IR 05000327/2007301
| ML072980616 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 05/09/2007 |
| From: | NRC/RGN-II |
| To: | Tennessee Valley Authority |
| References | |
| 50-327/07-301, 50-328/07-301, O.GO-5, Rev 0047 | |
| Download: ML072980616 (149) | |
Text
{{#Wiki_filter:SQN NORMAL POWER OPERATION 0-GO-5 Uni t 1 & 2 Rev. 0047 ( Pa!1e 81 of 93 STARTUP N Unit _ _ Date _ Powe r Coas tdown at End of Life (continued)
[10.3] ENSURE that indicated T AVG and Megawatt readings are . acceptabl [11] REMOVE secondary system equipment from service as Unit load is decreased (Reference Section 5.3 of this instruction for timely removal of secondary equipment). 0 END OF TEXT (
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Page 82 of 93 STARTUP N _ Un it _ _ Date _ LOAD FOLLOW OPERATIONS NOTE All load follow operations should be coordinated with Reactor Engineering for guidance conc erning rod position , 1\1limits, dilution/boration rate or quantity, and xenon worth. [C.5]
[1] ENSURE Precautions and Limitations have been reviewe D NOTE Steps5 .5[2] through 5.5[9] may be performed in any orde [2] ENSURE HUTs have sufficient capacity for the dilution/boration process . D [3] MAINTAIN T AVG on program . D [4] MONITOR S/G levels on program during the load chang D [5] MONITOR pressurizer pressure and leve D [6] MAINTAIN Axial Flux (1\1) within its target ban D [71 MONITOR all rod position indicators , group step counters , and power range channe ls during the load change . D [81 ENSURE steam dumps in TAVG mod D [9] NOTIFY Chemistry Section to sample the boron concentration of the pressuriz er and RC D [1O] IF Chem istry Section has determined that the boron concentration between the pressurizer and the RCS is greater than 50 ppm, THEN EQUALIZE the boron concentration between the pressu rizer and the RCS until Chemistry sampling has verified the difference to be less than 50 pp D
SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Paqe 83 of 93 STARTUP N Unit _ _ Date _ LOAD FOLLOW OPERATIONS (continued)
[11] IF a change in the rated thermal power equal to or greater than 15% in one hour occurs, THEN NOTIFY the Chemistry Section to initiate 0-SI-CEM-000-050.0, 0-SI-CEM-030-407.2, and 0-SI-CEM-030-41 D [12] IF RCS boron concentration is changed by 10 ppm or greater, THEN ENERGIZE pressurizer backup heaters in accordance with 0-SO-68-3 to equalize the RCS and pressurizer boron concentration D NOTE Valve position limit and governor control meter are displayed on EHC Display panel 1,2-XX-04i-2000 (M-2).
[13] MAINTAIN valve position limit approximately 10% above the current governor control indication as turbine load is change D NOTE Lowering load on the Main Generator will cause VARs to trend in the positive direction (toward outgoing). This will require lowering generato r voltage. Conversely, raising generator load will cause VARs to trend in the negative direction and will require raising generator voltage . Refer to GOI-6 Section E for MVAR limits for generator stability. Refer to precautions Q , R, and [14] PERFORM the following as required:
[14.1] IF Automatic Voltage Control is in service, THEN ADJUST Main Generator VARs USING [HS*57-221 Exciter Voltage Auto Adjuster as necessary during power escalatio [14.2] IF Automatic Voltage Control is NOT in service, THEN ADJUST Main Generator VARs USING [HS-57-23] Exciter Voltage Base Adjuster as necessary during power escalatio (
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Pane 84 of 93 STARTUP N Unit _ _ Date _ LOAD FOLLOW OPERATIONS (continued) NOTE Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water).
All appropriate verifications and peer checks shall be utilized during performanc [15] INITIATE a turbine load reduction to the target loa st ev
[16] MAINTAIN control rods above the low insertion limits or as directed by Reactor Engineering using boration of the ReS as load is reduce st ev [17] HOLD the turbine at the projected loa o [18] IF an axial xenon oscillation develops and requires suppression, THEN [1 8.1] MOVE control bank inward when AFD is moving positive above target AFD, 1st ev OR [1 8.2] MOVE control bank outward when AFD is moving negative below target AFD, 1st ev AND HOLD AFD at target until oscillation is suppresse o [18.3] IF this basic first overtone control is insufficient, THEN ( CONTACT Reactor Engineering for assistanc o [19] MAINTAIN .M within limits as xenon builds in by diluting Re o
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Pane 85 of 93 STARTUP N Unit _ _ Date _ LOAD FOLLOW OPERATIONS (conti nued) NOTES 1) Refer to Step 5.5[14] and the associated not ) Actions effecting reactivity are directed in the following step. 0-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized during performanc [20] WHEN a turbine load ascension is required, THEN INITIATE a load ascensio o NOTE Xenon will burn out as load is increase [21] HOLD the turbine at the projected loa [22] MAINTAIN 1'.1within limits as xenon burns out by boration of the Re [23] REPEAT portions of this instruction as required for changing load END OF TEXT (
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Page 86 of 93 RECORDS Completed copies shall be transmitted to the Operations Superintendent's Secretar SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Paqe 87 of 93 Appendix A (Page 1 of 1) DELETED (
SON NORMAL POWER OPERATION O-GO-S Unit 1 & 2 Rev. 0047 ( Paqe 88 of 93 Append ix B (Page 1 of 2) TURBINE RUNBACK RESTORATION TURBINE RUNBACK RESTORATION
[1] CHECK the following Turbine Runback relay indicating lights NOT LIT: [L-262, el. 706 on panel behind Gland Steam Spillover valve]: [1.1] IPIS-47-13RLY11. (Turbine runback from MFP loss).
[1 .21 IPIS -47-13RLY2l , (Turbine runback from NO.3 HDT Loss).
[1.3] IPIS -47-13RLY31. (Closure of LCV-6- 1068 from Loss of any #3 HDTP).
[2] ENSUR E governor valve tracking meter is centered close to ZERO . 0
[3] DEPRESS the rrURB MANUALl mode selector pushbutto [3.1 ] VERIFY the [fURB MANUALl lamp LI [3.2] VER IFY IOPER AUTOl iamp DAR [3.3] VERIFY reference and setter counters stabiliz [4] ENSURE governor valve tracking meter is centered close to ~RO . 0 [5] DEPRESS IOPER AUTO] mode selector pushbutto [5. 1] VERIFY IOPER AUTOl iamp LI o [5.2] VERIFY rrURB MANUAL] lamp DAR o [5.3] VERIFY reference and setter counters stabiiize . o
SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Page 89 of 93 Appendix B (Page 2 of 2) TURBINE RUNBACK RESTORATION STARTUP N Unit _ _ Date _ TURBINE RUNBACK RESTORATION (continued)
[6] IF VALVE POS LIMIT light is LIT, THEN [6.1] REDUCE load by using the SETTER until the VALVE pas LIMIT light is DAR [6.2] INCREASE VALVE pas LIMITER setpoint to 10%
above current load, ENSURING load does NOT change . o
[6.3] GO TO step 1.0[8]. o . [7J IF VALVE pas LIMIT light is DARK, THEN INCREASE the VALVE POSITION LIMITER setpo int to 10%
above current load, ENSURING load does not chang [8J RETURN to instruction in effec o END OF TEXT (
SQN NORMAL POWER OPERATION O-GO-S Un it 1 & 2 Rev. 0047 ( Page 90 of 93 Appendix C (Page 1 of 1) ISOLATION OF MSR STARTUP VENTS ISOLATION OF MSR STARTUP VENTS
[1] ENSURE the following MSR startup vent isolation valves CLOSED :
VALVE DESCR IPTIO N LOCATIO N POSITION INITIALS NUMBER MSR A-1 HCV-6-2840 TB el. 732 MSR A-1 LP end CLOSED startup vent isol MSR A-1 U-1: TB el. 706, N. Side Cond A U-2: HCV-6-2841 CLOSED startup vent isol TB el. 732, MSR A- 1 HP end MSR B-1 HCV-6-2842 TB el. 732, MSR B-1 LP end CLOSED startup vent isol MSR B-1 H.P.
( HCV-6-2843 startup vent isol TB el. 732, MSR B- 1 HP end CLOSED MSR C- 1 HCV-6-2 844 TB el. 732, MSR C-1 LP end CLOSED startup vent isol MSR C-1 HCV-6- 2845 TB el. 732, MSR C-1 HP end CLOSED startup vent isol MSR A-2 U-1: TB el. 732, MSR A-2 LP end U-2: HCV-6-2 846 CLOSED startup vent isol el. 706, S. Side Cond A, 12' up MSR A-2 U-1: TB el. 732 , MSR A-2 HP end U-2 : HCV-6-2847 CLOSED startup vent isol el. 706, S. Side Cond A, 15' up MSR B-2 U-1: TB el. 732, MSR B-2 LP end U-2: HCV-6-2848 CLOSED startup vent isol el. 706, S. Side Cond C, 15' up MSR B-2 U-1: TB el. 732, MSR B-2 HP end U-2: HCV-6-2 849 CLOSED startup vent isol el. 706, S, Side Cond B, 15' up MSR C-2 HCV-6-2850 TB el. 732 , MSR C-2 LP end CLOSED startup vent isol MSR C-2 H U-1: TB el. 732, MSR C-2 HP end U-2: HCV-6-285 1 CLOSED startup vent isol el. 706, S. Side Cond A, 15' up (
SQN NORMAL POWER OPERATION 0-GO-5 Un it 1 & 2 Rev. 0047 ( Paae 91 of 93 Append ix D (Page 1 of 1) RECO MMENDED POWER VALUES BASED ON CONDENSATED PRESSURE NOTES 1) This appendix provides recommended reactor power values to maintain adequate conden sate pressure when secondary plant equipment must be removed from service for maintenance. These values are guidelines and power may be subsequentl y raised above these values if condensate pressure is adequat ) Power values in this appendix assume all other condensate and heater drain pumps are IN SERVIC E. If combinations of pumps must be removed from service which are NOT addressed below, then Systems Engineering should be consulted for guidanc EQUIPMENT UNAVAILABLE RECOMMENDED REACTOR POWER VALU E One Hotwell Pump 75% One Cond Oemin Booster Pump No power reduction required provided all other pumps in servic One Condensate Booster Pump No power reduction required for short-term operation without one CB For long-term operation (as determined by management), power should be reduced to 85%.
#7 heater drain tank pumps NOT pumping forward 85% #3 heater drain tank pumps NOT pumping forward 60% #3 HOT pump flow degraded to 5500 gpm 80%
LCV-6-106B (closed) 95%
(
SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 ( Page 92 of 93 Source Notes (Page 1 of 2) Implementing Requirements Statement Source Document Statement Comm itment made that during power NER 89 0252 increases, monitor NIS, L\,T and INPO SER 89-009 calorimetries utilizing the highest for indication of reactor power . Als % power defined as 3411 MWT NOT to exceed the 3411 MWT average in an 8 hour period. (Changed to 3455 MWt by TS Change 01-08.)
This Commitment was made to provide PRO-SOP 89 0638P corrective action for PRO 890638 The NO.3 HOTP, CBP and COBP starts were changed from 80% to 70% in an attempt to reduce the potential for LCV-6-106B closures on low L\,P across the NO.3 HOTP's. This should reduce the instances that the NO.3 HOT LCV's are subjected to increased stresses as a result of the closure of LCV-6-106 Following refueling, relocating NIS or NER 1187001 modifications affecting the NIS SOER-90-003 response, provide adequate reductions of trip setpoints and limitations of reactor power until accuracy of the NIS is verified . Also provide alternate indications of power independent of calorimetric calculations during power ascensio SQN NORMAL POWER OPERATION 0-GO-5 c Unit 1 & 2 Rev. 0047 Page 93 of 93 Source Notes (Page 2 of 2) Implementing Requirements Statement Source Document Statement Operations has evaluated the need to LER 328/91001 CA proceduralize the process for resetting S10910201894 the electrohydrau lic control system NCO-91 0023003 following turbine runbacks . Steps for S62 910226 839 resetting of EHC system after a BOP runback have been proceduralized and placed in GOI-5 per Memorandum M. J . Lorek to C , T. Benton, Procedure for Regaining Control of the Turbine after a Balan ce of Plant (BO P) run bac Commitment made-that requires NER 89 0794 C,5 operations to request coastdown OER 89-3497 guidelines from Reactor Engineerin Revise GOI-5 to monitor the Stator II 90072 Ground Fault Relay 159GN3 during startu Required performance of NER 970015001 PI-SXX-000-022 .1 and -02 WTB-96-007 and 1,2-S I-SXX-068- 155.0 if startup is fo llowing a refuelin I App endix 0 Scenario Outline Form ES-D-1 I ( Facility: Examiners: Sequoyah Sce nario No. : Operators: 3 Op Test No.: NRC Initial Conditions: 75% Powe SG BD Rad Monitor OOS B PZR Spray Valve Isolated BCCPOOS TDAFW Pump OOS, but running for return to service post-mai ntenance Turnover: Ra ise Power to 100% . Target CTs: Isolate the Main Turbine prior to transition to any other procedure Start B MDAFW Pump prior to reaching bleed/feed criteria Event N Mall . N Event Type" Event Description 1 SI02A C-RO/SRO CL Accumulator Nitrogen Lea T+5 TS-SRO 2 THR 02 TS-SRO Chemistry reports high RCS activit T+15 ( 3 T+20 RX1 2 I-RO TS-SRO First Stage Pressu re Transmitter fails lo FW05 C-AII Feed Pump Trip; Power reduction require T+35 5 FW20 M-Ail Feedwater Header rupture; Reactor Trip. Feedwate r Isolation will terminate the feed line leakag T+55 6 TC04 C-BOP Main Turbin e Auto Trip failure Main Steam Line Isolation Valves lail to close 7 RP02 C-RO 8 1actuation failure; Manual actuation req uire FW07A, M-AII TDAFW Pump trip FW09B A MDAFW Pump Trip: Faulty 50 Relay. pump curre nt. discharge pressure, and flow decrease to S/Gs #1 & # B MDAFW Fail to Auto Start: airbound pump which will have no discha rge flow and initial speed will be higher. No water wili be added to the S/Gs, venting process to restore pumping capability
" (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix 0 NUREG 1021 Revision 9
I Appendix D Scenario Outline Form ES-D-1 I Scenario 3 Summary ( The crew will ass ume the shift at 75% Power with instructions to raise powe Afte r turnover a Cold Leg Accumulator N2 leak will develop, requiring action to make up to the CLA, and technical specification entry for the SR After techn ical specifications have been addressed, Chemistry will report high RCS activity. The crew will refer to AOP-R.06 for required action and the SRO will address technical specifications and determine that a shutdown is required . After technical specifications are addressed, a turb ine first stage pressure transmitter will fail low. The crew will take action in accordance with 1.08 to stop any rod motion and realign steam dumps in the steam press ure mode . The SRO will enter technical specification SUbsequently, a Main Feedwater Pump will trip, requiring a load reduction in acco rdance with AOP- S.01. When the crew has stabilized the unit, a feedwater header rupture will occur, requiring a reactor trip and entry to E- When th e reactor trips, the turbine will fail to automatically trip and MSIVs fail to close automa tically. The crew must manually close MSIVs to isolate the turbin Safety Injection will be required, but automatic initiation will fail, requiring manuai initiation.
