) *"
- 70. Verify the following switch lineup:
- a. MOTOR SPEED CHANGER at LSS (Luw Speed Stop) and in NEUTRAL, ( )
- b. MOTOR GEAR Lt.!T at HSS 'H11h Speed Stop) y and in NEUTRAL. ( )
- 11. yerify HPCI turning gear off as indir.atN by greae OFF light on TURNING GEAR MTR, ( )
- 12. Prepare stopwatch to time the period from when t-ne HPCI HANUAL INITIATION pushbutton is depressed until flow of 5600 gpm is first indicated C3 flC 1(L)-2340-1. H7CI FLOH CONTROLLER.
Initiep HPCI Syst am as follcws:
- a. DeDress HPCI MANUAL INITIATTON pushbutton A
f hold until MOTOR SPEED CHANGER reaches HSS (High speed stop),(Approximately 20 seconds) ( )
- b. Time the HPCI System response from Initiation to llow of 5600 gpm.
o I 2210a _ _ - _ - - - - - _ _ _ _ _ _ - -
OC05 2300-13 UNIT 1(2) AEVISION O O 13. R_e1Ej the followin; af ter flow has been stabilind at tne flow setpoint, i4CCEPTABLE~ PARAMETER HEASURED LIMIT (INITIAL) Initiation 45 sec , Time to 4/,35 ,see Maximum O '"- 5600 gpm iiPC'. Turbine 920 to Inlet 9 7 I psig 1005 psig di, - Pressure P1 1(2)-2340-4 '~ HPCI Pump Discharge Flow C/, 'TC gem NA NA FI 1(2)-2340-1 HPCI Pump Inlet AA psig NA N6 Pressure P1 1(2)-2340-7 HPCI Pump 1200 to Discharge Pressure
/ Loo pstg 1300 psig A Pl~1(2)-2340-2 HPCI Turbine Speed 400c- rpm NA NA 1(2)-2300-TI-1 IiPCI Turbine Exhaust Pressure
.(- psig NA NA Pl~1T2)-2 340-5 Reactor Pressure 44 6 psig NA NA P! 1(2)-263-156 HPCI Bearing 2. L mi I s g_mi i s Vibration BRG BRG NA Nr.
NUM1 NUM2 1(2)-5640-60 . O 2210a .g.
OC05 2300-13 UN!f 1(2) REV.:10N 0
- 14. Perform the following to restore the HPCI System:
0
- a. Close the following breakers:
(1) HD 1(2)-2301-8, HPCI PHP DISCH VLV at 250 VCC Reactor Butiding MCC 1A(2A). ( /) (2) H0 1(2)-2301-10. TEST RETURN VLV at 250 VDC Reacer Butiding MCC 1A(2A). ( V) { (3) MO 1(2)-2301-15. TEST RTN VLV at , 250 VDC Reactor Building MCC 1A(2A). ( (A
- 15. Shutdown the HPCI Turbine as follows:
- a. Start AUX Olt PMF ith control switch to MANUAL. ( f) g
- b. Start GLAND SEAL CLG WTR PHP. (/)
- c. Open H0 1(2)-2301-49, CLG RTN TEST VLV. ( ()
- d. Close H0 1(2)-2301-48. CLG RTN NORM VLV. ( )
- e. Depress REMOTE HPCI TURB TRIP pushbutton . ( /I
- f. Clos 2 HD 1(2)-2301-3, HPCI TURB STM SPLY VLV. ( V')
- g. Close HQ 1(2)-2301-14, HIN FLOW BYP VLV. ( V)
- h. Close HD 1(2)-2301-10 TEST RETURN VLV. ( V')
- 1. Verify HOTOR SPEED CHANGER at LSS (Low Speed Stop). ( V)
- j. DeDress MISC DRAIN VLV RESET. ( /)
- k. Verify open A0 1(2)-2301-64 DRAIN VLV, and _.
A0 1(2)-2301-65, ORAIN VLV. ( A
- 1. Verify open A0 1(2)-2301-29 DRAIN VLV, and ./
A0 1(2)-2301-30 ORAIN VLV. (' )
- m. Verify closed A0 1(2)-2301-28, ORA!N TRAP TO ORAIN POT VLV. ( /)
9 2210a __ _ _ - _ _ _ - _ __
OCOS 2300-13 UNIT 1(2) REVISION 0 O ( } NOTE HPCI turbine should remain on turning gear for a minimum of 3 hours after shutdown, t 3
- n. WHEN HPCI Turbine speed reaches zero, IHEN depress TURNING GEAR RESET pushbutton M Q verify HPCI Turbine goes on turning gear.
- o. IF HPCI does NOT go on turning gear, TIiEN perform @ A 2300 8.
< p. t _},Lr.1EMERGENCYO!LPUMP. -( M Q. StoD AUX O!L PMP by placing control switch to AUTO. (d
-l )
NOTE A minimum of 10 minutes should elapse from time of shutdown prior to O' performing the next step. ( )
- r. },tpp GLAND SEAL LEAKOFF BLOWER 9 9 place control switch to AUTO position. ( v1
- s. Verify eccentricity as indicatto on 1(2)-5640-60. ECCENTRICITY AND VIBRATION recorder PNT 15, HPCI TURBINE ECCENTRICITY is less than 10 mils.
- t. Stop the tube oil cooler system as follows:
(. 3 NOTE Gland Seal Leakoff Blower should be shutdown prior to performing the next step. ( ) (1) WHEN HPCI oil cooler outlet temperature drops below 120'F as indicated on TR 1(2)-2301-9 HPCI TURB AND DW TEMPS, Pt. 1. THEN stoD O GLAND SEAL CLG WTR PHP. ( y) V (2) Close H0 1(2)-2301-15. Test RtN VLV. ( /) 2210a .. . .
QCOS 2300-13 UNIT 1(2) REVISION O (3) Close MO 1(2)-2301-49, CLG RTN TEST VLV. ( v) (4) Open MO 1(2)-2301-48. CLG RTN NORM VLV. ( 7) ,
- u. WHEN 3 hours has elapsed since HPCI placed on turning gear, THEN:
(1) Stop EMERG Oil PUMP AND place switch to AUTO. ( V) (2) Verify HPCI turning gear off as indicated by 1reen OFF light on TURNING GEAR MTR. ( /) (3) H HPCI turning gear falls to stop, THEN: (a) Place HPCI TURNING GEAR MTR control switch to PULL-TO-LOCK position. (b) After several minu'es place HPCI Turning Gear MTR to %RMAL position. ( V. ) (c) Verify HPCI turning lear off as indicated by green Off inilcating Ilght on TURNING GEAR MTR. ( j)
- 16. E diesel generator cooling water pump var started, THEN stop pump. (0/i
- 17. IF local switch for HPCI room cooler was Diated in MANUAL, THEN return it to AUTO. ( 4/f
- 18. Record final TORUS LVL AJ verify within O P 300-T6. /< ?
Inches I 22104 OCOS 2300-13 UNIT 1(2) REVISION 0
- 19. Perform and r_ecord independent verification HPCI in the standby lineup per QCOP 2300-1:
Component Position INITIAL MO 1(2)-2301-3 Closed /D M0 1(2)-2301-14 Closed ["# N0 1(2)-2301-10 Closed M HO 1(2)-2301-15 Closed /$ MO 1(2)-2301-49 Closed M MO 1(2)-2301-48 Open M A0 1(2)-2301-64 Open ed A0 1(2)-2301-65 Open M AUX OIL PHP swltch AUTO GLAND SEAL BLOWER switch AUTO M GLAND SEAL CLG PHP switch STOP /_4 FIC 1(2)-2340-1 AUTO at 5600 gpm A TURNING GEAR MTR switch NORMAL />' EMERG~ OIL PUMP swltch AUTO < <7
- 20. If containment pressure is excessive, vent containment in accordance with-QOP 1600-3. Drywell Pressure Relief Through the Reactor failding Ventilation System, as necessary to reduce containment pressures to normal.
- 21. If the Drywell/Yorus dP control system was shutdown to test NPCI Start the dP control system in accordance with-QOP 1600-21. IA and 2A Orywell_and Suppression Chamber dP Control System Start-up.
22. Ethissurveillancewassatisfactojr,THENj, a. Surveillance performed by:[dignatu ' /# r M/ Date , b. Surveillance reviewed by: A//Y / l SCRE Signature Date
- c. . Surveillance approved by: _/
- SE Signature Date Comments: ND 22104 -13
QCOS 2300-13 UNIT 1(2) REVISION O
- 23. E this surveillance was unsatisfactory, THEN:
O
- a. Description of Deficiencies / Comments:
- b. Surveillance performed by, Nuclear Work Request (NWR) initiated:
(1) NHR initiated: YES NO ,_
/
Signature Date
- c. Surveillance reviewed by, DVR initiated:
(1) DVR initiated (T.S. LCO oniv):YES NO __,
/
SCRE Signature Date
- d. Surveillance approved by, HPCI Outage Report, QCOS 2300-2 initiated: g (1) HPCI Outage Report initiated QCOS 2300-2:
YES NO
~
/
5E Signature Date
- 24. Attach this completed $Urveillance to 005 005-56, Operations Refueling Outage and Operating Cycle Surveillance Test Assignment Sheet OR to HPCI System Outage Report, QCOS 2300-2, as appropriate.
J. MTACHMENTS None, O l (final) 2210a Simulator Cup dern Tost Procoduro Cover Sheet Test Number aos z'>oo-/ t Om oete eer<ormee // /z ">o Desctiption S g~ g g y, p.y gggyp(nm)pog,gy y 7-Discrepancies Section of Test Discrepancy Correc:ed item # Comments Requiring Report # (initials) Retest and Date O Test Results I 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above af*.er:
correction of above discrepancies. Retest Complete Date Test Complete /[f Date ll'/2-9 SFCC Acceptance . Date 3 '2 9 [ Simulator Supervisor's Acce ance DateJE-f[ c.c.co. ee n n n ee.
'l 005 2900-1 Revision 4 SArt SHUTOOWN MAKE-UP PUMP Decemeer 1988 4 (SSMP) FLOW RATE TEST A. PURP Q L l The* purpose of this procedure.is to outline the method used to verify , safe shutco n make-up pump-(SSMP) flow rate capacity. B. REFERENCES
- 1. P S 10's.
- a. -M-70, $afe Shutdown Makeup Pump System.
~ C. PREREQUISITES r
~
- 1. - _ Safe shutdown pump 11ned up for stancby operation in accordance with procedure 00P 2900-1. ,
- 2. Notify vibration personnel of Impending test for vibration readings.
0.- PRECAUTIONS
- 1. Monitor contaminated-condensate. Storage _ tank level during safe 4
shutdown pump operation.
- 2. Anytime during plant operation that the pump suction v lve is O closed,Lthe pump casing must be vented whenever the $UCtion-valve
.is opened again.
E. LIHtTATIONS AND ACTIONS 1 Once each month or after maintenance,' verify that the SSMP delivers 400 GPM against a system heaotcorresponding to a reactor vessel pressure of at least 1217 psig.
- 2. During performance of this.. surveillance an operator-should inspect l for leakage of the-SSMP piping.-valves and pump. Work requests should ce initiated as (eemed appropriate.
- 3. Upon completion of-testing, the flow indicating controller must pe-left in MANUAL, and its setpoint at 200 GPM.
l-l- 4 SSMP trips,
- a. Under. voltage,
- b. Over current.
L c. MO 2901-06 closed past-approximately its '50 gpm position. l LAy 3,. PRO %. DEC ' 91938 l 14/0481q -1 O. C. O. S. R. ; u_. ... m _ ._ . . . _ . _ . _ _ . _ _ _ . _ _ _ _ , . . . _ _ . . . _ _ . _ . . . , . - _ _ _ . _ _ _
005 29 W Revistoa a F. PROCEDUR_[
- 1. Manually start the SSMP system as follows:
N0i! . l De folicwing steps :an te performec l from the :ontrol r:>om at the 912-8 i canel or locally at the 1/2-2251-104 l panel, To control system from local panel, cla:e MCB-LOCAL selector switches (11) in LOCAL position.
- 6. Verify pump su; tion pressure available,
- b. Verify the $$MP fitw indt:ating controller is in MANUAL with the flow control value ocen 104 and the coatroller seucint is 200 gpm.
- c. OPEN MO 1/2-2901-07, throttl2 test valve,
- d. START safe shutdown makeup pump MIR 1/2-2901 FEED control switch,
- e. Place the SSMP flow indicating controller in AUTO anc sicaly increase the 55MP flew controller signal until flow is 400 GPM as indicated by flC 1/2-2940-07 on canel 912-8.
h
- f. Monitor all safe shutdown pump parameters,
- g. Monitor safe shutdown pump annunciator at 912-8 panel and take corrective action as necessary.
2, Record test results on $$MP flow rate test data sheet 005 2900-51:
- a. SSMP discharge pressure,
- b. SSMP flow rate.
- c. SSMP suction pressure.
- 3. Manually shutdown the SSMP system as follows:
- a. Place the flow indicating :entroller in MANUAL.
- b. CLOSE MO 1(2)-2901-00, injection valve if opened
- c. Depress the CLOSE button on the SSMP flow controller until flow is 200 GPM.
- d. STOP safe shutdown makeup oump MTR 1/2-2901 FEED :entrol switch.
niPROVE;
- e. CLOSE MO 1/2-2901-07, throttle test valve.
14/0481a f.EC'91968 O. C. O. S R.
005 2900 1 Revision 4
- 4. Line-up the safe snutco n pump for standby operation in ac:Or:an:e with 00P 2900-1.
(~
- 5. . verify that the safe shutdown cumo flow Indi:ating tontroller is in the MANUAL position alth its setpoint at 200 ;pm.
- 5. Report any als:recancy to the Shif t Engineer.
G. CHECELISTS
- 1. 005 2900-51, Safe Shutco.n Yateue Dume Flew Rate Test. '
- 2. CCS 005-58, Balan:e of Diant fest Assignment Sheet Operations Monthly.
H. TECHNICAL SDECIr! CAT:CN REFERENCES
- 1. None.
/
i n APPROVEJ
<7,n,3, DEC ' 91588 14/0481a 0. C. O. S. R.
1
005 2900-51
- g)
V ' SAFE SHUTOCHN MAKEUP Revision 3 Oecember 1983 PUMP FLCW RATE TEST DA fE ll'l200 CPERATOR DMd#IIO SHIFT ENGINEER IJ/A Test Procedure: QOS 2900-1 SSMP discharge pressure /2'Fo SSMP discharge flow 'foo
$$MP suction Dressure 8 SSMP follows flow ind! ating controller properly 4 HO 1/2-2901-6 valve or.erates satisfactorily /Til SSMP system returned to normal /If1 m
U The SSMP shall deliver 400 GPM against a system head corresponding to a reactor sessel pressure of at least 1217 PSIG, l Report any discrepancy to the Shift Engineer. D/rA Independent Verification of Octrability Status Fol1owIng test: il/A *Ifh Control Room Date n.'PROVEC Cid 9 3df) (final) 0.0.0,S.R. 14/0482a -1
Simulator Oaee Ore
- Test Procedure Cover Sheet Test Number aos 3 7oo-/
PTAO-105T1 O Test Dete eerformee </-<z so I Description p,,y gg,, , , y, , , , , , ere o res VRvs remn tr aeo swroouJ l l Discrepancies section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date O i Test Results
- 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retost the above after correction of above discrepancies.
Retest Complete Date Test Complets <1 Date /l-/2'% _ SFCC Acceptance .
- 6 Date @ 8 'f /
Simulator Supervisor Acc tanc Date J-f-9/ m . . ..., m ,,... Cf
005 3700-1 O REACTOR BUILDING CLOSED Revision 3 September 1990 COOLING WATER SYSTEM POWER OPERATED
. VALVE TESTING AT COLD SHUTDOWN A. PURPOSE l
The purpose of this procedure is to outline the steps necessary to verify the operability of the reactor building closed cooling water system power operated valves during COLD SHUIL.WN testing. B. REFERENCES
- 1. Inservice Testing Program.
- 2. QAP 350-1; Administration of the Inservice Testing Program.
3 B. PRERE00! SITES
- 1. None.
{ D. PRECAUTIONS
- 1. The stroking of these reactor closed cooling water power operated valves will isolate water to the equipment in the drywell. All equipment affected by the stroking of a reactor closed cooling O system power operated valve must be secured prior to the testing of the valves.