( Th e TDAFW Pump will trip. "A" MDAFW Pump will fail to start and will remain unavailable. "B" MDAFW Pump will fail to automatically start, but may be manua lly starte d. The crew must recognize the pump is air-bound, and take action to restore it in acco rdance with FR- The scenario may be terminated when "B" MDAFW Pump is restored or RCS Feed and Bleed is initiated . EOP flow: E-O- FR- PSA sign ificant component OOS: B CCP PSA sign ificant transient: Loss of Feed PSA significant action: Recovery of AFW Appendix D NUREG 1021 Revision 9
ESG-3 SCN File 03/23 /0 7 ( EVENT Sim ulator IC/MF/RF/OR # IC-14 DESCRIPTION/EXPECTED ACTIOl'iSIBOOTH FEEDBACK 75 % , BOL (-1000 MWD/MTUI IC ' B' Train work week C B ' D' Rods @ 185 steps, all others @ 228 steps; IB] = 1178 ppm; Ba Blender settin g: 29% Xe: -2529 pcm; Sm: -1019 pcm; Console Onerator actions: Place simulator in run and perform the following:
* Place the Turbine Driven AFW Pump in servic * Place I A-A CC P in servi ce and r emove IB-B-Place I B-B CCP in P-T-L and tag with H * Place Loop I Sp r ay valve in man ual and tag with Pink T a * Place Train W eek B sla n MFs, RFs, lR F RMRI9 f:3 SG BD Rad Monitor OOS: I-Rl\I-120A & 12I A and ta g with Pink Tag DRs are IMF RM90120 f:l acti ve when IMF Ac'\' OV 723 f:2 the SeN IMF R C06B f:O Loo p I PZR Spray Va lve Isol atcd (I -PCV-68-340D)
file is loaded . IMF CVOI B f:1 m-n CC P O OS T DAFW Pump OOS, but r unning for post-mainten ance test ing:
- TS LCOs 3.7.1. 2.a for TD AFW pump. 3.3.3.7.18b action I ; Accident Monitoring Instru mentation, ERCW to AFW Valve Position , Turbine Driven Pumps.
( IMF TC04 f:1 IM F RP02 f:l Turbine Fails To (automatically] Trip ; Sa fety Injection (SI ) automatic actuation sij!ual failure; Il\IF S I0 2A f:l k:1 #1 C LA LO-PRESSURE; Prior to inserting Malfunction , ens ure you can monito r CLA p r essur DMF SI02A Delete malfunction when CLA pressure drops to < 624 psi Faulty relief valve corresponds to 10 psi/minute decrease at 500 psid CLA-containment pressur TS 3.5.1.1. action a should be referenced ; Shutdown wli 24 hours per GO-5; IM F TH09 f:l k :2 Increase in activity released by cor IRF THR02 f:2 Surmort staffrepo rt: As Chemistry Sup ervisor: ca ll US and notify him that samp le res ults sh ow Res specific ac tivity is being determin ed (I OOIE microcuries/gram). Dose Equ ivalent 1-131 has increas ed to 55 microcuries/g rum du ring the last 24 hour If subseq uent call requ ests recomm endations, the Lab suspects a fuel leak has developed and reco mmends placing mix bed and cation bed in servic US refers to TS 3.4.8 & figure, determines shutdown is require Thi s malfunct ion work s in association w ith RCS activity remote function Page I of 3 G :\Prep week files\As Sub mitte d Operational Exa m' ScenartcsiScenarl o 3\3-20-07 ESC -3.doc
ESG-3 SCN File 03/23107 EVENT IC/MF/RF/OR # DESCRIPTION/EXPECTED ACTIONS/BOOTH FEEDBACK ( THR02, Primary System Radiation. Nonnally THR02 is set to some value around 2 microcuries/cubic centimeter to simulate normal RCS activit THR02 will be overridden by the malfunction if the malfunction is activ RF THR02 may be used to indicate core activity with TH09 activ However, TH09 will have to be removed before remote function THR02 will regain control of RCS activit . IMF RXllB f:l k :3 PT-I-73, PIMP C h 1 fails low- no-load value; Support stalfreport: When fvfSS or LVs is contacted to trip bistubles, inf orm the crew that the fMs will repo rt to the Me R in - 45 minutes (WD package & briefing time).
Ch 1, 11'-1 -73 indicated on l-M-4; directly affect s the load reference Tref- . MCR indications are also reflected in the system responds to the Tref program low failure;
- Steam Dump Ca nt Sys: will ann D solenoid, but dumps will not open since they are not armed; - Rod Ca nt Sys: no-load value- 54T F value; Rods will insert - SG LvI Ca nt Sys: no-load value-33% NR; - Crew may NOT place FWC in MANUAL, but may monitor AUTO control establish! control level at no-load valu NOTE: The US may refer to AOP-C.OI, Section 2.1, Continuous Rod Bank Movement Step 3.c will direct crew to AOP-I.08, Turbine Impulse Pressure ( IMF FW05B f:l k:4 Instrument Malfunctio IB-B MFW pump trip due to an oil leak at the pressure transmitte Suppo rt stalfreport: * When personnel dispatched to investigate, wait - 3 minutes and report that oil line is leaking but is containable to this elevation/surrounding are * If Environmental Controls and/or Fire Protection p ersonnel are dispatched, wait 5 minutes for each and report on station and implementing appropriate supporting action . IMF FW20 f:50 k :5 Feedwater line break in turbine building; failure of common header, downstream of # I FW Heater; IMF TC04 f: 1 Turbine Fails To Trip ;
Per E-O Step 2 RNO, close the MSIVs; turbine controls also can run the turbine down; following the reactor trip, to prevent an excessive RCS cooldown result . IMF FW22C f:l e:l TDAFWP becomes air-bound when required to supply AFW flow and IMF FW07C f:l d:240 will trip -4 minutes late e:l SUfJIJort staffreport:
* When p ersonnel are dispatched to investigate, wait ~5 min. then rep ort the T&Tvalve is closed, valve linkage separate . IMF RP02 f:1 Automatic Safety Iniection (SI) actuation signal failure; Page 2 of 3 G:\Prep Week files\As Submi tted Operational Exam'Scenarto s'S cenarlo 313-20-01 ESC-3.doc
ESG-3 SCN File 03/23/07 EVE NT IC/MFIRF/OR # DESCRIPTIO N/EXPECTED ACTI O NS/ BO O T H FEEDBACK ( M-4 or M-6 HSs will manually actuate SI signal as require IMF RP16K616A f:l Automatic MSLI actuation signal failure; Il\I F RP16K616B f:1 IMF RPI6K623A f:1 M-4 MSIV IISs will manually close MSIV IMF RPI6K623B f:1 IMF FW07A f:1 l A-A AFW Pump triplfail to start; l A-A AfW Pump Breaker has a faulty 50 relay and cannot be re-started; IMF FW09B f:1 1B-B AFW Pump AUT O-Start defeated; 1B-B MDAFWP will fail to start on any automat ic start signal; Manual actuation will start the pump . IMF FW22B f:l e:l IB-B Air-bound AFW Pump; 1B-B AfW Pump is air-bound when the pump is started and indicates only no load current, no discharge flow; if AFW is required, no water will be added to SIGs #3 & #4 until the pump is vented; IM F FW07B f:1 d:180 ROL E PLAY: As TB AUO when dispatched. after 4 minutes report that the c:1 - pump is hot 10 the touch, request pump he placed in P- l~L, fo r ventin IB-B AFW Pump triplfail to start; 1B-B M W Pump due to air-bound condition; DMFFW07B lB-B AFW Pump trip/fail to start; DM F FW22B Delete IB-B Airbound A F W Pum RO LE PLAY : As AB AUO, after 4 minutes notify the MCR that the l B-B MD AFW Pump has been vented and is ready to be returned to servic T ermination C riter ia Restore fe edwater flo w via lB-B A FW Pump prior to reactor cooling via R CS feed/bleed as directed in FR-H,l.
( Page 3 of 3 G:\Prcp Weekfiles\As Submitted Operational Exam\Sccnarios\Scenario 3\3-20-07 ESG-3.doc
I Appendix D Required Operator Actions Form ES-D-2 I c Op Test No.: Event Description: NRC Scenario # 3 Event # Cold Leg Accumulator Nitrogen Leak
....:..____ Page 3 of ..;2=:2=---1 Time I Position I Applicant's Actions or Behavior Booth Instructor:
When directed, initiate Event 1 Indications available: 1-AR-M6-D, A1, ACCUMULATOR TANK 1 PRESSURE HI-LOW Refer to alarm response procedure RO CHECK CLA digita l pressure indication on [1-PIS-63-128] and
[1 -PIS-63-126] (M-6).
RO ( IF CLA pressure is <624 psig OR >668 psig, THEN DECLARE the Accumulator inoperabl RO ADJUST accumulator level and/or pressure in accordan ce with 1-S0-63-1, Cold Leg Injection Accumulator RO EVALUATE Technical Specifications , LCO 3.5 .1.1 for applicab ilit US * Enter Action a. if CLA pressure goes below 624 psig l CAUTION 1 Appendix D NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # _ 3_ _ Event # ....:..___ _ Page 4 of -:2;=. 2---1 ( Event Description: Cold Leg Accumulator Nitrogen Leak Time I Position I Applicant's Actions or Behavior Do not cross connect the Cold Leg Accumula tor CAUTIO N 2 Each Cold Leg Accumulator shall be pressurized between 624 psig and 668 psig to comply with TS 3.5.1.1. The Accumulator safety relief valve is set to relieve pressure at 700 psig . ENSURE Power Checklist 1-63-1 .01 comp let RO ( ENSURE Valve Checklist 1-63-1.02 complet RO ENSURE Valve Checklist 1-63-1 .06 complet RO VER IFY the following valves CLOSED: VALVE NUMBER FUNCTION 1-FCV-63-107 NO. 2 CL Accum N2 Supply Isol RO 1-FCV-63-87 NO. 3 CL Accum N2 Supply lsol 1-FCV-63-63 NO.4 CL Accum N2 Supply Isol OPEN [1 -FCV-63 -64] N2 Supply to CL Accu RO Appendix 0 NUREG 1021 Revision 9
I App endix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # -'-_ _ _ _ Page 5 of ..;2=:2=---I ( Event Description: Cold Leg Accumulator Nitrogen Leak Time I Position I Applicant's Actions or Behavior IF Unit 1 nitrogen regulator 0-PCV-77-254 is INOPERABLE, THEN OP EN [0-77-865A] to align Unit 2 nitrogen regulato r 0-PCV-77-253 to supply U-1 cold leg RO accumulators . NOTE If CLA pres sure is less than 600 psig, then temperature monitoring is required to prevent brittle fracture of nitrogen piping downstream of O-PCV-77-253 or -25 IF Accumulator 1 pressure is less than 600 psig, THE N
- PERFORM the following during pressurization: * MONITOR piping temperature downstream of [1 -63-( *
705] using contact pyromete IF piping temp eratu re approaches 40°F, THE N RO THROTTLE [1-63-705] in close direction as necessary to maintain piping tempe rature greater than 40° * WH EN CLA #1 pressure is greater than 600 psig, THE N STOP temperature monitoring and OPEN [1-63-705] as desire (Not required) OPEN [1 -FCV-63-1 27] NO. 1 CL Accum N2 Supply isolation to admit nitrogen to accumulato RO NOTE Tech Spec opera bility range for CLA pressure is 624- 668 psi WHEN CLA #1 pressure increases to desired value, THEN RO App endix 0 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ....:...____ Page 6 of ....:2;;0 2---1 ( Event Description: Cold Leg Accumulator Nitrogen Leak Time I Position I Applicant's Actions or Behavior
* CLOSE [1-FCV-63-1 27]. * CLOSE [1-FCV-63-64].
IF [1-63-705] was TH ROTTLED, THEN ENSURE [1-63-705] is RO FULLY OPE IF [0-77-865A] was OPENED, THEN ENSURE [0-77- 865A] is RO CLOSE When Cold Leg Accumulator is within T5 pressure limits, the Lead Examiner may cue the next event Appendix D NUREG 1021 Revision 9
I Appendi x D Required Op erator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 2 EventDescription: High RCS Activity Time I Position I Aoolicant's Actions or Behavior Booth Instructor: Report high ReS activity per cue sheet Indications available: None Reviews Techni cal Specifications US
- Determin es TS action 3.4 .8.a applie MODES 1, 2 and 3* action a US AND ( MODES 1, 2 , 3, 4 and 5 action a Enters AOP-R.06, High RCS Activity US EVALUATE EPIP-1 , Emergency Plan Ciassific ation Matri Reactor coolant system specific activity exceeds LCO (Refer to SON Tech. Spec. 3.4.8):
1. Radiochemistry analysis indicates (a or b): a. Dose equivalent Iodine (1-131) >0.35 lJCi/gm for 48 hours or in excess of TIS Figure 3.4-1 with Tave 2:500 of . NOUE condition exists based on EAL 2.4 ( Appendi x D NUREG 1021 Revision 9
I App endix D Reguired Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 2 (, Event Description: High RCS Activity Ti me I Position I Aoolicant's Actions or Behavior Prepare to perform plant shutdown Crew When Technical Specification actions have been addressed , the Lead Examiner mav cue the next event ( App endix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I c OpTest No.: Event Description: NRC Scenario # 3 Event # _3::.....____ Page 9 Turbine First Stage Pressure Transmitter PT 1-73 failure of 22 Time I Position I Aoolicant's Actions or Behavior Booth Instructor: When directed, initiate event 3 Indications available: 1-A R-M5-A , C6 , TAVGffR EF DEVIAT ION 1-AR-M5-A, B7 , ST EAM GEN LVL HIGH-LOW DEVIAT ION Refer to alarm response procedures Crew Direct entry to AO P-1.08, Tu rbine Impulse Pressure US Instrument Malfunction ( OR MAY ente r to AOP-C.01, Sect 2.1, Continuous rod ban k movement: CHECK rod control: a. ENSURE rod control in MAN. (YES) b. CHECK rod motion STOPPED. (YES) US 2. CHECK for steam line or feedwater line break: (NO) 3. CHECK for instrumentation malfunction: a. CHECK nuclear instrumentation OPERABLE. (YES) b. CHECK RCS RTDs OPERABLE. (YES) e. CHECK turbine impu lse pressure channels OPERABLE. (NO) Transitions to AOP-I.08 from a.c ( NOTE: Loss of Instrument Power to Steam Generator level setooint prooram input will drive the Appendix D NUREG 102 1 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I c Op Test No.: Event Description: NRC Scenario # 3 Event # ...;3::.-____ Page 10 Turbine First Stage Pressure Transmitter PT 1-73 failure of 22 Time I Position I Aoolicant's Actions Dr Behavior setpoint below 33% Steam Generator leve CHECK PI-1-73 indicates norma * PLACE rods in MA * EVALUATE placing Main Reg Valves in MAN to maintain SG level on progra Operators may elect to leave FW Reg valves in auto, S/G will control at a lower leve * PLACE Steam Dumps in Steam Pressure Mode USING 0-SO-1-2 , Steam Dump Syste [1] PLACE [HS-H 03Aj Steam Dump A FSV and [HS -1-1036j Steam Dump B FSV handswitches to OF RO/BOP [2] PLACE [HS-1 -103Dj Steam Dump Mode selector to STEAM PRES [3] VERIFY [XI-1-103A16l Steam Dum ps Armed white light is LI [4] IF [PIC-1 -33j Steam Dump Controller in MANUA THEN ENSURE demand is Zero on controlle [5] IF [PIC -1-33] Steam Dump controller in AUTO, THEN ADJUST setpo int to obtain zero outp ut (dema nd).
[6) PLACE [HS-1-103Aj Steam Dump A FSV and [HS-1-103Bj Steam Dump B FSV handswitches to O [7J ADJUST [PIC-1-33j Steam Dump controller to maintain desired steam pressur * DETERMINE Program T-avg for current reactor power USING TI-28 Figure A.9 or ICS (NSSS I BOP , Program Reactor Average Temperature).
- WHEN plant stable, THEN RESTORE T-avg to within 3 deg rees of program:
* POSITION control rod OR * ADJUST turb ine load .
OR
* ADJU ST RCS boron concentration CHECK PI-1-72 indicates norma BOP l
Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES*D-2 I Op Test No.: NRC Scenario # 3 Event # -'3::....____ Page 11 of 22 ( Event Description: Turbine First Stage Pressure Transmitter PT 1-73 failure Time I Position I Aoolicanl's Actions or Behavior NOTE: If performing AOP in conjunction with AOP -1.1 1 for an Eagle LCP failure, then actions to hard trip bistab les should be delayed until Eagle system reset is attempted . Actions to hard trip bistables must be completed within 6 hours UNLESS affected loop is restored to opera ble status by resetting Eagle rac IF PI-1-72 or PI-1-73 has failed, THEN NOT IFY 1M to remove failed chann el from service USING App endix A, P-1-72 (P-US 506) OR Appe ndix B, P-1-73 (P-505)
-
EVALUATE the following Tech Specs for applicab ility: ( US * 3.3.1.1 (3.3.1 ), Reactor Trip System Instrumentation (ACTION B.b appl ies) When Tec hni cal Specifications have been determined, the Lead Examiner may cue t he next event Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 4 ( Event Description: Feed Pump B trip Time I Position I Applicant's Actions or Behavior Booth Instructor : Wh en directed, initiate event 4 Indications available: SG levels trending down Main Feedwater flow lowering SG Level deviat ion alarms Respond to lowering feedwater flow Crew Direct entry to AOP -S.01, Loss of Normal Feedwater, section US 2.5 ( CHECK at least one MFW pump RUNNING . BOP ENSURE running MFW pump loads as require CHECK feedwater flow greater than steam flo IF steam flow reducti on is needed , THEN PERFORM the following : BOP
* REDUCE turbine load USING valve position limite * ENSURE contr ol rods inserted as necessary to match T-avg and T-re!.
l App endix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 4 ( Event Description: Feed Pump B trip Time I Position I Applicant's Actions or Behavior NOTE If main feed reg valve controller output is off-scale high with actual level above program, momentarily placing each main feed reg valve controller to MANUAL then back to AUTO will reset outpu MONITOR stea m generator levels returning to program leve BOP
-
CHECK reactor power less than 60%. ( ENSURE affe cted Main Feedwater Pump Tur bine Condenser isolation valves CLOSED :
* MFWP A 0 FCV-2-205, Condensate Inlet BOP 0 FCV-2-210 , Condensate Outlet OR * MFW P B 0 FCV-2-211, Condensate Inlet 0 FCV-2-216, Condensate Outlet ENSURE unit is returning to stable condition Crew US DISPATCH personne l to lnvestlqate MFW pump tri App endix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 4 ( Event Description: Feed Pump B trip Time I Position I Applicant's Actions or Behavior CHECK C-7 LOSS OF LOAD permissive DARK. [M4A, window E-5] IF Steam Dumps are in Tavg Mode, THEN PERFOR M the following to reset C-l permissive:
* PLACE HS-1-103A and 103B, Steam Dump Control , in BOP OFF . * PLACE HS-1-1 03D , Steam Dump Control , in RESET and VERIFY spring return to TAV * VERIFY c-r . LOSS OF LOAD INTER LOCK alarm, DARK. [M-4A, 5E] * ENSURE Steam Dump demand is ZERO . * PLACE HS-1-103A and 103B, Steam Dump Control, in ON . -
CHECK valve position limit light DARK . [M-2] ( BOP * RESTORE turbine controls as necessary USING Appendix NOTE To ensure unit is within capacity of one MFWP, the following should be considered when determining fina l power level:
* Power should be reduced below 60% (if all cond booster pumps and heater drain tank pump s in service) or 55% (if two cond booster pumps in service).
- Less than or equal to 90% controller output should be maintained on running MFWP INITIATE load reduction as required USING 0-GO - Crew INITIATE repairs on affected equipmen US When olant is stable, Lead Examiner may cue the next event App endix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES* D*2 I Op Test No.: NRC Scena rio # 3 Event # 5.6.7,8 ( Event Description: Feed Header Rupture, Main Turbine fail to trip, Sl auto actuation failure, loss of feed Time I Position I Applicant's Actions or Behavior Booth Instructor : When di rected , initi ate event 5 Indications available: Rapidly lowering Main Feed pressure and fl ow SG levels rapid ly lowerinq VERIFY reactor TRIPPED:
* Reactor trip breakers OPEN * Reactor trip bypass breakers DISCONNECTED or - RO OPEN * Neutron flux DROPPING * Rod bottom lights LIT * Rod position indicators less than or equal to 12 step CRITICAL VERIFY turbine TRIPPED:
TA SK BOP * Turbine stop valves CLOSED. (NO)
* CL OSE MSIVs VERIFY at least one train of shutdown boards ENERGIZE BOP DETERMINE if SI actuated:
RO * ECGS pumps RUNNIN * Any SI alarm LIT [M-4D] ( Appendix 0 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I c Op Test No.: Event Descripti on : NRC Scen ario # 3 Event # 5,6 ,7,8 Feed Header Rupture, Main Turbine fail to trip, Sl auto actuation failu re, loss of feed Time I Position I Applicant's Actions or Behavior
.
BOP PERFORM ES-0.5, Equipment Verifications WHILE continuing in this procedur DETERMINE if secondary heat sink available: a. CHECK total AFW flow greater than 440 gpm. (NO) b. CHECK narrow range level greater than 10% [25 ADVj in at least one S /G . c. Attempt to restore feed RO
-
Determines that 1B MD AFW Pump is air bound and c places HS in P-T-L and dispatches AUO to check and vent locall Direct Entry to FR-H.1, Loss of Secondary Heat Sink US CHECK the following: Total feed flow less than 440 gpm due to operator action directed by another procedur US AND Total feed flow capability of greater than 440 gpm AVAILABL (NO) a. GO TO Step Appendi x D NUREG 1021 Revision 9
I Appendi x D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 5,6,7,8 ( Event Description: Feed Header Rupture, Main Turbine fail to trip, SI auto actuation failure, loss of feed Time I Position I Applicant's Actions or Behavior MONITOR RWST level greater than 27%. RO Determines secondary heat sink required: RCS pressu re greater than any non-Faulted S/G pressur Crew RCS Temperatu re greater than 350 MONITO R at least one CC P available . RO
-
( NOTE Pressu rizer pressure greate r than or equal to 2335 psig with rising RCS temperature and a low loop delta-T indicates loss of heat removal capab ilit MONITOR RCS feed and bleed criteria: CHECK th e following:
* Any three S/G wide range levels less than 20% [41 %
Crew ADVj OR
* Pressurizer press ure greater than or equa l to 2335 psig due to loss of secondary heat remova MONITOR CST level greater than 5%.
BOP Appen dix D NUR EG 1021 Revision 9
I Appendi x D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scena rio # 3 Event # S.6.7,8 ( Event Description: Feed Header Rupture, Main Turbine fail to trip, SI auto actuation failure, loss of feed Time T Position I Aoolicant's Actions or Behavior ATTEMPT to establish AFW flow to at least one S /G in the following ord er of priority- - Intact, Ruptured, Faulted :
* CHECK S /G blowdown isolation valves CLOSED . * CHECK control room indications for cause of AFW BOP failure :
0 CST level 0 AFW pump power supply 0 AFW valve alignment May dispatch AUO to check AFW Pumps if not already dispa tche Evaluator Note: Cue console operator to delete auto-start failure and airbound pump malfunctions for 1B MD AFW pump prior to reaching bleed and feed criteri ESTABLISH MD AFW pump flow: CRITICAL TASK ENSURE MD AFW pumps RUNNING .(NO) ( * DISPATCH personnel to restore MD AFW pump flow USING EA-3-10 , Establishing Motor Driven AFW Flo BOP ENSURE AFW level control valves OPE ENSURE MD AFW recirculation valves FCV*3-400 and FCV-3-401 CLOSE CHECK total flow to S /Gs greater than 440 gp BOP US/RO Stops RCPs Scenario mav be terminated when MD AFW flow is establishe Appendix D NUREG 1021 Revision 9
Aooendix D Reauired Operator Actions Form ES-D-2 (' Op Test No.: NRC Scenario # 4 Event # ES- Page-19 - of 22 Event Description: Equipment Verifications Tim e I Position I Applicant's Actions or Behavior ES-O.5 Actio ns CHEC K ERCW system operation: BOP * VERI FY at least four ERCW pumps RUNNIN * VERIFY DIG ERCW supply valves OPE VERIFY CCS pumps RUNNING:
* Pump 1A-A (2A-A) - BOP * Pump 1B-B (2B-B) * Pump Co VERIFY EGTS fans RUNNIN BOP VERIFY generator breakers OPE BOP VER IFY AFW pumps RUNNING:
CRITI CAL TASK
* MD AFW pumps (NO) Must man ually start 1B-B MD BOP AFWPump * TO AFW pump .
App endix D NUREG 1021 Revision 9
Aooendix D Reauired Ooerator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # ES- Page 20 of 22 ( Event Description: Equipment Verifications Time T Position I Aoolicant'sActions or Behavior NOTE AF1N level control valves should NOT be repositioned if manual action has been take n to contro l S/G levels, to establis h flow due to failure, or to isolate a faulted S/G . CHECK AF1N valve alignment: a. VERIFY MD AF1N LCVs in AUTO . b. VERIFY TO AF1N LCVs OPE BOP c. VERIFY MD AF1N pump recirculation valves FCV-3-400 and FCV-3-401 CLOSE ( VERIFY MF1N Isolation :
* MFW pumps TRIPPED * MF1N regulatin g valves CLOSED BOP * MF1N regulating bypass valve contro ller outputs ZERO * MF1N isolation valves CLOSED * MF1N flow ZER MONITOR ECCS operation:
VERIFY ECCS pumps RUNNING: BOP * CCPs
* RHR pumps * SI pumps Appendix D NUREG 1021 Revision 9
Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # ES- Page 21 of 22 ( -- Event Description: Equipment Verifications Time I Position I Applicant's Actions or Behavior VERIFY CCP flow through CCPI * CHECK RCS pressure less than 1500 psig . BOP * VERIFY SI pump flo * CHECK RCS pressure less than 300 psi VERIFY RHR pump flo VERIFY ESF systems ALIGN ED: 0 Phase A ACTUATED: 0 CONTAINMENT ISOLATION PHASE A TRAIN
- A alarm LIT [M-6C, B5].
0 CONTAINMENT ISOLATION PHASE A TRAIN B ala rm LIT [M-6C, B6]. ( 0 Conta inment Ventilation Isolation ACTUATED: 0 CONTAINM ENT VENTILATION ISOLATION TRAIN A alarm LIT [M*6C, C5]. 0 CONTAINMENT VENTILATION ISOLATION T RAIN B alarm LIT [M-6C, C6]. BOP * Status monitor panel s: 0 6C DARK 0 6D DARK 0 6E LIT OUTS IDE outlined area 0 6H DARK 0 6J LI Train A status panel 6K: 0 CNTMT VENT GREEN 0 PHASE A GREEN
* Train B status panel 6L:
0 CNTMT VENT GREEN 0 PHASE A GREEN ( Appendix D NUREG 1021 Revision 9
Appendix D Required Opera tor Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # ES- Page 22 of 22 ( -- Event Description : Equipment Verifications Time I Position I Acc licant's Actions or Behavior MONITOR cont ainment spray NOT required:
* Phase B NOT ACTUATED AND BOP * Containment pressure less than 2.81 psig * Ensure Containment Spray is actuated VERIFY pocket sump pumps STOPPED: [M-15, upper left corner] * HS-77-410 , Rx Bldg Aux Floor and Equipment Drain BOP Sump pump A - * HS-77-411 , Rx Bldg Aux Floor and Equipment Drain Sump pump B.