- 2. Operate each valve individually and return it to its normal position prior to operating the next valve.
- 3. If shutdown cooling is required while both-recirculation pumps are off, raise reactor vessel water level to above 90 inches as read on LI-263-101 (upper 400") on 901-4 (902-4). This instrument is calibrated for cold conditions. The 0-60" narrow range instruments on 901-5 (902-5) are calibrated hot and will read non-conservatively high in the cold con." tion. (45" actual level will indicate 60") Be cautious not to flood steam lines.
E. LIMITATIONS AND ACTIONS
- 1. Perform this test each COLD SHUTDOWN but-not more than once each 90 day period, after' valve maintenance which could affect volve operability or after valve replacement.
- 2. The- first valve stroke time shall be used fot- the record and initial operability determination.
- 3. Stroke times-shall be' measured to the nearest 1/10 of a second;
- 4. Record all data on-checklist QOS 3700-51.
APPROVED 21/0470q ' Q.C,0.S.R.
. - . _ _---.r_~ ., ~ _ _ _ , _ _ . . ._ m. _ . . . . , . . __.. ,__ ..i..._._,..-.,m, . _ , , _ , _ . , , .
005 3700-1 Revisten 3
- 5. 035 005-4, IST valve Position Indication Surveillance, may te performed in conjunction ith this procecure for applicable vat.es.
l F. PROCEDURE
- 1. Stop both reactor recirculation cumes for tne curation of the valve testing of MO 3702, 3703, and 3706.
- 2. Rack out the valve motor breakers to MO 3703 and MO 3736. >
- 3. Stroke MO 3702 and time the valve.
- 4. OPEN MO 3702.
- 5. Rack out the valve motor breaker to MO 3702 and ratt in the valve motor breaker to MO 3703.
- 6. Stroke MO 3703 and time the valve.
- 7. OPEN MO 3703.
8, Rack out the valve motor breaker to MO 3703 and rack in the valve motor breaker to MO 3706.
- 9. Stroke MO 3706 and time the valve.
- 10. OPEN HO 3706.
- 11. Rack in the valve motor breaker to MO 3702 and MO 3703.
- 12. Stroke MO 3702, MO 3703, and MO 3706 together with the control switch on 912-1
- 13. OPEN MO 3702, MO 3703, MO 3706.
- 14. Start the reactor recirculation pumps, as necessary.
G. CHECKLISTS
- 1. 005 3700-51, Reactor Buildint ed Cooling Water System Power Operated Valve Checklist - CL :utcown Tes ting.
H. TECHNICAL SPECIFICATION REFERENCES
- 1. None.
APPROVED (final) 21/04704 Q.C.O.S.R.
i p) y Reviewee Ov' Shtft Enc. Initials Date 005 3700-51 IST Coore. Revisicn 2 l l
.oper. Ena. September 1990 AN!! ,
l T.S. Supv. R(ACTOR BUILDING CLOSED COOLING HATER SYSTEM POWER OPERATED VALVE CHECKLIST - COLD SHUTDOWN TESTING OPERATOR T HSufFo UN!T**mR$N1 DATE //- / -So l l JCRE 1 Stroke Accef Stroke Time (' Tejec,b' t Valve No. Direction (Sec.) & Inits. l MO 3702 l CLOSED I @E3 I @ l l_HO 3702 l OPEN l NA l y) l l H0 3703 1 CLOSED l 'f i 8 i @ l lH03703 I OPEN l NA l Ah'd l l MO 3706 l CLOSED l 37.5 l $ l l~MO3706 l OPEN l NA l Oh l t Independent Verift:ation of Operability Status following Test: fM / Control Room Date Test Procedure: 005 3700-1 (~ V) APPROVED 13/04714 (2 " I40V 131990 d.C.O.S.R.
l Simulator Aueo Omsr Test Procedure Cover Sheet Test Number wor scoo -/ - PT AO-105T1 O Test Date Performed //-/200 - Description gygg ggg p,g pg f,j y , g gg [Ns7&MEMrx77n/ R/NC77oNAL 7BJT Discrepancies Section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Dato O Test Results
- 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are sctisfactoy. Rotest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after correction of above discrepancies.
Retest Complete Date Test Complete Date l/-/200 SFCC Acceptance 'i Date3" 2 1/
- o - -
Simulator Supervisor's Acceptance Date 3-F -9/ c.c.co. ei u n nn
UN!T SIMu!# M 005 5600-t DATE - IHz-90 Revision S y CPERATOR T rW M fe february 1939 SHIFT ENGINEER 4/A S.R./0.H. TURB!NE CONTROL VALVE FAST CLOSURE SCRAM INSTRUMENTATION FUNCTIONAL TEST A. PURPOSE The purpose of this procedure is to outline the method used to functionally test the scram circuitry assoClated with turbine control valve fast c bsure. B. REFERENCES
- 1. None.
C. PREREQUISITES
- 1. The turbine controls must be reset with-normal EHC oil pressure, D. PRECAUTIONS
- 1. Observe EHC oil pressure as normal and stable through the test.
- 2. Perform steps of this procedure in strict order to prevent an inadvertent reactor scram, E. LIMITATIONS AND ACTIONS
- 1. This test shall be performed monthly when the unit is operating.
(TS)
- 2. This test may normally be performed any time at equal to or less than-90% power, assuming stable power operation. If the unit is operating in EGC or automatic flow control, contact the Load Dispatcher and trip EGC and return the unit to manual flow control,
- 3. This RPS trip may be bypassed when turbine first stage pressure is less than that which corresponds to 45% rated steam flow (400 psi), (TS)-
F. PROCEDURE INITIAL
- 1. Verify all stop valves and control valves are open, h
- 2. Verify all four CONTROL VALVE FAST CLOSURE TEST PERMISSIVE Indicating lights are energized. 'id
- 3. Select CONTROL VALVE on the TEST SELECTOR switch located on panel 901-7 (902-7). 'pd b
APPROVED 11/0313Q APO 181999 G.C,0.S.R,
005 5000-1 Revisten 5 INtifAt
- 4. If turbine first stage pressure is >45%. proceed to step F.6. 'M
- 5. If tureine first stage pressure if <45%, remove fuse 590-726A in panel 901-15 (902-15) TB "A" F-18 l to remove " TURBINE PRESS. GEN. LOAD REJECTION &
STOP VALVE SCRAM BYPAS5" 10
- 6. Close #1 control valve by depress',g the butten marked #1 STOP VALVE / CONTROL VALVE TEST 901-7 (902-7). During the final one inch of j valve stroke, the fast acting valve is operated. r1
- 7. Verify " CHANNEL A/B TURB/ GEN LOAD MISMATCH" half scram alarm and cnannel "A" groups I through 4 scram solenoid valves de-energize as indicated on panel 901-5 (902-5).
4 __
- 8. Release the pushbutton and observe that the control valve opens. M
- 9. Verify all four CONTROL VA:VE FAST CLOSURE TEST PERMISSIVE indicating lights are energized. 4!
- 10. Reset the " CHANNEL A/B TURB/ GEN l SAD HISMATCH" half scram.
a'l l
- 11. If turbine first stage pressure is >45%, proceed to step F.14 41 l
- 12. If turbine first stage pressure is <451, install fuse 590-726A in panel 901-15 (902-15) 'B"A"F-18. k/
- 13. If turbine first stage pressure is <45%, remove fuse 590-726C in panel 901-15 (902-15) TB"E"F-18. dM
- 14. Close #2 control valve by depressing the button marked #2 STOP VALVE / CONTROL VALVE TES1, 901-7 (902-7). d,
- 15. Repeat steps F.7. , F.8. , F.9. , and F.10. for #2 control valve. $1
- 16. If turbine first stage pressure is >45%, proceed to step F.19. 'glI l
- 17. If turbine first stage pressure is <45%, install fuse 590-726C in panel 901-15 (902-15) TB"E"F-18. d/l
- 18. If turbine first stage pressure is <45%, remove fuse 590-726B in panel 901-17 (902-17) TB"A"F-18. Ij//
APPROVED ll/0313q APRI8889 Q C.O.S.R.
l 005 5600 1 Revisten 5 IN!TIAL O,. 19. Close #3 control va've by depressing the button marked #3 STOP VALVE /CCNTROL VALVE TEST 901-7 (902-7). YM
- 20. Verify " CHANNEL A/B TURB/ GEN LOAD MISMATCH" half scram alarm and channel "B" groups 1 through 4 scram solenoid valves de-energize as indicated on panel 901-5 (902-5), di1
- 21. Release the pushbutton and observe that the control valve opsns. Tr!
- 22. Verify all four CONTROL VALVE FAST CLOSURE TEST PERHISSIVE indicating lights are energized. <ri
- 23. Reset the " CHANNEL A/B TURB/ GEN LOAD MISMATCH" half scram, il
- 24. If turbine fi/st stage pressure is >4$%, proceed to. step F.27. _d T _
- 25. If turbine first stage pressure is <45%, install fuse 590-7268 in panel 901 17 (902-17) TB"A"f 18. d/4
- 26. If turbine first stage pressure is <45%, remove fuse 590-7260 in panel 901-17 (902-17) TB"E"F-18.- 4
- 27. Close #4 control valve by depressing the button marked #4 STOP VALVE / CONTROL VALVE TEST 901-7 (902-7). dr1
- 28. Repeat steps F.20., F.21., F.22. and F.23. for #4- -
control valve. .<t1
-29. If turbine first stage pressure is <45%, install-fuse 590-7260 in panel 901-17 (902-17) TB"E"F-18. NA-
- 30. Select "0FF" on the test selector switch located on panel 901-7 (902-7). 861
- 31. Report'any system discrepancies to the Shift' Engineer. If one or both RPS trip channels are inoperable,_ refer to Tech Spec Table 3.1-3. QOS 500-01 should be filled out.
- a. If a control valve does not cause a 1/2 scram for one trip--
channel, a 1/2 scrain must be manually taken for that channel,
- b. If control valves do not cause a 1/2 scram for both trip channels, either all control rods must be inserted within 4 hours, or tne MSIV's must be closed within 8 hours.
APPROVED
.11/0313q APR 181989 ;
Q.C.O.S.R. 1
l
@5 5(M.
Re.ision 5 C. The above actions may be cleared once lots is re'futed to .U t the stram function is automatically bypassed at less than 400 psi turbine first stage pressure. Indecenctnt verifi:ation of operability status follcwing test: A
, 8JfA Control Room 2 ate G. CHECKLISTJ
- 1. QOS 005-53, Operations Monthly Surveillance fest Assignment Sheet.
- 2. 005 500-01, RPS Instrumentation Outage Report.
H. TECHNICAL Sptc!r! CATIONS REFERENCES
- 1. Table 4.1-1.
- 2. Table 3.1-3, RPS Instrumentation Requirements in the RUN mode.
- 3. Notes 2.A. and 2.C. In Table 3.1-4.
O APPROVE (final) APR 181989 11/03130 Q.C.O.S.R. 1
Simulator M MO 07/65 Test Proceduro Covor Shoet Test Number aos 5soo a PTAO-105T1 i]' Test Date Performed //-d'70 - Description 7,)g,gg gyny, ggyg e gg;7agg g 7 ,4 g ,,g ,y g g g g 7g g ,,, facenc+//l. Tes7-Discrepancies section of Test Discrepancy Corrected item # Comments Requiring Report # (initials) Retest and Date W Test Results
- 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests resaits UNSATISFACTORY. Retest the above after correction of above discrepancies.
Retest Complete Date Test Complete , Date k-l3)0 SFCC Acceptance Date _3 7 'l / Simulator Supervisor's0Accept 6nce
~
4g' Date Jf 9/ f c.c.co. n.m s u.n
f b UNITG&UOTotI"'D QOS 5600-2 DATE INP'>v Revision 5 i OPERATOR T *f M fo June 1989 SHI,FT ENGINEER Ma S.R./0.H. TURBINE STOP VALVE CLOSURE SCRAM INSTRUMENTATION FUNCTIONAL TEST A. PURPOSE The purpose of this procedure 15 to outline the method used to functionally test the scram circuitry associated with turbine stop valve closure. B. REFERENCES
-1. None.
C. PRERE0VISITES
- 1. The Turbine must be reset with normal EHC oil pressure.
l
- 0. PRECAUTIONS
- 1. Observe EHC oil pressure as normal and stable throughout the test.
- 2. Perform steps of this procedure in strict order to prevent an inadvertent reactor scram.
E. LIMITATIONS AND ACTIONS
- 1. This test shall be performed monthly with the unit operating. (TS)
- 2. This test may normally be perfortned any time at equal to or less than 90% power, assuming stable power operation.- If the unit is operFing in EGC or automatic flow control, contact the Load Olsp echer and trip EGC and return the unit to manual flow control.
- 3. This RPS trip may be bypassed when the turbine first stage pressure is less than that which corresponds to 45% of rated steam flow (400 psi). (TS)
F. PROCEDURE INITIAL
- 1. Select STOP VALVE on the TEST SELECTOR switch located -
on panel 901-7 (902-7). $1 2,- If, turbine first stage pressure is >45%, proceed to step F.4 O-
- 3. If turbine first stage pressure is (45%, remove fuse 590-726A In panel 901-15 (902-15) TB "A" F-18 to remove
" TURBINE PRESS. GEN. LOAD REJECTION & STOP VALVE SCRAM
, BYPASS". M APPROVED i 10/0305q. 1-0W i Q.C,0.S.R. l _ m. _.m_. _ . . _ -_ . _ . . _ _a.u_.____._..._,,._._,..____._._.2.
005 5600-2 Revision 5 INIT!AL ,
- 4. Verify stop valve relays 590-124A thru H are energized. 5
- 5. Depress #1 and #2 stop valve test pushbuttons on panel 501-7 (902-7) to close the valves to the 90% open ,
position. d
- 6. Verify " CHANNEL A/B STOP VLVS CLOSE TRIP" half scram and groups 1 through 4 scram solenoid valves de-energize. 4
- 7. Immediately release the stop valve test pushbuttons and j observe the stop valves open to the full open position. r1
- 8. Reset the " CHANNEL A/B STOP VLVS CLOSE TRIP" half scram. 0
- 9. If tu bine first sta t pressure is >45%, proceed to step F.12.
4
- 10. If turbine first stage pressure is (45%. Install fuse 590-726A in panel 901-15 (o02-15) TB"A"F-18. '3[/.
- 11. If turbine first stage pressure is <45%, remove fuse 590-726C in panel 901-15 (902-15) TB"E"F-18. d
- 12. Verify stop valve relays 590-124A thru H are energized. $
- 13. Oepress the #3 and #4 STOP VALVE TEST pushbutton to close the valves to the 90% open position. 41
- 14. Verify " CHANNEL A/B STOP VLVS CLOSE TRIP" hslf scram and groups I througn 4 scram solenoid valves de-energize. ',H
- 15. Immediately release the stop valve test pushbuttons and observe the stop valves open to the full open position. 'bl
- 16. Reset the " CHANNEL A/B STOP VLVS CLOSE TRIP" half scram, ,'
r l
- 17. If turbine first stage pressure is >45%, proceed to step F.F.
1_
- 18. If turbine first stage pressure is <45%, install fuse 590-726C in canel 901-15 (902-15) TB"E"F-18. M
- 19. If turbine first stage pressure is <45%, remove fuse 590-7268 in 901-17 (902-17) TB"A"F-18. %j
- 20. Verify stop valve relays 590-124A thru H are energized. M l
- 21. Depress the #1 and #3 STOP VALVE TEST pushtutton to ,
close the valves to the 90% open position. @ 10/0305q Awrwvdc NOV I O 1989 Q.C.O.S.R.
005 5600-2 Revision 5 O .
- 22. Verify " CHANNEL A/B STOP VLVS CLOSE TRIP" half scram and groups I through 4 scram solenoid f#
valves de-energize.