( DISPATCH perso nnel to perform EA-O-1 , Equipment Checks Following ESF Actuatio BOP Appendi x D NUREG 1021 Revision 9
Operations Chemistry Information ( Sample Point Units Boron Date ITime Goal Limit U1 RCS ppm 1178 Today / Now Variable Variable U2RCS ppm 816 Today / Now Variable Variable U1 RWST ppm 2601 Today / Now 2550 - 2650 2500 - 2700 U2 RWST ppm 2569 Today / Now 2550 - 2650 2500 - 2700 BAT A ppm 6850 Today / Now Variable Variable BATB ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA #2 ppm 2575 Today / Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today / Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today / Now ~2050 ~2000
,*,:~~I~h!um, Ri~~,I,~~ '" :,' : : ::i ,:':" e- " .-' .
".
-....:..-
...;.
'Z * * "
~:- ~
-, ',>j-GQ. al,"' ,:" ; ~~i.;-'::,": M id poJn*t
*._.* *-"L--.* .~_! .. . 1> * * -,;. ' * *
ppm Today / Now >1 >1 ppm 2.43 Today / Now 2.18-2.48 2.33
.~:::\:<~~,?)e (Jma,tY:tQ'~§~~9n~atYJ.l. :~~.k r~~e * H1f~*! m~ti9r(<T<?tEl,I;.~.PM1,!~M799:"~,~!.1 ;~.~l: :'
\ . .... :;r*...'.l:'<> 1.,~*a..<t,;, .,:._ ...~ \ ' h. f{... i-<:~ ..R",,: '-c ~!<11<.k:"".. . iS'N,;. f,. , ~,N.'It1i, .. ,i. ....._f1.i:",*.:tl.,. ~. >I 0(., .... >.*'ol....... ~ .. .. ... I;w.;.~ ... ;P... _ ~, i< .-,_ ).,i', .. .\ .
,j,:
'* *"
C' "
- ,
Indicator Units U1 Date I Time U2 DatelTime SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now S1137.5 CVE Leakrate gpd < Today / Now < Today / Now 5 gpd leak equivalent cpm 229 Today / Now 68 Today / Now 15 gpd (30 min increase) cpm 567 Today / Now 83 Today / Now 30 gpd leak equivalent cpm 11 74 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today / Now 150 gpd leak equivalent cpm 5710 Today / Now 870 Today / Now CVE Air Inleakage cfm 10 Today / Now 1 Today / Now Bkgd on 99/119 cfm 40 Today / Now 40 Today / Now (
SHIFT TURNOVER CHECKLIST Page 1 of 3 Today
[8J SM [8J US/MCR Unit 1 ----'--- [8J UO Unit 1 ----'---
Off-going - Name o AUO Station
- SON ---- [8J STA (STA Function ) AUO Comp Actions On-coming - Name Part 1 - Completed by Off-going Shift/Reviewed by On-coming Shift:
Abnormal E ui ment Lineu IConditions: MAIN CONTROL ROOM(7690) (593-5409) Train B Week
* 1-PCV-68-340D Valve Controller is drifting; (WO 06-080000-000). Pink tag on 1-M- TURBINE BUILDING (7771) (593-5416) * 1-RM-90-120&121 SG BD Rad Monitor DOS; Investigate the pump/instrument failure (WO 06-080880-000). Pink tag on 1-M-1 * None II AUXILIARY BUILDING (7775) (593-54 14) I * CCP 1B-B Out of Service: ODS for previous 8 hrs. to repair leakage on pump discharge; expected return to service -12 hrs. (WO 06-080025-000) * U1 TDAFW Pump has been inoperable for 10 hours. The pump was tagged due to a steam lea Tech Support and MMG determined and completed repairs necessary. Post maintenance testing is in progres Res Leakage (SI-137.0) I Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600)
(
SHIFT TURNOVER CHECKLIST Page 2 of 3 Today ( 51fTest in Progress/Planned: (Including Need for New Brief) 0 51-401 release package (wi Chem Supvr) for SGBD releases to the rive U1 TDAFW Pump post-maintenance testing is in progres Major Activities/Procedures in Progress/Planned : 0 Power was reduced to 76 % Rx Power (73 % Turb load) -36 hours ago to reduce plant runback risk while Maintenance and Engineering evaluate a 1A MFP potential control system proble Maintain current plant conditions until evaluation is complet Radiological Changes in Plant Dur ing Shift: 0 NONE expecte l ~ft'~-: J;'; t};t:':l;} ~~'~ - 'jC!' ~3;:, ; \~t :!;,H'~ i~~ - " , -* ~ j_ * LCO/O DCMfTRM ACTIONS ]:;'; - j , ;,; ,". ,, ;,,~ -- ' ; - ' -;'1'; < ;;";X,c --
-' ,;" 'j -j. " " ,
0 TS 3.5.2.a, TRM 3.1.2.2. for 1B-B CCP 00 TS 3.7.1.2.a for TDAFWPp
* ODCM 1.1.1 action 31 for 1-RM-90-1201121 005 Pan 2 - Performed by on-coming shift D Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N1A for AUO's)
D Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shift Turnover; D Standing Orde rs D LCO(s) in Actions (N/A for AUOs) D Immed iate Required Reading D TACF (NIA for AUO's) Part 3 - Performed by both off-going and on-coming shift D Walkdown of MCR Control Boards (N/A for AUG's) Relief Time: Relief Date; today TVA 40741 [03-2001J OPOP-!-! [03-14-2001
SHIFT TURNOVER CHECKLIST Page 3 of 3 Today ( Disabled Annunciators PANEL WINDOW ANNUNCIATOR . WO I PER Number Equipment Off -Normal (Pink Tags) UNID And Noun Name Panel Problem Description WOlPER Number
-
( MCRWO LIST ID And Noun Name Panel Problem Description WOlPER Number (
UNIT ONE REACTIVITY BRIEF Date: Today Time: Now ( RCS Boron: 1178 ppm Today I BA Controller Setpoint: 29 % '" I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850ppm I BAT C Boron: 6850ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 185: 13 gallons of acid, 65 gallons of water
'" Venfy boric acid flow controller IS set at Adjusted SA Contro ller Setting law 0-50-62-7 section Gallons of acid : 25 Gallons of water: 119 Rod Steps: 2 Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 175 Steps on bank D 94 gallons 30% 154 Steps on bank D 280 gallons 50% - 129 Steps on bank D 474 gallons U These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or 50-62-7 calculated values. These values are calculated assum ing 100% steady state power operat ion only. Eng ineering data last updated one week ago. Data Valid until three weeks from no Number of dilutions: 1 Number of borations: Rod steps in:
Gallons per dilution: 12 Gallons per boration: Rod steps out: Total amount diluted : 12 Total amount borated: Net change: IN/Out Number of dilutions: 1 Number of borations : Rod steps in: Gallons per dilution: 12 Gallons per boration: Rod steps out: Total expected dilution: 12 Total expected boration: Net change : In/Out Remarks: Rx Power - 76% MWD/MTU - 1000 Xenon - 2538 PCM Equilibrium Samarium -1 019 PCM Last Dilution Complete -1 hour ag Next Unit 1 Flux Map is scheduled-three weeks from now ( Jnit Supervis or: Name/Date
Operations Chemistry Information ( .;; . ~%::o.;<.; ",...;, . c,,, ,',,";!, .' 't .v*,,':*
" .8
" . ..".
' .... Resu oron . Its
,t :". ***~:l< ~:::~,t,~ *::~* .... :.! *'t2"b\:j~~:t }_"::"~:~~"~ ";;" :" ,:',' :.
Sample Point Units Boron Date I Time Limit U1 RCS ppm 1178 Today / Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable U1 RWST ppm 2601 Today / Now 2550*2650 2500 - 2700 U2 RWST ppm 2569 Today / Now 2550 - 2650 2500 - 2700 BAT A ppm 6850 Today / Now Variable Variable BATB ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA#2 ppm 2575 Today / Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today / Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 -- ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today / Now ? 2050 ? 2000
.
.v-:
:?:':::~ *\bi~,~L~J2L5~:~. ~ Its :: * . *. * . ~ :S1~~~~ri\illi3\e: ,F:~;i&~81R.~;:*;. I{~
U1 RCS ppm Today / Now >1 >1 U2 RCS ppm 2.43 Today / Now 2.18-2.48 2.33 I t~~Jili:1~~'~\.,\: :;E *; :;:~.rl*m~~X£'~;~::!~'~i~ ;gu~[rYLea~~:~~;~'M1!g~'r:atio~.* qgl~;!; *~ F.M .:fl~t~2¢~:WV ~) ".. '.,:;:;~'~<L' ,}..,( Indicator Un its U1 Date I Time U2 Date/Time SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now S1137 .5 CVE Leakrate gpd < Today / Now < Today / Now 5 gpd leak equivalent epm 229 Today / Now 68 Today / Now 15 gpd (30 min increase) cpm 567 Today / Now 83 Today / Now 30 gpd leak equivalent cpm 1174 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today / Now 150 gpd leak equivalent epm 5710 Today / Now 870 Today / Now CVE Air Inleakage efm 10 Today / Now 1 Today / Now Bkgd on 99/119 ctrn 40 Today / Now 40 Today / Now (,
SHIFT TUR NOVER CHECKLIST Page 1 of 3 Tod ay r ( l8] SM l8] US/Me R Unit 1
[8) UO Unit 1 Off-going - Name 0 AUG Station SON t8J STA (STA Function) AUO Comp Actions On-comlnq - Name Part 1 . Completed by OH-going ShiftJReviewed by On-coming Shi ft:
Abnorma l Equ ipment Lineup/Conditions:
':. "' *~ ~::;'ll** :;*!* "Il!t*~* :,-: 7... *J '~t~ ........ *J ... . . . .".~ ;.r....ro-: .. l-: .' -... ~ *. "!....:~,,: ,.:.* ~. :. e."; ~. _r*~***.,1 *. *. *1* ..** ~.'t ,~ ~..:( . .;; ::.1....;'".-**.-;:j ~'-L '-: I * , . ...( :- ;./r**~*J- *4"!"'"*'}~':* **ali"""'(. '
:''~:;..~' ..,!:::.:..;-;;~.;;\~ :,,~;,r, :..~.'.. .c*..:~* .;;:~<. .:-,..... *.' MAJN*CONtROL*ilbbM{7,69dJ'(~5409) \ "-* -,~A; J;) ;;'* ::*': :.:.
~ . :...... : '. ..;:>: !
~ . St\"~:~*.,( . !,..;\"':-.'-1~" :\~~-i~'m";,'H~* *
..:~ . _ .,...~,_.;,o ~:;r ' ~" ~ __ .,
..h" - ;:.,,;l'~ ~("~ . v' .;..' ...; (~ ~......;. !:~'. I..... .. . .. "'(".0_ " e- .- .* ~ ___ * _ -T:" ... _ * * * *~ _ ... _ _
~
*~_tJ ~":'f" *.... ........ '}._'" '-:.1 -:0': .! ,. <;," ~';",:J . . ,-
,~~~-:f),o.~...t .. -f .. ~. .. } ....~.. a......~.'/'
Train a Week
* 1-PCV-68-340 D Valve Contro ll er is drifting; (WO 06-080000 -000). Pink tag on 1-M- * 1-RM-90-120&121 SG aD Rad Monitor 005; Investiga te th e pump/ins trument failure (Wa 06-080880-000). Pink tag on 1-M-1 * Non e AUXILIARY BUILDING (7775) (593-5414) * CCP 1a-a Out of Service : 005 for p revio us 8 hrs. to repa ir leakag e on p ump d ischarge ; exp ec ted return to service - 12 hrs. (WO 06-080025-000) * U1 TDAFW Pump has been inoperable for 10 hours. The pump was tagged due to a steam lea Tech Support and MMG determined and completed repairs necessary. Post ma intenance testing is in progres Re s Leakage (SI-137.0) I To tal 0.03 g pm / Identified 0.02g pm / Unide ntified 0.01 gpm. (Tod ay 0600)
--_.,
SHIFT TURNOVER CHECKLIST Page 2 of 3 Today (
.:WTest in Progress/Planned: (Including Need for New Brief)
* 51-401 release package (wi Chem Supvr) for SGBD releases to the rive * U1 TDAFW Pump post-maintenance testing is in progres Major Activities/Procedures in Progress/Planned :
* Power was reduced to 76 % Rx Power (73 % Turb load) -36 hours ago to reduce plant runback risk while Maintenance and Engineering evaluate a 1A MFP potential control system proble * Maintain current plant conditions un til evaluation is complet Rad iological Changes in Plant During Shift:
* NONE expecte ',:'-,: *;;*O'. :*** *S**::*2:...;,*'. ,. ':-,' ~*,~ ':y1.'y~..::* ;~ \. l:: :. ' j LCO/ODCMfTRM ACTIONS
,. -, .- >.:>::,:{ } ~ :SS: :.;J.'~:: :i';,~x l/;:"Y::~'::'::i\;y.:,::~ ::::: I
* TS 3.5.2.a, TRM 3.1.2.2. for 18-8 CCP 00 * TS 3.7.1.2.a for TDAFWPp
* ODCM 1.1.1 action 31 for 1-RM*90-1201121 005 Part 2 - Perform ed b y on -co mi ng shift D Review of Operating Log Since Last Shift Held or 3 Days. Whichever is Less (N/A for AUO's)
D Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shift Turnover: D Standing Orders D LCO(s) in Actions (N/A lor AUOs) D Immediate Required Reading D TACF (N/A for AUO's) Part 3 - Perf orm ed by both oft-going and on -com ing shift D W alkdown of MeR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40741 [03 -200' 1 OPDP-, -, [03-' 4-200 1 (
SHIFT TURNOVER CHECKLIST Page 3 of 3 Today ( Dis abled Annunciators PANEL WINDOW ANNUNCIATO WO I PER Number Eoui pment Off* Normal (Pink Taqs ) UNID And Noun Name Panel Probl em Descripti on WO I PER Numbe r
-- (
MCRWO LIST ID And Noun Name Panel Probl em Description WOlP ER Number (
UNIT ONE REACTIVITY BRIEF ( Date: Today Time: Now RCS Boron : 1178 ppm Today I BA Controller Setpoint: 29 % << I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850ppm I BAT C Boron: 6850ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from 185: 13 gallons of acid 65 gallons of water I
* Venfy boric acid flow controller IS set at Adjusted BA Controller Settinq law 0-SO-62-7 section Gallons of acid: 25 Gallons of water: 119 Rod Steps: 2
. ...-: :... :~' .. *..*: ~;-;: ;:,:-< E*s t i rriat e d 'rods/b oron' for' emergency step power reduction ~~ <~ :.~ ~;: ' .; ':~~:;,;, " :.~~. ',~_ ~ '.':'
'! .. ..... -." ". ...~ .- ...., - " ... . ~ ..... : :- : ' . . ** **. *~ . . .- . ~. ~ . ~t . - .