- 23. Immediately release the STOP VALVE TEST pushbuttons and obser've the stop valves open to the full open position. #n 24 Reset the " CHANNEL A/B STOP VLVS CLOSE TRIP" half scram. h
- 25. If turbins first stage pressure is >45%, proceed to step F.28.
b
- 26. If turbine first stage pressure is <45%. Install fuse 590-726B in panel 901-17 (902-17) TB"A"F-18. d/A
- 27. If turbine first stage pressure is (45%, remove fuse 590-7260 in panel 901-17 (902-17) TB"E"F-18. IIf/s
- 28. Verify stop valve relays 590-124A thru H are energized. 'Di _
l
- 29. Depress #2 and #4 STOP VALVE TEST pushbutton to close the valves to the 90% open position. TH
- 30. Verify " CHANNEL A/B STOP VLVS CLOSE TRIP" half scram and groups I through 4 scram solenold
( valves de-energize. 41
- 31. Immediately release the STOP VALVE TEST pushbuttons and observe the stop valves open to the full open position. 41
- 32. Reset the " CHANNEL A/B STOP VLVS CLOSE TRIP" half scram. 'i,n
- 33. If turbine first stage pressure is <45%, Install fuse j 590-7260 in panel 901-17 (902-17) TB"E"F-18. NA /
- 34. Select "0FF" on the-test selector switch located on panel 901-7 (902-7).
- 35. Report any system discrepancies to the Shif t Engineer. If one or both RPS trip channels are inoperable, refer to Tech Spec Table 3.1-3. QOS 500-01 should be filled out,
- a. If one or more stop valves do not cause a 1/2 scram for one trip channel, a 1/2 scram must be manually taken fer that channel,
- b. If one or more stop valves do not cause a 1/2 scram for both trip channels, either all control rods must be inserted within 4 hours, or the HSIVs must be closed within 8 hours.
O A:emovgo 10/0305q Q.C,0.S.R.
005 5600-2 i Revision 5
- c. The above actions may be cleared once load is reduced to hsre the scram function is automatically bypassed at less than 4LO psi tureine first stage pressure.
Independent verification of operability J status following test: 'NA d4 Control Room Date G. CHECKLISTS
- 1. QOS 005-S3, Operations Monthly Surveillance Test Assignment Sheet.
- 2. QOS 500-01, RPS Instrumentation Outage Report.
H. TECHNICAL SPECIFICATION REFERENCES
- 1. Table 4.1-1,
- 2. Table 3.1-3, RPS Instrumentation Requirements in the RUN nede.
- 3. Notes 2.A. and 2.C in Table 3.1-4.
G AP PR O V d C, g NOV 101989 (fina1) 10/0305q C.C.O.S.R. 1
Simulator d u e d m ser Test Procoduro Cover Sheet Test Number ~ vos sa- f ~ PT A O-10 5 T'? > O T est oate ee<<ormee //-<> '>> Description gggm g, g g __ Discrepancies Section , of Test Discrepancy Corrected . Item # Comments Requir;ng Roport # (initials) Retest and Dale - 2 O i Test Results
/ 1. Test Completed. Satisfactorily i 2. After correction of the above discrepancies, test results aib satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATluFACTORY. Retest the above after; correction of above discrepancies.
1 i-Retest Complete Date ,, Test Complete ' u o Date 0-l30 - O SFCC Acceptance . , .
- Date 3-71/
Simulater Supervisor's Ac tance <w Date J f-9/
.... . ...,,,, ..... cy
UNIT GMMUfd b . _, 005 5600 4 O' DATE b' I3'*)0 Revision 19 August 1990 [ OPERATOR I MII0 , SHIFT ENG WA OPER ENG __ _ l WEEKLY TURBINE GENERATOR TESTS j
- 4. QRPOSE The purpose of this procedure is to outline the method used to perform the weekly turbine generator tests.
B. REFERENCES
- 1. None.
C. PREREQUISITES l. If the unit is acerating in EGC or automatic flow control, contact ' the Load Dispatcher and trip EGC and return the unit to manual flow control for steps F.1 thru F.9. All remaining steps may be O performed w",ile in EGC operation. D. PRECAUTIONS
- 1. Do not perform tests at the 901-7(902-7) panel simultaneously .ith tests at the-901-31(902-31) cabinet (steps F4-6) as a turbine trip can result.
- 2. When testing the stop valves on the turbine (MSV 1 through 4) and intercept _stop valves (1 through 6), hold the pushbutton down until tne valve being tested makes its full travel. If your finger slips off the pushbutton, DO NOT re-test the valve until it returns to normal. An extra pressing of the pushbutton during valve travel could lower the EHC pressure far enough to 9tve a turbine generator load reject relay operation and a possible full scram.
E. LIMITATIONS AND ACTIONS
- 1. If_an abnormal test result occurs during the performance of a portion of this survell~ lance which involves the turbine trip logic, discontinue testing until the condition has been investigated and corrected, or it is determined that the test may continue under current concitions without a turbine trip resulting. If a malfunction occurs take action as necessary to avoid an inadvertent turbine trip and possible reactor scram. Consideration should be given to reducing power below the turbine trip scram bypass if the s situation warrants. (OVR 4-2-89-019)
APPROVED 10/0279Q -1 E15 n eco.sa,
l l 005 %00-d Revfslon 19
- 2. Thrust near detector.
I
- a. If the alarm falls to C Prn or the te' light does not come l on, release the test buttor, affd 013Ontinue testing until the
. problem can be corrected. The alarm and Ilght indicate that
, the thrust 9etr trip is bypassed. The turbine could trip if testthg continued. Failure of the alarm or 11 abt to clear indicates that the thrust wear trip is still byphsted and corrective action should be taken to clear the aisem before proceeding. F. PROCEDURE
- 1. Main stop valve testing,
- a. By using the test panel, at panel 901-7 (902-7), select stoD valve with the STOP/ CONTROL " VALVE TEST" selector switch. The upper half of the test button will light to indicate that the stop valve test circuits are armed.
- b. Depress the (#1) test button and observe that the valve position indicator shows that the valve closes and that the
, relays drop out,
- c. Observe that the valve fast closes the last 10% of valve travel. g,
- d. Repeat steps F.1.a. through F.1.c. for stop valves 2, 3, and 4.
STOP VALVE - 1 M RELAY 124 A, B #M STOP VALVE - 2 4 RELAY 124 C, F k SYOP VALVE - 3 di RELAY 124 E, D @ _ . _ , STOP VALVE - 4 _ $f RELAY 124 G, H [t1
- e. Turn STOP/C0hTROL " VALVE TEST" selector switch to 0FF.
- 2. Combined intermediate valve testing is to be performed at the discretion of the Shift Engin4er. S.E. approval W/A .
- a. Depress the pushbutton for combined intermediate valve (#1).
b, Observe that the valve position indit;ator for the intercept valve (meter on right) shows that the valve closes fully before the intermediate stop valve (meter on left).
- c. Observe that the valves fast close the last 10% of valve travei.
APPROVED 10/02794 e,c,o.sJt
w 5600-4 Revision 19 tO d, Release the test button and observe that the intermediate stop V valve opens completely before the intercept valve starts to open. CAUTION Verify heater levels are stable prior to continuing.
- e. Repeat steps F 2.a. through F.2.e. for #2, 3, 4, 5, and 6 combined intremediate valves.
CIV - 1 @ CIV - 2 1 CIV - 3 t l. CIV - 4 T) CIV 5 41 CIV-6'N1 .,
- 3. Thrust bearings.
CAUTJN e If the alarm falls to sound or the test light fails to come on, release the test pushbutton and discontinue the test until the alarm or light is corrected. The turbine could trip if em the test is continued in the absence or the alarm or light. (]
- 8. Chec* the thrust bearing wear detector and record readings of generator end trip point and turbine end trip point.
2] 3'l (Generator End) (Turolne End)
- 4. Emergency gowoor oil trip.
CAUTION using upper and is er lamp, test push , buttans, verify all lights work before proceeding.
- a. Push the " TEST" button for lock out valve on EHC panel.
- b. Observe "LOCKE0 OUT" 11 0 ht and alarm. /Tri k' c. Push and hold "Olt TRIP" butten until over-speed trip status lights Indicate "TRIPPE0" condition. r1 f)
V APPROVED 10/0270Q QAO.SR.
005 5600-4 cevit % 19
- d. IMPORTANT - Hait at least 15 seconds before proceeding.
CAUTI.0J If after the " RESET" push button is released in step F.4.e., the "TRIPPE0" light illuminates, proceed with steps F.4.e. (1) through (9) inne di a te l v . If turbine resets satisfactorily proceed to step F.4.f.
- e. Push " RESET" button for emergency governor and hold until "RS5E'" light is lit. If the " RESET" light goes out proceed immediately with F.4.e. (1) through (9).
(1) Push the " TEST hutton for lock out valve on EHC panel. (2) Observe " LOCKED OUT" light and alarm. Wri (3) Push "0!L TRIP" push button momentarily. (4) Hait 10-15 seconds. (5) Push " RESET" push button and hold until " RESET" light illuminates. (6) If " RESET" light goes out again, repeat steps F.4.e. (1), (2), and (3) several times. If " RESET" light continues to go out, proceed to step F.4.e. (7), (7) Push " TEST" push button. , (8) Leave turbine " LOCKED OUT" and inform Instrument Maintenance for further investigation and testing. (9) If conditions permit, start reducing turbine load to less than 407..
- f. Emergency governor stiitus will automatically go to normal after 10 seconds.
NOTE Verify both the NORMAL and the RESET switches are illuminated and all other indicators are extinguished on the OVERSPEED TRIP SYSTEM 5TATUS PANEL located on the turbine control board 901-7(902-7) prior to performing steps F.5, 6, and 7. APPROVED 10/0279q enm Q.C,0.SJL l
QOS 5600-4 Revislon 19
- 5. Back-up overspeed trip (BUOT).
- a. Push the "12 PERCENT OVERSPEED CIRCUIT" test button at the adjustment panel in 901-31(902-31)
. cabinet. (coc10 NA
- b. If the button backlights, the BUOT is operational.
- 6. Power-load unbalance.
4 NOTE The turbine must be 1 40% power by ensuring that relays 590-123A-0 are de-energized, a, At the adjustment panel in 901-3)(902-31) t cabinet,pushthe" BUTTON". POWER-LOADUNBALANCETEST[MA) A
- b. If the push button backlights the "P.L. UNBAL.",
the circuits are operational. (touC) o/4
- 7. Back-up speed governor, a ._ At the adjustment panel in 901-31(902-31) cabinet, push the "BACK-UP SPEED CIRCUIT" test button. bud N/A
- b. If the push button backlights, the test is successful, but) IMA
- 8. _ Vacuum trip' pressure switches.
- a. Select vacuum trip pressure switches "A". (r1 NOTE g If any of the six lights light,-a faulty pressure switch is indicated.
- b. Verify that no 1.ights light. Iri
- c. Select vacuum trip pressure switches "B". 4
- d. Verify that no lights light, @
- 9. 24 VDC master trip solenoid valves,
- a. Verify that both MTSV lights are ON prior to performing this test. M O APPROVED 10/0279q -S- (2 151990 ,
o c.o.s.a. l
005 S600-4 Revision 19
- b. At the turbine panel, place the master trip solenoid test switch to the " TRIP A" position. (n
- c. When the light goes 0FF, release the switch. Tr1
- c. When both lights are ON, place the test switcil to the " TRIP B" position. It1
- e. When the light goes OFF, release the te;,t ,6 switch. 'lH
- f. Verify that both lights are ON. $4
- 10. Stator Water Unit.
- a. Check auto start of the reserve stator cooling /
pump by pushing the test button on the stator M ol cooling pump power unit. dri
- b. Stop the reserve stator water pump. Tr1
- 11. Hydrogen Seal Oil Unit.
- a. Push the test button for the emergency seal oil V ("' p"*"
pump (pressure switch at iron horse) and verify auto start. 4f
- b. STOP the emergency seal oil pump. /I}1
- 12. Turbine oil level alarm.
- a. Test the HI HI/HI/ LOW level alarms on the turbine oil tank by manually raising and lowering the (loc 4 U float in the oil tank, u/A l
- 13. Auto start of turbine lube oil pumps.
NOTE I All oil pumps are stopped from the control room, l fuiteheet'...
- a. Push the test button on the oil tank gage panel */ Tuo2 for the motor suction pump test valve. When the
. pump has started, release the button. Tri l b. Stop the motor suction pump by turning the control l switch momentarily to "0FF" Leave the control l
switch in "AUT0" M APPROVED 10/02794 l o c.o.s a m
.. = - . . -- . . .. -. -
005 5600-4 Revision 19 I - (~T - NOTE ' L) The emergency bearing oil pump will not start from the test button if the turning gear oll pump is running with a discharge pressure greater than 15 psig. c, Push the test button on the oil tank gage panel
/
I 'k"" for the emergency bearing oil pump test solenoid Tel and verify auto start. 61
- d. Stop the emergency bearing pump and leave the control switch in "AUT0". Id
- e. Start the turning gear oil pump with its push- /
button and verify auto start. M
- f. Stop the turning gear oli pump from the control room and leave its control switch in auto. TH 14, fuller's earth filter,
- a. Record the pressure before and after the Fuller's Earth Filter,
- b. Subtract the before and after reading.
~N' (G NOTE If the Fuller's Earth Filter pressure crop exceeds 30. PSI or the 0.5 micron bypass filter exceeds 15 PS!; notify the Shift Engineer and-fill out a work request to install new fuller's Earth Filter elements-and/or 0.5 micrcn bypass filter.
(bot) = OIFFERENCE (30) M/A - uA o/A BEFORE AFTER DIFFERENCE
- 15. Record the. color (blue or pink) of the EHC oil vent air dryer. If the color is pink notify the Shift Engineer and write a work request to change @ U@
the drying medium. 9/A -
- 16. Record EHC oil pump running current.
18 $$ EHC PUMP AMPS APPROVED 10/02794 -7_ 15 W CLC.O.SJL ,
005 5600-4 Revision 19
- 17. Check auto start of the reserve EHC fluid pump by l< - A " h" pushing the test button on the EHC fluid pump power / Teo2.
Unit. 'N1
- 18. Record the turbine lube oil filter pressure drop. N/A NOTE Notify Shift Engineer and write a work request to change lube oil filters if OP exceeds 20 PSIO.
- 19. Record v:bration from recorder 5640-60. Record phase angle readings at .,anel 901-7(902-7). Record bearing oil temperatures from computer points T124-T135(T224-T235). Indicate by a check mark (/) those phase angls readings that are not steady.
TURBINE SPEED: rpm (600 GROSS LOAO: Mw 623 BEARING VIBRATION PHASE ANGLE TEMPERATURE (MILS) NORMAL (DEG) +180' (/) (*F) 1 2.I ')$ 075~ l3$.7 2 l.G QS 280 (38.lo 3 2.2 96 2T l36.7 a 2.G *)5 280 159.3 5 2 .') =)5 250 13 8. 8
. 25 *); 280 (3 ).8
_ 1 l.*) D5 18a 137.4 8 .92 75 ZFo I.E . o 9 2.o *)5 E8o (38.8 10 l.o "J5 253 /39.7 11 2. 2. 75 2 80 /37.7 12 2.0 25 28a 139.I APPROVED O 10/02790 Q.C,0.!!ut
005 5600 4 Revision 19 ,n G. CHECKLISTS
- 1. QOS 005-S7, Balance of Plant Test Assignment Sheet Operations Weekly.
H. TECHNICAL SPECIFICATION REFFRENCES 1, None. APPROVED (final) 10/02794 DED 15 F/90
%c.O.SR.
Simulator Cao Cmes Test Procedure Cover Sheet Test Number aos saoo s ! PTAO-105T1
,) Date Performed //-/FJo Description gy, gygg g gy 7 Discrepancies section of Test Discrepancy Corrected item # Comments Requiring Report # (inillais)
Retest and Date m U Test Results
- 1. Test Completed Satisfactorily
- 2. After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary.
- 3. Tests results UNSATISFACTORY. Retest the above after:
correction of above discrepancies. Retest Complete Date Test Complete [ Date O'lM6 SFCC Acceptance Date 3
- 7' N Simulator Supervisor's Acce ance / t A Date Jf-9/
C.E.CO. 80 1215 12 99
005 5600-5 Revision 5 v TURBINE GENERATOR MONTHLY TESTS July 1985 A. PURPOSE The purpose of this procedure is to outline the method of conducting the turbine generator monthly tests. B. REFERENCES
- 1. None.
C. PREREQUISITES
- 1. None.
D. PRECAUTIONS
- l. For bypass valve testing, trip EGC or automatic flow control and return the unit to manual flow control if not already in manual l flow control.
E. L_[MtTATIONS AND ACTIONS 1, In general, the lift pumps should be operated before unit shutdown or monthly to assure their availability when required,
,m
( 2. A single pressure switch interlock is supplied in the pump suction N-line in each lift pump enclosure which does not permit lift pump operation unless bearing header oil is available. A test valve is furnished in the oil line to the pressure switch which, when operated, shuts off oil to and releases pressure from the pressure switch F, PROCEDURE 1, Lift pump operation.