(:':'- <t.*. /. (As suming Xeno n equilibrium and no reactivity eHeets due to Xenon, 2/3 total reactivity from rods,' 1/3 from"boron) ' " ,:';::: " . ,:~
">.1 ... *
Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 175 Steps on bank D 94 gallons 30% 154 Steps on bank D 280 gallons 50% -- 129 Steps on bank D 474 gallons
** Th ese values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-62-7 calcula ed values. These values are calculated assuming 100% s eady state power ope ration only. Engineering data last updated one week ago. Data Valid until three weeks from no Number of dilutions: 1 Number of borations: Rod steps in:
Gallons per dilution: 12 Gallons per boration: Rod steps out: Total amount diluted: 12 Total amount borated: Net change: IN/Out Number of dilutions: 1 Number of borations: Rod steps in: Gallons per dilution: 12 Gallons per boration: Rod steps out: Total expected dilution: 12 Total expected boration: Net change: In/Out Remarks: Rx Power - 76% MWD/MTU - 1000 Xenon - 2538 peM Equilibrium Samarium -1 019 PCM Last Dilution Complete - 1 hour ag Next Unit 1 Flux Map is scheduled-three weeks from now Jnit Supe rvisor : Name/Date
I
* I Operations Chemistry Information (
\. :0f~¥~!(,T~ ;~~:i};~::i:~:: ~;~', :'>'" :H:~~g!1~7'v~4~~~~s " . :,:i'*:i~":;~ ", ; Sample Point Units Boron Date I Time Goal Limit U1 RCS ppm 1178 Today / Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable U1 RWST ppm 2601 Today / Now 2550*2650 2500 - 2700 U2 RWST ppm 2569 Today / Now 2550 - 2650 2500 - 2700 BAT A ppm 6850 Today / Now Variable Variable BATB ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA#2 ppm 2575 Today / Now 2470*2630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400*2700 U2 CLA #1 ppm 2531 Today / Now 2470*2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Toda y / Now 2470*2630 2400-2700 U2 CLA #4 ppm 2526 Tod ay / Now 2470-2630 2400-2700 Spen t Fuel Pool ppm 2547 Today / Now ~ 2050 ~2000
* ~\;;*~E~~~:~;~;m~!5.~~,~ 1ts '~.t:t~~frlj~?;~li;r~X: * .': ": ~..':: '::;'\.:~t; ; ,;; " ,9()~Jl{{~iiki~;0 ;~(,. :' ;/}~1t2P'~J.n~~, *. :X~;
ppm Today Now >1 >1 ppm 2.43 Today / Now 2.18-2.48 2.33
.;'Y2, :;tt>/: :::;!:q{;E I~m~lj;, ~,Ci;§;~§8:tlg~K~ \~a~,~:~~*~::l~1?0~m.~ ti on ::<:Ig!~!. c,p.~ R~:~~"q;~~U} ~) ,' . "" ,..
Indicat or Units U1 Date I Time U2 Date/Time SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < Today / Now < Today / Now 5 gpd leak equivalent cpm 229 Today / Now 68 Today / Now 15 gpd (30 min increase) cpm 567 Today / Now 83 Today / Now 30 gpd leak equivalent cpm 1174 Tod ay / Now 206 Today / Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today / Now 150 gpd leak equivalent cpm 5710 Today / Now 870 Today / Now CVE Air Inleakage cfm 10 Today / Now 1 Today / Now Bkgd on 99/119 cfm 40 Today / Now 40 Today / Now (
!* *, .
SHIFT TURNOVER CHECKLIST Page 1 of 3 Today (
[gJ SM [gJ US/MCR Unit 1 ~ UO Unit 1 Off-going - Name 0 AUO Station SON IZ1 STA (STA Funct ion) AUO Comp Actions On-coming - Name Part 1 - Completed by Off-going Shift/Reviewed by On-coming Sh ift:
Abnormal Equipment Lineup/Conditions:
:?::~,,~~~.~~!~i*~:~!~ tf) ~,"'~JY1~~,~~~\i~*}~1 ~*~~~;'*1*.~;~:t~~~;~ ~,t:* ~ I r~~: :.-- *1;.*"v ~~' l~f~ :,".,~;;rVi~.."";(..':'.:\' ~ -/I,!\~:~~ ",for: \=1 ~;'j~. (-:./.:;: frclt.~~i:~..j t ~J:~': :~i'~~f5 ~,;,r'*i~"i*j~t i' )'. ~g;:: -;~~ ~
: ~~:~:".li~ t~.~:.t..~~~,;. l~~.;.(~~~**~~ .,.Ji.4~l:~. ; ~~ * :';,," . ,~" >.:'MAIN
,.<"' 1"' :"" ' " '~"<")'Y' ~ v. '>-.';f ~ v ~ I * :';'it ." ,; "r,, ;" '.' " :' ..
'0 ' .' . ,. *
CONTROL'ROOM(7690r(59~5409)
* ,,' .- '. '- 0/ 1 " "~' \. ..__ -. - . . ~., .
- ,.' (.,'~~ ,.,, {.<r., ': "YO )' .. ~v : ' '- ' ', "" ..' ',~'I.\!.. \" :... ~~..("
_ _,' , ... ~ .. . ~:;=.. ~"i~i.: ,f:Iir~~r~~.~:J.iJ~*"f~~:::::J;*~{.! f:';';!;rit./~VI~i~~ Train B Week
* 1-PCV-68-340D Valve Controller is drifting; (WO 06~080000-000). Pink tag on 1-M- * 1-RM-90-120&121 SG BD Rad Monitor 005; Investigate the pump/instrument failure (WO 06-080880-000). Pink tag on 1-M-1 AUXILIARY BUILDING (7775) (593-54 14) * CCP 1B-B Out of Service: 005 for previous 8 hrs. to repair leakage on pump discharge; expected return to service - 12 hrs. (WO 06-080025-000) * U1 TDAFW Pump has been inoperable for 10 hours. The pump was tagged due to a steam lea Tech Support and MMG determined and completed repairs necessary. Post maintenance testing is in progres Res Leakage (SI-137.0) I Total 0.03 gpm /Identified 0.02gpm / Unidentified 0.01 gpm. (Today 0600)
(
'-' ...
SHIFT TURNOVER CHECKLIST Page 2 of 3 Today ( SIITest in Progress/Planned: (InclUding Need for New Brief)
* SI-401 release package (wI Chem Supvr) for SGBD releases to the rive * U1 TDAFW Pump post-maintenance testing is in progres Major Activities /Procedures in Progress/Planned:
* Po wer was reduced to 76 % Rx Power (73 % Turb load) -36 hours ago to reduce plant runback risk while Maintenance and Engineering evaluate a 1A MFP potential control system proble * Maintain current plant conditions until evaluation is complet Radiological Changes in Plant During Shift:
* NONE expecte I~~?;:;~ :':" .~'. '" >.,. , N
#' . <.:'.~'?' "; "~.':~::,;" . ..~ '..
' ;."').;" :,,:,,",..~ :.:,
';. ,." } .:' ;. t:,'>:~~* >.' . '. ~~. LCO/ODCMfTRM ~' J ~~ .-,
ACTlbNS ' :'::~ ' .:.".: '>~l:~i;::~<' .,:~::1~~5*j t;:: ~~.~/?:~~::r;~\:?:: ~~*~~'. :. ~~~.~~':~~?'::;::~;~:.: . . I
- , * TS 3.5.2.a, TRM 3.1.2.2. for 1B-B CCP 00 * TS 3.7.1 .2.8 tor TDAFWPp I ODCM 1.1.1 action 31 for 1-RM-90-1201121 005 Part 2 - Perf or med b y o n-comi ng shi ft 0 Review of Operating Log Since Last Shift Held or 3 Days. Whichever is Less (N/A for AUO's)
0 Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Follow ing Programs lor Changes Since Last Shift Turnover: 0 Standing Orders 0 LCO(s) in Actions (N/A lor AUOs) 0 Immediate Required Reading 0 TAC F (N/A for AUO's) Part 3 - Perf ormed by bo th o ff-going and on -co ming shift 0 Walkdown 01 MCR Control Boards (N/A lor AUO's) Relief Time : Relief Date: today TV A 40741 [03-2001] OPDP-1-1 [03- 14-2001 (
*.
SHIFT TURNOVER CHECKLIST Page 3 of 3 To day ( Di sabled Annunciators PANEL WINDOW ANNUNCIATOR . WO I PER Number Equip ment Off-Normal (Pin k Tags) UNID And Noun Name Panel Problem Descripti on w e I PER Numb er
-_.
( MCR we LIST ID And Noun Name Panel Probl em Descr iption WOlPER Number
: I UNIT ONE REACTIVITY BRIEF ( Date: Today Time: Now RCS Boron: 1178 ppm Today I BA Controller Setpoint: 29 % W I RCS B-10 Depletion: 2 ppm Operable BAT: A I BAT A Boron: 6850ppm I BAT C Boron: 6850ppm \ RWST Boron: 2601 ppm Nominal Gallons per rod step from 185: 13 gallons of acid, 65 gallons of water . Verify boric acid flow controller IS set at Adjusted SA Controller Setting law 0-5 0 -62-7 section Gallons of acid: 25 Gallons of wat er: 119 Rod Steps: 2 . ,.~:/.,./:~.":;.::" . :.V~\~::~*:.~~~! ~:la~~e. rp'd5/bor~~ .fp r eme rgency step power r~~u~tion' ~~ .::";"~ S ;~rs~ \~~:\~~,:~;.:~ ~:~_ .,: '; -~J. .: ... . (Assuming Xenon eqUlhbn urn and no reactivity eHects due to Xenon. 2/3 total reactivity from rods, .1/3 from bor on) ~. " ~ ';'.\ . ,: >.
Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 175 Steps on bank 0 94 gallons 30% 154 Steps on bank 0 280 gallons 50% -- 129 Steps on bank 0 474 gallons
.. These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or 50-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until three weeks from no Number of dilutions: 1 Number of borations: Rod steps in:
Gallons per dilution: 12 Gallons per boration: Rod steps out: Total amount diluted : 12 Total amount borated: Net change: IN/Out Number of dilutions: 1 Number of borations: Rod steps in: Gallons per dilution: 12 Gallons per boration: Rod steps out: Total expected dilution: 12 Total expected bora tion: Net change: In/Out Remarks: Rx Power - 76% MWO/MTU - 1000 Xenon - 2538 PCM Equilibrium Samarium -1019 PCM Last Dilution Complete -1 hour ag Next Unit 1 Flux Map is scheduled-three weeks from now ( Jnit Supervisor: Name/Date
I Appendi x D Scenario Outline Form ES-D-1 ( Facility: Sequoyah Scena rio No.: 4 Op Test No.: NRC Examiners: Operators: Initial Conditi ons : 10.3 % power or higher in Intermediate Range Turnover: Raise Power to POA Target CTs: Start at least 1 EDG prior to placing equipment in PTL in ECA- Start at least 1 CCP prior to completion of E-O Start CCS Pump 1A-A prior to completion of E-O Event N Mall. N Event Type' Event Description 1 R-RO Raise power T+ O 2 RC05 C-RO/SRO PORV 68-334 Leakage - Tech Spec evaluation
-
T+1 0 TS- SRO c'.
T+20
CV09 CC1 0B I-RO/SRO C-BOP/SRO VCT Level Channel 130 fails high 1B-B CCS Pump trip and failure of backup pump auto start ; Manual start of backup required T+30 CC09A-pre-insert 5 CC05A C-BOP/SRO RCP TBHX Supply Line Lea T+40 6 TS-SRO Call from Engineering - SI Pumps 1A-A and 1B-B are found to have the wrong grade of lube oil, affecting operabili ty of both pump T+55 7 TH02C M-AII SBLOCA resulting in reacto r trip and safety injectio T+60 8 EDOl M-AII Loss of Off-Site Power resulting in a ioss of power to both 6.9 KV Shutdown Board EG03A- C-BOP lA-A EDG fails to start in auto pre-insert 1B-B EDG trips and cannot be started EG02B-pre-insert 10 SI01A C-RO 1A-A 81 Pump Trip Cv35a= -1 1A-A CCP fails to auto start
, (C)omponent, (M)ajor (N)orma l, (R)eactivlty, (I)nstrument, Appe ndix D NUR EG 1021 Revision 9
I Appendi x D Scenario Outline Form ES-D-1 ( Scenario 4 Summary '. The crew will assume the shift with the unit in a startup, power in the Intermediate Range, with instructions to conti nue raising powe r to the Point of Adding Heat After the RO raises power, PORV 68-334 will leak, requiring the crew to close the associa ted PORV Block Valve to isolate the leak. Technical Specification actio ns appl When the plant is stable, VCT level transmitter 130 will fail high , requiring the RO to man ually control VCT level by stopping the diversion of letdow When VCT level is stable, 1B*B CCS Pump will trip. The backup pump will fail to auto matica lly start, and must be manually sta rted in accordance with AOP-M.0 W hen the standby CCS pump is running, an RCP Thermal Barrier Heat Exchanger supply line leak will develop . The crew will respond in accorda nce with AOP-R.0 Engineering will call in a report of SI Pump inoperability. The SRO will refer to Technical Specifications for the appropriate action. (TS 3.0.3) A SBLOCA will develop after stabilization fro m the CCS leak. The crew will trip the reactor and enter E-O. Shortly after the trip , off-site power is lost. 1A-A EDG fails to auto sta rt, and must be sta rted manually. 1B-B EDG trips and cannot be starte The crew must start 1A-A EDG and place it on the bus to avoid entering ECA-O.O ( and pe rforming the coping step Additionally, 1A-A SI Pump trips and 1A-A CCP fails to auto start. Starting the pump is critical to a SBLO CA with the 1B-B CCP unavailable due to loss of power. Starting CCS Pump 1A-A is also critical to the continued operat ion of Train 'A' ECCS equipment EOP flow: E-O- FR-Z.1 - E-1 (Note ; ECA- O.O MAY be entered briefly prior to starting EDG) The scenario may be terminated upon comp letion of FR- PSA significant task: Start EDG, Start CCP PSA significant DAS: SBLOCA PSA significant component failure: CCS Pump trip Appendix D NUREG 1021 Revision 9
ESG-4 SCN File 03/2 3/0 7 EVENT IC /MF/RF/OR # DESCRIPTION/EXPECTED ACTIO NSIBOOTH FEEDBA CK ( Simulator IC-97 IC - 10-3%, BOL [-1000 I\IWD/I\IT UI CB ' 0 ' Rod s @ 150 steps, all others @ 228 steps;
[BI = 17IIppm; Ba Blender setting: 48%
Xe/Sm equilihrium Console Operator action s: Place simulator ill run and perform the Isllssiss:
* Place the 1\1 ODE 2 sign on 1-1\1-4 * Place T rain Week B sign MFs, RFs, IM F CC09A f: I lA-A CCS Defeat Pump Auto-Start DRs are II\IF EDO I f: I d: 30 Loss o f Off-Site Power resulting in a loss of power to both 6.9 KV Shutdown active e: I Board when the seN tile is l;\lF EG08A f:1 l A-A EDG fails to start in AUTO MATIC; loade II\IF EGOm f:1 1B-B EDG trios and cannot be re-started; 1;\11' SIOI A f:1 l A-A SI Pump trips on auto star set yp_ cv35a =-1 1A-A CCP fails to auto start- CONSOLE NOT E: cannot sec status on malfunction screen. Will require sim svs to verifv malfunction is activ Raise Power to POA . IMF RC05 f:5 k:2 I-FCV-68-334 Fail s 5% Op en; Pressurizer PORV fails open ; TS evaluation; ( Support sta f]'renort:
If AUOs dispatched to remove powerfrom POR I' Block Val ve, 1- FCV-68-333, wait - 3 minutes and use the remote/ unction R CR041:0 to remove p owerfrom the block valv _ 1MF CV09 1': I k:3 VCT Level C h 130 fails high ;
* This affects VCT level transmitter LT -62-130A and will produce: - LCV-62-l 18 diverts letdown from vcr to the holdup tanks. vc r level will decrease; - VCT makeup process will terminate if makeup was in progress at the time the mal function was activated; - Auto makeup to VCT is defeated; - CVCS VCT to RWST low-level transfer is defeate Support sta([report:
Whell tvlSS or IMs contacted to repair level channel, inform the crew that the IMs will report to the MCR in - 25 minute . IM F CCIOB 1':1 IB-B CCS Pump trip; TS evaluation; k:4 Support sta([ report: When personnel disp atched, wait - 3 minu tes then rep ort motor hot to the touch, burned electrical insulation smell at the CCS Pump 1I10to IMF CC09A 1': I IA-A CCS Pump auto start failure ; Manual sta rt required; (pre-insert) The lA pump will fail to start on a blackout, SI or low pressure signals; Manual start is availabl Page I of 2 G:\Prep Week files\As Sub mitted Op er ational E:u m\Sccnari os\Scenal'"io 4\.' -21-07 ESG-4.doe
E SG-4 SC N F ile 03 /23/0 7 EVENT I C /MF/RF/OR # DE SCRIPTlOi'/ EXPE C T ED AC TI O NS/B O O T H FEEDBACK ( IM F CC05A f:l #1 RCP T BHX CCS Leak@ - 200 gpm; TS evaluation; k:5 Component Cooling Pipe Break Inside Containment; #1 RCP therma l barrier HTX inlet pipe breaks. # 1 RCI' thermal barrier HTX flow decreases (will also decrease to the other three pumps as well since the cooling water supply is going out the break. TB HTX isolation valves and TBBl's will not isolate since the isolation and trip signal is initiated when the return flow is more than 5 gpm greater than the supply flow. The plant will continued loss ofCC S water to containment w/ surge tank level decrease and containmen t sump level increas . ROLE PLAY: As Engineer ing -Call MCR and inform SRO that st Pumps tA-A and IB-B are fo und to huve the IITOllg grade of/ube oil. affecting cperobillty ofboth pump . D lF T H02C f:.09 SBLOCA re sulting in reactor trip an d safety inj ection; k:7 Small RCS Leak on LOOD 3; IM F EDOI f: 1 d:3 0 T ota l Loss of Offsite Power; e: l Crew will concurrently perform EOPs plus ES-0.5 then AOP-I'.O I; U2 will accept/complete AOP-P.O I when Step 9 CA restoration is complete . I!\-IF EGOSA f: I I A-A EDG fail s to sta rt in auto;
- Start at least I EDG prior to placing equip ment in PTL in ECA-O .O l A-A EDG fails to sta r t from a SI Signal , 6.9KV SDBd BIO or UV; M-26A ( and L-4A eme rgency manual start PB s an d M-l emergency sta r t liS remain op erable; Mannal EDG star t is active fr om these loca tions with this malfunction activ IM F EG02B f:l 1B-B EDG trips and cannot be started; EDG current differential relay trips. locks out output breaker 19 12; 6.9kY SDBd IA -A is not damaged by the malfuncti on; 1 set yp_ cv35a- l lA-A Ce nt rifuga l C ha rging Pump (CC P) Auto Sta rt Failure; (Malfunction is pre-inserted)
Manual CCP starting is available to the operato IRF IAR12 f:l k:9 RES ET Control Air CompoTRIPS. HS-32-25B IRF lAR02f:l k:9 AIR COMP-B Local Operation - ON d: 30 When requested by crew lAW EA-32-2; NOTE : On ly IA CA Comp ressor is available; IR F IAR06 f:2 OPENS FCV-32-80, 102, & 110 after all isolation signals rese k:lO IRF IAR07 f:2 When requested by crew lAW EA-32-1; d:30 k :l0 IR F IAROS f:2 Crew will concurrently perform EOPs plus ES-0.5 then AOP-P.O I; U2 will d:60 k:l0 accept/complete AOP*P .OI after Step 9. CA restoration is complete Ter mination Criter ia Complete ES-I.2 S tep 14, RCS cooldown initiate PaRI: 2 of 2 G:\Prep Week files\As Sub mitted Operational Exam'Scenarios'Scenario ~ \3* 2I -0 7 ESC-4.doc
I Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario # 4 Event # - ' - _ _ _ _ Page 3 of _ 3:::2=--; Event Description: Raise Powe r Time I Position I Aoolicanf s Actions or Behavior Boot h In struct or: No action req uir ed fo r Event 1 Indications availabl e: No ne. Crew will perf orm startup lAW O-GO-3, Section NOTE Averag e toop aT (U0485) is considered to be the most accurate power indication below 15% power. NIS power range and steam dump demand should also be monitore (REFER TO 0-SO-1-2 tor steam dump demand program.)
WITHDRAW RODS OR DILUTE to bring reactor power to RO between 1 and 2% RTP, while continuina with this instruction.
( NOTE After refue ling operations the "Initial Startup System Parameter Log" is performed during power escalations to provide the operator with alternate indications of power level (indications independent of calorim etric calculations). If significant differences occur (approx . 5%) betwee n the alternate power indications then Engineering should be notifie IF startup is after a refueling or maintena nce on NIS, THEN INITIATE performance of 0-PI-OPS-000-001.0, Initial Startup System Parameter Log. COMPARE NIS power range instrumentation with loop eT indicato rs and steam dump US demand to evaluate accuracy of PRM This SteD N/A SELECT the highest reading IRM or ""I and PRM channels to be recorded on NR 4 RO ( REVIEW plant parameters and indications to determine plant Crew stabilitv prior to startup of Main Feed Pum Appendix D NUREG 1021 Revision 9
I Append ix D Reguired Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event ~ -'- Page 4 of _ 3:;::2'---1 ( Event Description: Raise Power Time I Position I Aoolicant's Actions or Behavior MAINTAIN reactor power approximat ely 1%. RO NOTE Steps 5.2[7] and 5.2[81 may be pertormed in any order. (The tollowinc 2 steps) WHEN total Aux FW flow to SGs 1 and 2 is constant and greater than or equal to 300 gpm, THEN CLOSE [FCV-3-400], AFW PUMP A RECIRC ISOL VLV , and PLACE handswitch BOP
[HS-3-400A] in the PULL TO LOCK positio W HEN total Aux FW flow to SGs 3 and 4 is constant and ( BOP greater than or equal to 300 gpm, THEN CLOS E [FCV-3-401],
AFW PUMP B RECIRC ISOL VLV, and PLACE handswitch
[HS-3- 401A] in the PULL TO LOCK positio NOTE Control rod bank D should be <165 steps at steady state power levels below 85% RT This guidance is to preclude long-term operation at <165 steps to avoid potential impact on safety ana lysis assumption s. Short-term operation at <165 steps is NOT a concer ENSURE the plant is stabilized between 1 and 2% reactor RO Dowe COMPARE NIS intermediate range instrumentation with loop RO ~T indications to evaluat e accurac v of IRM RECORD IRM readings : N35 % RTP N36 % RTP RO When power has been raised sufficie ntly to record a rea ctivity ma nipulati on, lead examiner may cue t he next eve nt (
Appendix D NUREG 1021 Revision 9
I App endix D Required Operat or A cti o ns Fo rm ES-D-2 I C'
"
Op Test No.: Event Description: NRC Scenario # 4 PORV 68*334 Leakage Event # 2 of 32 Time I Position I Aoolicant's Actions or Behavior Booth Instructor: When directed, initiate Event 2 Indications available: 1-AR-M5-A, E2, PRESSURIZER POWER RELIEF LINE TEMP HIGH 1-AR-M5-A-D2, PRESSURIZER SAFETY VALVE LINES TEMP HIGH PORV 334 position indication extinguished Acoustic monitors on M4 indicate flow Resp ond in ac cor d an ce wi t h Al arm Respon se Pro ced ur es C rew (AOP-R.OS Sect 2.1 Step 10.c RNO actions are similar to ARP actions; see following) US may use or refer to AO P-R.05, RCS Leakage Identification Sect ion 2.1 Small Reactor Coo lant System Leak: ( 1. CONTROL charging flow to maintain pzr leve l on progra . MONIT OR pzr level >10% & STA BLE or RISIN . MAINTA IN VCT level with make u . MONIT OR containment pressure STA BLE or DROPPIN . MONIT OR RCS pressu re STA BLE or RISIN . CHECK secondary side radiation NORMA L CHEC K leak inside containme nt Crew 8. CHECK containment airborne activity RISING (RM-90-106 or 112) ENSURE containment purging and venting STO PPED: 10. DETERMI NE leakage source: CHECK leakage source UNKNOWN (YES) ISOLATE letdown and cha rging (YES) CHECK pressurizer PORVs NORMAL (NO)
* Tailp ipe temp erature (elevated) * Acoustic mon itors (elevated)
Go to RNO App endix D NUREG 10 21 Revi si on 9
I Append ix D Required Operator Actions Form ES-D-2 I c Op Test No.: Event Description: NRC Scenario # 4 PORV 68-334 Leakage Event # 2 of 32 Time I Position I Aoolicant's Actions or Behavior Evaluator Note: The following steps are from the ARP. AOP-R.05 Sect 2.1 Step 10.c RNO actions are simila IF PZR pressure is less than 2315 psig (PORV reset) THEN ENSURE both power relief valves close RO * RO attempts to close but has no position indicatio * RO closes block valve 333 CHECK temp erature on PORV discharge line to dete rmine which valve is leaking (M-4). [TI-68-331 (PORVs); TI-68-330 (SV-68-563); TI-68-329 (SV-68-564); TI-68-328 (SV-68-565)] RO
- * Indication is PORV leak. Other temperatures are also elevated c
CHECK 1-XX-68-363A "PZR PORV ACCOUSTI C MONITORS (M-4) to determine which PORV or safety valve is leakin RO * Indication is PORV 334 EVALUATE Technical Specifications (3.4.3.1 & 3.4.6.2).