- a. START the lift pumps from tne control room.
- b. Record the discharge pressure of each pump.
- 2. Test interlock pressure switch,
- a. Depress the test pushbutton on XA 5620 pump enclosure and verify that pumps A, B, and C trip, (1) Record the test as " SAT" If the pumps trip.
APFHC;C e9 \ / ;[ [ 'J -* 3d 3 13/0384q OiR
005 5600-5 Revision 5
- b. Depress the test pushbutton on XB 5620 pump enciesure and verify that pumps 0 and E trip.
(1) Record the test as " SAT" if the pumps trip.
- c. Shutdown the lift pumps and check that the system is returned to a normal status.
- 3. Emergency bearing oli pump test.
- 8. With a hand tachometer and stop watch, check the time from starting to rated speed. Also, record DC voltage to the pumo {'
by recording the 250 V battery voltage at associated pattery charger, i
- b. Record running pump speed. Rated pump speed is 1760 rpm. i
- 4. Test turbine bypass valves:
CAUTION l Testing BPVs will drop load by about 30 MWe, BPV testing should not be attempted while the pressure control system is controlling the bypass valves. Allow sufficient time between each valve for all plant parameters to
) return to normal.
- a. Select each bypass valve 1 through 9 by using the selector switch on 901-7 (902-7) panel. Push the BPV test button and verify that the selected BPV comes fully open in about 10 seconds. Release the test button and verify that the BPV comes closed in about 10 seconds.
G. CHECKLISTS
- l. Q05 5600-52, Turbine Generator Monthly Surveillance.
- 2. Q05-005-SB, Balance of Plant Test Assignment Sheet Operations Monthly.
H. TECHNICAL SPECIFICATION REFERENCES
- 1. None.
APPROVED U DEC 041985 ( 7, ng , 13/03844 O C.O S R l
O UNIT Sielut Afof. 610 'w] DATE H.rtoe OPERATOR Tr14rt.ufb 005 5600-52 SHIFT ENGINEER 9/A Revision 3 July 1985 TURBINE GENERATOR MONTHLY SURVEILLANCE Turbine Generator Lift Pump Operation Enclosure Pump
- Pressure Switch Interlock Lift Pump Discharge Pressure Sat. Unsat. U-l (U-2)
U-l IA 5620 A LE/L d[a 4 (3) (S A L U-2 2A 5620 (COL d4 5 (2) l*AL B (acAL d4 6 (4) bc4L (acAL J/4 2 (1) b'r fl C (ocAL M 3 (5) loc AL loe AL , di 1 (6) local 0 l oe/L al/! 8 (9) loc A L LotAL tj/i 7 (10) l* CAL p E .iochL slle 9 (8) loc)L V - boc AL *lli 10 (7) L8cA L A single pressure switch interlock is supplied in the pump suction line in each lift pump enclosure which does not permit pump operation unless bearing header oil is available. Emergency Bearing 011 Pump Hith a hand held tachometer and stop watch, check the time from starting to rated speed-(1760 rpm), j Starting Time kA DC Voltage to Pump M [L1r)4 Record Running Speed kA APPRO'/ED DEC 0 41985 h<^ 0 C.O 5 A 1/0061a .l.
005 5600-52 Revision 3 l I Bypass Valve Testing Verify bypass valve opens and closes. BPV-1 It " TURBINE BYPASS VALVE OPEN" alarm 41 BPV-2 Ai BPV-3 'C1 BPV-4 drf BPV-5 '$1 SPV-6 H BPV-7 <T)1 BPV-8 [Q , f BPV-9 /l r'l O O TEST PROCEDURE: 005 5600-5 l l APPROVED l L-
~ DEC 0 41985
- 0. C.0= 3 R U t nd )
lL 1/006i1 l
~
Simulator @v/o O/77Er Tost Procoduro Covor Shoot Test Number G5 66 eo-/ PTAO-105T1 (] Date Performed 2-3' D/ D e s c riptlo n $/ESTl Gene /Afbt Mw770Y l'dp TEs'T Diserepancies section of Test Discrepancy Corrected item # Commerts Requiring Report # (initials) Retest and Date
- . , =
- m-Test Results I 1. Test Completed Satisfactorily 2 After correction of the above discrepancies, test results are satisfactoy. Retest is NOT necessary,
- 3. Tests results UNSATISFACTORY. Retest the above after correction of above discrepancies.
Retest Complete Date Test Complete /I He Date 2-3 9/ SFCC Acceptance ! / . , - - Date 3 3 il Simulator Supervisor's Acc ptance Date c3-f' 9/ c.c.co, es-i2 n i2 n
005 6600-1 Revision 21 DIESEL GENERATOR MONTHLY LOAD TEST uary 1991 A. MRPOSE The purpose of this procedure is to outline the method used to perform the monthly load test on the Diesel Generators. B. REFERENCES 4
- l. Inservice Testing Program, a- QAP 350-1, Administration of the Inservice Testing Program.
- 3. H-25, M-72, Service Air Piping.
, 4. H-43, Reactor Building Equipment Orain Sump Piping, C. PREREQUISITES
- 1. Prior to operation,
- a. All related systems must be in service or available for service,
- b. All start-up preparation must be completed,
- c. For Unit 2 Diesel Generator only, notify RP Foreman prior to any planned start-up. This is due to contamination control concerns with work activities at TH-2 during Unit 2 Diesel Generator operation.
D. PRECAUTIONS
- 1. The normal engine trips are not bypassed in manual operation.
- 2. Avoid testing the redundant diesel engines at the same time.
- 3. Avoid shutting down the redundant diesel engines within three hours of each other.
- 4. Olesel Generator 4KV feed breaker to 4KV emergency bus will not close if the Diesel Generator is out of synchronization with the 4KV bus.
- 5. While operating the 01esel Generator on other than on auto start condition, avoid starting large loads on bus 14-1(24-1) or 14(24)
(bus 13-l(23-1) or 13(23) for 1/2 0.G). This is to avoid tripping the Diesel Generator output breaker. If it is necessary to start large loads, consideration should be given to unloading the 01esel Generator while starting such equipment, then re-load the Olesel O Generator. APPROVED 2/0055q 14 Q.C.O.S.R.
005 6600-1 Revision 21 E. LIMITATIONS AND ACTIONS
- 1. Each Diesel Generator shall be manually started and loaded once each month to demonstrate operational readiness. The test shall continue until both the diesel engine and the generator are at equilibrium conditions of temperature while full load output is maintained. (TS)
- 2. Record Olesel Generator monthly load test data on data sheet QOS 6600-51.
- 3. Monthly testing of the 1/2 Diesel Generator shall consist of synchronizing and loading the 1/2 OG to bus 13-1, then synchronizing and loading 1/2 Diesel Generator to bus 23-1.
4 Avoid ~ Jeated fast starts from 15 minutes to 3 hours after shut 6vwn; 1.e., allow the engine to cool at least 3 hours after it has been operated in the loaded condition, or perform tne restart within 15 minutes of shutdown. (Unit 2 and 1/2 0.G. only)
- 5. Successful start and operation of the Diesel Generator demonstrates that check valve 1(2)(1/2)-5299-157 strokes to the open and closed positions and check valve 1(2)(1/2)-5299-158 strokes to the open position.
- 6. Successful start of the Diesel Generator demonstrates that check valves 1(2)(1/2)-4699-196 (odd months) and 1(2)-4699-123 (1/2-4699-48) (even months) stroke to the open position.
- 7. Successful start of the Olesel Generator verifies that valves 1(2)(1/2)-4699-226 and 1(2)(1/2)-4699-310 stroke open and 1(2)(1/2)-4699-309 strokes closed.
- 8. Repositioning of the upper and lower air start motors after diesel start demonstrates that valves 1(2)-(1/2)-4699-226 and 1(2)(1/2)-4699-310 stroke closed and 1(2)(1/2)-4699-309 strokes open.