US * Enters TS 3.4.3.2 Action B Eva luator Note: t-hour Tech Spec to close and de-energize the associated PORV Block Valve. Ensure action is addresse Lead Examiner may cue next event when Technical Specifications are addresse Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 3 ( Event Description: VCT level transmitter 130 fails high Time I Position I Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 3 Ind icat ion s available: 1-AR-M6-C-A3, LS-62-129A1B VOLUME CONTROL TANK LEVEL HI-LOW 1-LT-62-130 Indication failing high Respo nd to alarm response proced ure Crew ( Note: If actual level is permitted to becom e low, charging pump gas intrusion could occ u Evaluator Note: Th ere are sev eral notes in the alarm response that do not apply to this failure. The notes listed are the ones that do apply. There are seve ral sections of procedur e step ONLY th e applicable step (step 3) is listed in this guid NOTE 2 High failure of 1-LT-62-129A will divert letdown flow with NO affect on Auto makeu NOTE 3 High failure of 1-LT-6 2-130A will divert letdown and prevent Auto makeup. 1-L1-62-129 will indicate actua l leve Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES*D*2 I Op Test No.: NRC Scenario # 4 Event # 3 ( Event Description : VCT level transmitter 130 fails high Time I Position I Aoolicant's Actions or Behavior IF 1-LT-62-129A or 130A failed high, THEN ENSURE [l -LCV-62-118] in VCT position USING [1-HS-62-118A] AND manually RO operate as required to maintain VCT leve Lead Examiner may cue the next event when LCV-62-118A is in the VCT position ( ( Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario>> 4 Event >> 4 Event Description: CCS Pump Trip. Manual start of backup required Time I Position I Applicant's Actions or Behavior Boot h Instructor: When directed, Initiate Event 4 Indicatio ns available: O-AR-M27-B-A, A1, CCS REAC BLDG SUPPLY HEADER FLOW LOW O-AR-M27-B-A, E4, ERCW/CCS PUMP MOTOR TRIP Tri p indicat ion on 1B-B CCS Pump (Red light off, Green and white lights off) Responds to alarm response procedure(s) Crew ( Enter AOP-M.03, Loss of Component Cooling Wate r US Determine section 2.1 applies (CCS Pump Trip or Failure) US CAUTION: The Containment Spray Pumps may experience bearing failure after 10 minutes of loss of CCS coolin NOTE 1: When the associated TRAIN of CCS is out of service the CCPs, SI Pumps, and RHR Pumps are INOPERABLE for ECCS purposes due to not being able to fulfill it's design function for sump recirculation. LCOs 3.5.2, 3.5.3, 3.6.2.1,3.7.3 should be evaluated and appropriately entered by the SR Appendix D NUREG 1021 Revision 9
I Append ix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 4 ( Event Description: CCS Pump Trip. Manual start of backup required Time I Position I Applicant's Actions or Behavior NOTE 2: When CCS is out of service to mechanical seal HXs ONLY, the affected CCPs, SI Pumps, and RHR Pumps have been evaluat ed to be OPERABLE and AVAILABL Thes e pumps can run indefinitely without CCS cooling wate r to mecha nical seal HXs ENSURE the following pump that is currently aligned to B Train RUNNING:
* CoS CCS Pump OR * 1B-B CCS Pump - BOP OR * 2B-B CCS Pump (
Determines that the CoS Pump is aligned to the B train header Go to Step 10 US IDENTIFY and LOCK OUT failed CCS Pum CAUTIONS:
* Loss of comp onent cooling water flow to the RCP motor, requires RCP be stopp ed within two (2) minute * Containment Spray Pumps may experience bearing failure during operation after 10 minutes of loss of CCS coolina .
Appendix D NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions For m ES-D-2 I Op Test No.: NRC Scenario # 4 Event # _4
. :....-____ Page 11 of 32 (
Event Description: CCS Pump Trip. Manual start of backup required Time I Position I Aoolicanfs Actions or Behavior NOTE 1: When the associated TRAIN of CCS is out of service the CCPs, SI Pumps, and RHR Pumps are INOPERABLE for ECCS purposes due to not being able to fulfill it's des ign function for sump recirculation. LCOs 3.5.2, 3.5.3, 3.6.2.1,3.7.3 should be evaluated and appropriately entere d by the SR NOTE 2: Wh en CCS is out of service to mechanical seal HXs ONLY, the affected CCPs, SI Pumps, and RHR Pumps have been evaluated to be OPERABLE and AVAILAB L These pumps can run indefinitely without CCS cooling water to mechanical seal HXs ( ENSURE affect ed Unit's standby CCS Pump (aligned to T rain A) RUNNIN BOP
* Must manuall v sta rt CCS Pump 1A-A CHECK Train A CCS Heat Exchanger inlet pressure NORMAL for present plant condition [1-PI-70-24A, 1A1/1A2 CCS HXj [2-PI-70-17A, 2A1/2A2 CCS HXl BOP * Between 87 psig and 110 psig Determines pres sure aoorcxlrnatelv 105 ps ia Go to Procedure and step in effect ( US Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 4 ( Event Description: CCS Pump Trip. Manual start of backup required Time I Position I Annlicant's Actions or Behavior Evaluator note: Depending on the time it takes to start 1A-A ees Pump, letdown may divert on high temperature. The step below is an RO action that will be taken per the alarm response and SO-62-1, Step 5.2 (12) If letdown diverts to VCT on high temperature, place handswitch 1-62-79Ain the DEMIN position when ces is RO restored When directed to go to appropriate plant procedure, Lead Examiner may cue the next event ( (, Appendix D NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D -2 I Op Test No.: NRC Scenario # 4 Event # 5 ('. Event Description: TBHX Supply Line break Time I Position I Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 5 Indications available: O-AR-M27-B-A, B1, RC PUMPS THRM BARRIER RETURN HEADER FLOW LOW O-AR-M27-B-A, B2 - B5, RC PUMP 1 (2), (3), (4), THRM BARRIER OUTLET FLOW LOW Flow indication below normal on 1-FI-70-81A (M27) Subsequent alarms on:
* O-AR-M27-B-D2, Unit 2 CCS SURGE TANK AUTO MAKEUP * 1-AR-M5-A-C5, REACTOR BLDG AUX FL & EO DRAIN SUMP HI -
( Crew Refer to alarm response proc edures Evaluator Note: Crew may start a second Thermal Barrier Booster Pump per the ARP; Go to AOP-M.03, Loss of Compon ent Cooling Water US Determine Section 2.3 applies US CAUTION: During operation, the Containment Spray Pumps may experience bearing failure after 10 minutes of a loss of CCS coolin Appendix 0 NUREG 1021 Revision 9
I Append ix D Reguired Operator Actions Form ES-D-2 I c Op Test No.: Event Description: NRC Scenario # 4 TBHX Supply Line break Event # 5 Time I Position I Aoolicant's Actions or Behavior NOTE 1: When the associated TRAIN of CCS is out of service the CCPs, SI Pumps, and RHR Pump s are INO PERABLE for ECCS purposes due to not being able to fulfill it's design function for sump recirculation. LCOs 3.5.2, 3.5.3, 3.6.2.1, 3.7.3 should be evaluated and app ropriately entered by the SR NOTE 2: When CCS is out of service to mechanical seal HXs ONLY, the affected CCPs, SI Pumps, and RHR Pumps have been evaluated to be OPERAB LE and AVAILABL These pumps can run indefinitely without CCS cooling water to mechanical seal HXs ( '. MONITOR REACTOR COOLANT PUMPS MOTOR THRUST BEARING TEMP HIGH annunciator DARK [M-5B, E-3]. BOP DISPATCH operators with radios to Aux Bldg to locate failure and perform valve manipulation US/BOP DISPATCH an ope rator with radio to perform Appendix A, Operation of Appendix R Valves Required by Section US/BOP ENSURE all affected Unit's CCS Pumps RUNNIN BOP ( Appendix D NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 4 Event # 5 ( Event Description: TBHX Supply Line break Time I Position I Aoolicant's Actions or Behavior CHECK ERCW flows NORMAL fo r present plant conditions:
* 1-FI-67-61, 1A Supply Header BOP * 1-FI-67-62, 1B Supply Header * 2-FI-67-61, 2A Supply Header * 2-FI-67-62, 2B Supply Header NOTE:
In the event of a "A" train line break, the surge tank baff le prevents the "B" train from draining to less than 57% indicated leve MONITOR Train A CCS surge tank level between 65% and 85%. ( BOP * 1(2)-L1 -70-63A, Unit 1(2) A CCS Surge Tank Leve ENSURE surge tank auto makeup starts at 64% leve BOP MON ITO R Train A surge tank level greater than 0%. BOP NOTE: A high flow indication on FI*70*142 may indicate a line break on the Rx Bldg Supply/ Return Header. A line break in other areas of the CCS system may rob flow to the Rx Bldg Supply header resulting in inadequate flow to the RCP oil coolers.
( Appendi x 0 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I NRC Scenario 4 Event # ( Op Test No.: # 5 Event Description: TBH X Supply Line break Time I Position I Aoolicant's Actions or Behavior MONITOR Rx Bldg Supply Hdr flow NORMAL [1,2-FI-70- 142] . BO P * Between 800 gpm an d 1100 gpm without Excess Letdow n
* Between 900 c orn a nd 1300 oom with Excess Letdown NOTE :
W ith RCP oil coolers iso lated , Rx Bldg Supply Hdr flow [1,2- FI-70 -142], being at some value above zero and approximately equal to Thermal Barrier Return Flow
[1,2-FI-70-81] would indicate that the failure is within the boundary of the isolated oil coolers . -
MONITOR Th ermal Bar rier Return Flow NORM AL
[1,2-FI-70-81] (160 - 200 gpm) .
BO P Flow Indicates acero xlmatelv 135 GPM IF ind ications of abnormal flow exist OR CCS to Th ermal Barrier Heat Exchangers has isolated, THEN PER FO RM the following for the affected Unit: a. STOP and LOCK OUT affected Unit's Thermal Barrier Booster Pump b. ENSURE the following valves are CLOSED for the affected unit:
* 1(2)*FCV-70-90, Thermal Barrier Return Containment BOP Isol * 1(2)*FCV*70-87, RCP Thermal Barrier Containment Isol * 1(2)-FCV-70-133, RCP Thermal Barrier Supply Isolation * 1(2)*FCV-70-134, RCP Thermal Barrier Supply Isolation * 1(2)-70-516, Rx Bldg Supply [Unit 1, 714' el. CCS HX Mezzanine, 7 It from N.W. corner of elevator, 3 It above mezzanine] [Unit 2, 714' el. CCS HX Mezzanine, 20 It N.E. of stairs, 7 ft above mezzanine]
Appendix D NUR EG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 5 of 32 ('- Event Description: TBHX Supply Line break Time I Position I Aoolicant's Action s or Behavior CAUTION: Isolation of the Mise Equipment Header will also isolate the Rx Bldg Supply Heade NOTE: A high flow indication on FI-70-164A may indicate a line break on the Mise Equipment Header. A line break on the Mise Equipment Header may rob flow to the Rx Bldg Supply header resulting in inadeq uate flow to the RCP oil cooler MONITOR Misc Equipment Hdr Supply Flow [FI-70-164A]:
- * Between 350 gpm and 800 gpm NORMAL ALIGNMENT * Between 800 gpm and 1700 gpm with 1(2)-TCV-70-( 192, Letdown HX Temperature Control OPEN Evaluator note:
Remainder of procedure may be performed by the BOP as 'Reader-Doer' because the crew may have identified that the leak has been isolated EVALUATE need for isolating equipment USING Appendix F, Misc Equipment & Rx Bldg Equipment Lis BOP CAUTION: SFP Cooling Pump operation above 180"F may exceed system piping thermal design limitations.
( Appendix D NUREG 1021 Revision 9
I Appendi x 0 Required Operator Actions Form ES-D -2 I Op Test No.: NRC Scenario # 4 Event # 5 Event Description: TBHX Supply Line break Time I Position I Applicant's Actions or Behavior NOTE: W ith SFP Heat Exchangers isolated and a maximum heat load in the SFP, a heatup rate of 15°F/h r could be experience CHECK SFP Heat Exchang er A & B CCS Header INTAC T:
* Flows NORMAL for present heat load (3300 gpm maximum):
BOP * 0-FI-70-20, SFP HX A OR
* 0-FI-70-6, SFP HX B -
CHECK A Train CS Pump Mech Seal Outlet Header INTACT: (
* Flow NORMAL [FI-70-150]:
BOP 0 Between 5.3 gpm and 12 gpm (Unit 1) 0 Between 6 gpm and 12 gpm (Unit 2) CHECK ECCS Pump mechanical seals INTACT:
* A Train CCP Mech Seal Outlet Flow NORMAL [FI-70-146] (between 5 gpm and 9 gpm) * A Train SI Pump Mech Seal Outlet Flow NORMAL [FI-BOP 70-147] (between 5 gpm and 9 gpm) * A Train RHR Pump Mech Seal Outlet Flow NORMAL [FI-70-151] (betwee n 5 gpm and 20 gpm)
CHECK A Train RHR Heat Exchanger CCS Header INTACT: BOP * 1(2)-FI-70-159, Supply Flow NORMAL
* 1(2)-FI-70-158, Outlet Flow NORMAL Appendix 0 NUREG 1021 Revision 9
I Appe ndix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 5 ( of 32 Event Description: TBHX Suppiy Line break Time I Position I Aoolicant's Actions or Behavior CHECK A Train CCS Heat Exchanger Inlet Pressure between 90 psig and 110 psig: BOP * 1-PI-70-24A, 1A1/1A2 CCS HX
* 2-PI-70-17A, 2A1/2A2 CCS HX ENSURE all breakers are reopened USING Appendix A, Operation of Appendix R Valves Required by Section BOP -
STOP any unnecessary CCS Pumps.
( BOP CH ECK Train A CCS header pressure between 90 psig and 110 psig: BOP * 1-PI-70-24A, 1A1/1 A2 CCS HX
* 2-PI -70-17A, 2A1/2A2 CCS HX CAUTION :
A LOCA on a Unit makes that Unit unavai lable for SFP Coolin CHECK SFP Cooling CCS Supply/ Return Header INTAC BOP Appendix D NUREG 1021 Revision 9
I Appendix D Reguired Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 5 ( Event Description: TBHX Supply Line break Time I Position I Aonlicant's Actions or Behavior ALIGN SFP Cooling to the unaffected Unit USING 1(2)-SO-70-1, Component Cooling Water System "A" Train . BOP CHECK Misc Equipment Header INTAC BOP CHECK the following:
* A Train failed AND - BOP * Misc Equipment Header loads desired ( Determines that A train has not failed US/BOP Go to appropriate plant procedure When the leak has been isolated, Lead Examiner may cue the next event (
Appendi x D NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 6 Page 21 of 32 ( Event Description: Diesei Generator Inoperability Time I Position I Aooiicant's Actions or Behavior Booth Instructor: When directed, call in report of Sl Pump oil problem Receives report; Refers to Technical Specifications section SRO and 3. Determines T.S. 3.0.3 applie SRO When Technical Specifications have been addressed, the Lead Examiner may cue the next event.