- 9. Running the Diesel Generator for extended periods of time at no-load or low-load (less than 500kH) conditions is detrimental to the engine and turbo charger and should be avoided. However, during monthly testing the Olesel Generator should be allowed to run unloaded for approximately 2 to 4 minutes to allow the engine to warm up. ,
- 10. During monthly testing, the Diesel Generator should be loaded gradually over a period of approximately 2 to 4 minutes to reduce thermal stresses and maximize engine life,
- 11. If operating conditions permit, after oil filter change or after oil change, the engine circulating oil pump (and the Turbocharger circulating oil pump - U-l 0.G. only) should be in operation for at least 30 minutes and the strainer box full before starting the engine. APPROVED 2/0055q JAN 141991 Q.C,0.S.R.
005 6600-1 Revision 21 If any Olesel Generator is inoperable, refer to 9 12. 005 6600-01, 02, or 03; Diesel Generator Outage Report.
- 13. With the Olesel Generator 1/2 lined-up to a particular unit, the opposite unit operator shall not use the voltage regulator or governor control switches unless granted permission by the SCRE.
(NRC commitment to resolve DCROR 8.1.1.8/05-5)
- 14. The starting air system data and the hourly readings taken per checklist 005 6600-51 are collected for predictive maintenance purposes only. Values found outside of the provided ranges do not constitute inoperability of the system. They are a performance indicator, and should be reported to Tech staff as soon as possible.
F. PROCEDURE
- 1. Manual opera'. ion for starting,
- a. Record initial starting Air Receiver pressures.
- b. Record initial fuel oli levels,
- c. At the engine governor, set governor speed droop to 50.
d, Verify proper oil level in the governor sightglass.
- e. Verify that the Diesel Generator 1(2)(1/2) engine lube oil circulating pump and the Turbocharger lube oil circulating pump (U-1 0.G. only) are running.
NOTE Ouring the Diesel start test, one bank of receivers will be isolated to confirm that the check valves on the opposite set of receives stroke to their proper positions. A failed start on a single bank of receivers suggests that the Air Start Receiver Bank, Not the Olesel, may be APPROVED inoperable. If the diesel fails to start, and the problem appears to be JM 141Mt related to low starting air flow, re-open the isolation valve closed in 4 C.O.S.R. step F.2.f, regain normal starting air pressure, and re-attempt the start sequence at step F.2.g. A successful start proves diesel operability.
- f. Unlock and close valve 4699-122 (1/2-4699-47) (odd months only) OR 4699-121 (1/2-4699-46) (even months only).
O
~
- g. Verify that plant personnel are notified of the impending Diesel Generator start.
2/0055q i
QOS 6600-1 Revision 21 NOTE O Starting a OG on only one bank of air receivers may actuate the DIESEL gj4g GENERATOR TROUBLE alarm at 901-8 (902-8), as well as the LOW STARTING Q,C.O.S.R* AIR PRESS / COMPRESSOR LOCKED OUT alarm at 2251-10(2252-10, 2212-45). This is due to the larger amount of air required from a single receiver bank.
- h. Start the diesel engine by placing the engine stert switch on 901-8 (902-8) in the START position,
- i. Veriff that the diesel engine starts by the diesel RUN light and mete,s on 901-8 (902-8).
NOTE The Diesel Generator should be allowed to run unloaded for approximately 2 to 4 minutes to warm up the engine, but should not be run at no-load or low-load (less than 500kW) conditions for extended periods of time.
- j. Record minimum starting Air Pressures reached and approximate O times required to recharge the Air Start Receivers,
- k. Verify that the Diesel Generator 1(2)(1/2) room vent fan starts when diesel engine reaches f ull speed.
- 1. Verify that Diesel Generator 1(2)(1/2) cooling water pumps start.
- m. Bring diesel engine up to speed with engine governor switch located on panel 901-8 (902-8),
- n. Adjust Diesel Generator voltage to approximately 4160 volts with voltage regulator switch located on panel 901-8 (902-8).
- o. Turn on synchroscope, readjust generator voltage and engine speed until generator output is synchronized to 4KV bus,
- p. Once the Diesel Generator outpu't has been synchronized to the 4KV bus, then CLOSE the appropriate 4KV feedbreaker.
(1) DIESEL 1/2 to 4KV Bus 13-1 (23-1), DIESEL 1 to 4KV Bus 14-1, DIESEL 2 to 4KV Bus 24-1.
- g. Load diesel to full load capacity. With the voltage regulator, maintain VARS outgoing at approximately half the
! value of the KH. The diesel should be loaded gradually over a period of approximately 2 to 4 minutes. 2/0055q Q05 6600-1 Revision 21 W '
- r. LOCK OPEN valve 4699-122 (1/2-4699-47) on odd months O_R C 4699-121 (1/2-4699-46) on even months,
- s. Maintain load until equilibrium engine and generator temperatures are established or for two hours, whichever is
-shorter.
- t. Monitor the diesel engine for low oil pressure, high temperature, etc.
- u. Thirty minutes after starting the dies 61, and at subsequent sixty minute intervalt, record the parameters indicated on QOS 6600-S1.
- v. UNLOCK and OPEN VALVE 4699-201 and VALVE 4699-202, air dryer blowdown tank drains,
- w. After tank is drained CLOSE and LOCK VALVE 4099-201 and VALVE 4966-202.
- 2. Manual operation for securing Diesel Generator.
CAUTION When shutting down the Diesel Generator ensure that voltage is set at 4160 g volts and frequency set at 60 cycles, to be able to come up to speed and voltage in the event of an auto start,
- a. Reduce Olesel Generator load-to zero. ,
- b. Observe and regulate Olesel Generator voltage as load is reduced. -Maintain VARS outgoing at approximately half the value of the KW.
- c. Open circuit breaker from 01esel Generator to 4rV bus,
- d. At panel 901-8 (902-8) turn the Olesel Generator control switch to the STOP position. Return control-switch to the AUTO position.
- e. Observe that 01esel Generator continues to run for 11 minutes for cool down and then stops.
NOTE APPROVED If Olesel Generator prematurely trips 3 j 4 1991 during cooldown, restart diesel and allow to run for 11 minutes and then 4to,sg shutdown.
- f. Stop operation of the Diesel Generator 1(2)(1/2) vent fan.
2/0055q ()CS 6600-1 Revision 21
- g. Drain oil from the air box drain located under the crankcase over-pressure switch,
- h. Stop operation of the Diesel Generator 1(2)(1/2) cooling water
-pump.
- 1. Verify that Olesel Generator 1(2)(1/2) engine lube oil circulating pump and the Turbocharaer lube oil circulating pump (U-l D.G. only) are running.
- j. Reset the DIESEL GENERATOR 1 (2)(1/2) RUNNING alarm on panel 901-8 (902-8).
- k. Verify that fuel injection cam has returned to the start position.
- 1. At diesel engine governor, set speed droop to zero.
- 3. Take diesel crank case oil sample for monthly testing and send to Radiation-Chemistry department for quality analysis.
4 Blowdown air dryer drain tank and Y-strainer.
- 5. Verify that the 4KV emergency bus degraded voltage relay targets in panel 2251-87(2252-87)(2251-86, 2252-86) are black. These panels are next to bus 14-1(24-1) (13-1,23-1) respectively. (TS) g
- 6. Record final fuel oil levels.
- 7. Verify that valves 4699-122 (1/2-4699-47) and 4699-121 (1/2-4699-46) are left in the locked open position.
- 8. Perform 005 6600-3, Diesel Fuel Oil Transfer Pump Operability.
G. CHECXLISTS
- 1. QOS 6600-S1, Diesel Generator and System Operability.
H. TECHNICAL SPECIFICATION REFERENCES
- 1. Section 4.9.A l.a.
- 2. Thble 4.2-1.
APPROVED $ JAN 141991 (final) 2/0055q Q.C.O.S.R.
UNIT %ulAs (u.0 005 6600-51 DIESEL NUMBER 'l Revision 14 DATE Z 3 ")I January 1991 TIME NOTE OPERATOR i t1HfW F. Monthly testing of 1/2 DG shall be l SHIFT ENGINEER M/a accomplished by loading to Bus 13-1
? and then 23-1.
MONTHLY DIESEL GENERATOR AND SYSTEM OPERABILITY TEST DATA SHEET PREOPERATIONAL CHECKLIST VERIFICATION Starting Air Pressure: Receiver A: lv/t psig (220-260 psig) B: bc/L ,_psig (220-260 psig) C: t< at psig (220-260 psig) Nj D: Leut psig (220-260 psig)}}