( c, Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7,8.9,10 ( Event Description: SBLOCA, Loss of off-site power, EDG failure, lA*A CCP,l A-A CCS Pp start failure Time I Position I Applicant's Actions or Behavior Booth Instructor: When directed, initiate Event 7 Indications avai lable: RCS pressure decreasing ra pidly Con ta inment parameters increasing rapidly Reactor Tri p Safety Injecti on Direct entry to E-O, Reactor Trip or Safety Injection US ( Note 1 Steps 1 through 4 are immediate action steps Note 2 This procedure has a foldout page VERIFY reactor TRIPPED:
* Reactor trip breakers OPEN * Reactor trip bypass breakers DISCONNECT ED or OPEN RO * Neutron flux DROPPING * Rod bottom lights LIT (No, if LOOP has occurred) * Rod position indicators less than or equal to 12 steps, BOP VERI FY turbine TRIPPED:
Appendix D NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES*D*2 I Op Test No.: NRC Scenario # 4 Event # 7.8.9.10 ( Event Description: SBLOCA, Loss of off-site power, EDG failure, lA-A CCP,l A*A CCS Pp start failure Time I Position I Aoolicant's Actions or Behavior
* Turbine stop valves CLOSE CRITICAL VERIFY at least one train of shutdown boards ENERGIZE TASK * Attempt t o rest ore po we r to at least ONE train of shutd own boards BOP * Place DG 1A*A co nt ro l switch in START * Verify Train A Sh utdo wn Boards ENERGIZED DETERMINE if SI actuated : -
RO
* ECCS pumps RUNNING.
( * Any 81 alarm LIT [M-4D] (SI will be actuated) PERFO RM ES-0.5, Equipment Verifications WHILE continuing in this procedur (Actions for ES-0.5 are contained in attachment at back of BOP scenario guide) Critical Task to start 1A*A CCP is contained in ES* actions DETERMINE if secondary heat sink available: a. CHECK total AFW flow greater than 440 gp b. CHECK narrow range level greater tha n 10% [25 ADVj in at least one S/G . RO c. CONT ROL feed flow to maintain narrow range level between 10% [25% ADVj and 50% in all S/Gs.
(, (Heat Sink is available from Train A and TDAFW ) Appendix 0 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7,8,9 ,10 ( Event Description: SBLOCA, Loss of olf-site power, EDG failure, l A-A CCP,lA-A CCS Pp start failure Time I Position I Applicant's Actions or Behavior CHEC K if main steam lines should be isolated : a, CHEC K if any of the following conditions have occurred:
* Any S/G pressure less than 600 psig AND STEA MLINE PRESS ISOL Sl BLOCK RATE ISOL ENABL E permissive DARK [M-4A, A4]
OR
* Any S/G pressure dropp ing RO UNCONT ROLLE OR - * Phase B actuation ( b. ENSURE MSIVs and MSIV bypass valves CLO SE (Main Steam lines will isolate on Phase B)
NOT E: Loss of seal injection flow could advers ely affect RCP seal CHEC K RCP trip criteria: a. CHECK the following:
* RCS pressu re less than 1250 psi AND RO * At least one CCP OR SI pump RUNNING b. STOP RCPs (RCPs will be off due to loss of Oft-Site Power)
(, Appendix D NUREG 1021 Revision 9
I App endix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7,8 ,9,10 ( Event Description: SBLOCA, Loss of oft-site power, EDG failure, l A-A CCP,lA*A CCS Pp start failure Time I Position I Aoolicant's Actions or Behavior MONITOR RCS temperatures:
* IF any RCP running ,
THEN CHEC K T-avg stable at or trending between 547 degrees F and 552 degrees RO OR
* IF RCPs stopped, THE N CHECK T-cold stable or trending to between 547 degrees F and 552 degrees ( CHEC K pressurizer PORVs , safeties, and spray valves :
a. Pressurizer PORVs CLOSE b. Pressurizer safety valves CLOSED . RO c. Normal spray valves CLOSE d. Power to at least one block valve AVAILABL e. At least one block valve OPE CHEC K S/G secondary pressure boundaries INTACT: RO
* All S/G pressures CONTROLLED or RISING * All S/G pressures greater than 140 psi CHECK S/G tubes INTACT :
( RO a. CHECK all S/G narrow range levels CONTROLLED or DROPPING . Appendix D NUREG 1021 Revision 9
I Append ix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenarto # 4 Event # 7 ,8 .9.10 ( Event Description: SBLOCA. Loss of off-site power, EDG failure, lA-A CCP.1A-A CCS Pp start failure Time I Position I Aoolicant's Acfions or Behavior b. CHECK following rad monitors. including available trends prior to isolation :
* Main steam line NORMA * Condenser exha ust recorder RR-90-119 NORMA * S /G blowdown recorder RR-90-120 NORMA Post-Accident Main Steam Line Radiation recorder RR-90-268B. points 3 (blue) . 4 (violet).
5 (black) and 6 (brown) NORMAL. [M-31 (back of M-30)
-
CHECK if RCS is INTACT : ( * Containment pressure NORMAL
* Containment sump level NORMAL * TS -30-31 LOWER COMPT TEMP HIGH alarm DARK [M-5C. B1]
RO * Upper containment high range rad monitors RM-90-271 and RM-90-272 NORMAL [M-30]
* Lower containment high range rad monitors RM-90-273 and RM-90-274 NORMAL [M-30] * Containment rad recorders RR-90-112 and RR-90-1 06 NORMAL [M-12] (prior to isolation)
Monito r Status Trees Crew Go To E-1, Loss of Reactor or Secondary Coola nt ( Appendix D NUREG 1021 Revision 9
I Appendix D Reguir ed Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7,8,9,10 ( Event Description : SBLOCA, Loss of off-site power, EDG failure, 1A*A CCP,1A*A CCS Pp start failure Tim e I Position I Applicant's Actions or Behavior Determines Orange condition exists on Containment CSF Crew Status Trees Directs entry to FR-Z.1, Respons e to High Containment US Pressure NOTE If this procedure has been entered for an orange path and perform ance of ECA-1 .1 (Loss of RHR Sump Recirculat ion) is required, FR-Z.1 may be performed concurrently with ECA-1 . MONITOR RWST level greater than 27%. RO VERIFY Phase B valves CLOSED ,
* Panel 6K PHASE B GREEN RO * Panel 6L PHASE B GREEN ENSURE RCPs STOPPE RO Appendi x D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7,8.9 ,10 ( Event Description: SBLOCA , Loss of off-site power, EDG failure, lA-A CCP,l A-A CCS Pp start failure Time I Position I Applicant's Actions or Behavior DETERMINE if this procedure should be exited : a. CHECK for faulted S/G:
* Any S/G pressu re DROP PING in an uncontrolled manner OR * Any S/G pressure less than 140 psi b. CHECK containment pressure less than 12 psi RO c. CHECK at least one containment spray pump RUNNING and deliv ering flo d. CHECK at least one containment air return fan RUNNING e. RETURN to procedure and step in eHect.
( Directs entry to E-1, Loss of Reactor or Secondary Coolant US Scenario may be terminated upon t ran sition to E-1 Appendix D NUREG 1021 Revision 9
I Append ix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Sce nario # 4 Event # ES-Q.5 ( Event Description: Equipment Verifications Time I Position I Aoolicant's Actions or Behavior CHECK ERCW system operation: BO P * VERIFY at least four ERCW pumps RUNNIN * VERIFY DIG ERCW supply valves OPEN . VERI FY CCS pump s RUNNING: CRITICAL TASK
* Pump 1A-A (2A-A) Must Manually Start BOP * Pump 1B-B (2B-B) * Pump C- (
VER IFY EGTS fans RUNNIN BOP VERIFY generator breakers OPE BOP VERIFY AFW pumps RUNNING : BOP * MO AFW pumps
* TO AFW pump .
NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S/G levels, to establish flow due to failure, or to isolate a faulted S/G.
( Appendi x 0 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # ES-O S ( Event Description: Equipment Verifications Time I Position I Aoolicant's Actions or Behavior CHECK AFW valve alignment: a. VERIFY MD AFW LCVs in AUT b. VERIFY TD AFW LCVs OPEN . BO P c. VERIFY MD AFW pump recirculat ion valves FCV-S-400 and FCV-S-401 CLOSED . VERIFY MFW Isolation:
* MFW pumps TRIPP ED - * MFW regulating valv es CLOS ED BOP * MFW regulating bypass valve controller outputs ZERO * MFW isolation valves CLOS ED ( * MFW flow ZERO .
MONITOR ECCS operation: CRITIC AL TAS K VERI FY ECCS pumps RUNNING: BOP * CCPs - MANUALLY START 1A- A CCP
* RHR pumps * SI pumps VERIFY CCP flow through CCPI * CHECK RCS pressure less than 1500 psi BOP * VERIFY SI pump flo * CHECK RCS pressure less than SOO psi * VERIFY RHR pump flow . Appendix D NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # ES- of 32 ( Event Description: Equipment Verifications Time I Po sition I Applicant's Actions or Behavior VERIFY ESF systems ALIGNED:
* Phase A ACTUATED:
0 CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT [M-6C, B5]. 0 CONTAI NMENT ISOLATION PHAS E A TRAIN B alarm LIT [M-6C, B6].
* Containment Ventilation Isolation ACTUATED :
0 CONTAI NMENT VENT ILATION ISOLATION TRAIN A alarm LIT [M-6C, C5]. 0 CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C , C6].
- BOP * Status monitor panels:
0 6C DARK 0 6D DARK ( 0
6E LIT OUTSI DE outlined area 6H DARK 0 6J LI Train A status panel 6K: 0 CNT MT VENT GREEN 0 PHASE A GRE EN
* Train B status panel 6L:
0 CNTMT VENT GREEN 0 PHASE A GREEN MONITOR containment spray NOT required: 0 Phase B NOT ACTUATED AND BOP
* Containment pressure less than 2.81 psig * Ensure Conta inment Spray is actuated (
Appendix D NUREG 1021 Revision 9
I Appendix D Reguired Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # ES-O.5 ( Event Description: Equipment Verifications Time I Position I Applicant's Actions or Behavior VERIFY pocket sump pumps STOPPED : [M-1 5, upper left corner]
* HS-77-410, Rx Bldg Aux Floor and Equipment Drain BOP Sump pump A * HS-77-411, Rx Bldg Aux Floor and Equipment Drain Sump pump DISPATCH personnel to perform EA-0-1, Equipment Checks Following ESF Actuatio BOP (
( Appendix D NUREG 1021 Revision 9
. to SHIFT TURNOVER CHEC KLIS T Page 1 of 3 Today ( [8] SM [8] US/MeR Unit 1 o uo Unit 1 Off-going - Name o AUO Station SON [8] STA (STA Function) AUO Com p Actions On-coming - Name * Secon da ry equipmen t operating or ready fo r s ervice.
( AUXILIARY BUIL DING (7775) (593-5414)
* Aux. Bldg. equipment operating or operable and ready for servic * 1B-B CCS Pump in service for routine bearing vibration check Res Leaka ge (51-137.0) I T otal: 0.04 gp m; Id entified: 0.02 gpm; nidentified : 0.01 gpm (today)
(
"' _ " ' ,.0--- ' -
SHIFT TUR NOVE R CHECKLIST Page 2 of 3 Today ( Sirrest in Progress/Planned: (Including Need for New Brief) Q*SI*NUC*000*1.0, Estimated Critical Condition SI*SXX*06S*127.Q, Minimum Temp for Criticalit Major Activities/Pro cedures in Progress/Plann ed: Reactor startup in accordance with Q*GO*3 Section 5.2, step SO-213-1 Section 5.16.3 Step 6 Radiological Change s in Plant Duri ng Shift : Containment dose rate increase with Rx power increase. Contact Rad Con for all RWP detail I ,: '1";-
.: ... '.':\.';" :,',
,;';:::."" "
" .'. ' ":~~:1:~ ' * , ' ,';*;;);i} \*~ :~ >i::;~:::, . LCO/ODCMrrRM " , ACTIONS,.*..~.*.**.
** .~,..,.".':
' \ *"...."* :'"
..,.. c e, ..-, ,,,
~':;,"} ~ ., ..," ,,,, , .'" ., .-.... " ":" '>.:'.'"
. * ..".A"".": ,.>',..,,'.* '.',:-
;t:'~ ':':,';',-;'\1' f.::~ ', ,'.*' ,\ ,...-:....: " ,: ' : :<*i:", ;~;' ~"'~' .~ ~ t.':, :*r"" . ',
_, ' ..
~::
None ( Part 2 - Perf or med by on -c om in g shift 0 Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) 0 Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shilt Turnover: 0 Standing Orders 0 LCO(s) in Actions (NiA for AUOs) 0 Immediate Required Reading 0 TACF (NiA for AUO's) Part 3 * Perfo rmed b y both o ft-going and on-coming shift 0 Wa lkdown of MCR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40W (0)-20011 OPOP*I * ! (0)- 14.2001 (
-.-. _.~ . ...*.. .-_. . .
SHI FT TURNOVER CHECKLIST Page 3 of 3 Today ( Disabled Annun ciators PANEL WINDOW ANNUNCIATOR WO I PER Num ber Equo.pmen t Off .Norma I (P'on k Tags UNI D And Noun Name Panel Probl em Descriptio n W OI PER Number
-
( MCR WO LIST ID An d No un Name Pane l Probl em Descrip tion WOl PER Nu mbe r (
UNIT ONE REACTIVITY BRIEF ( Date: To day Time: Now RCS Boron: 1711 ppm Today I BA Controller Setpo int: 48 % * I RCS B-1 0 Depletion: 0 ppm Operable BAT : A I BAT A Boron: 6850 ppm I BAT C Boro n: 6850ppm I RWST Boron: 2601 ppm Nominal Gallons per rod step from_ _: N/A gallons of acid, N/A gallons of water
* Ve nfy boric acio flow contro ller IS set at Adjusted BA Controller Setting law 0-80-62-7 section Gallons of acid: N/A Gallons of water: NIA Rod Steps: Nt A
; i .:',:::.. ,.: '.' : ';>,':,L.:' ;:{:>:*\:~, :\ ~s!i m at.~ 9 rodsrooron..for emergency step.power reduction ~~. :;.,;...." .:'.::; \~~; ~ : ::.: . \,;t~;,~':>
* *(As~JJ m i rig; Xe nori:eq (i ilihri u.m. :a nd . n o reactivity ~ffects due to Xenon. 213 tota l reactivity trornrods, 1/3 from " ,
. ~: ' .::, ~.~ . :- :. ' ~" " ~: ';';'.:..::~~::- <::'~j"';/::(~'" -; :'~>-" .. ~: ".::: boron) .. >:~;--; . '.::' .:. ...;.,; . ....: .... ~' --i . :~ ~. ." ;.'. ~::< .'/<:
Po w er red uction amount Esti mated Final Rod Pos ition Est imat ed boron addit io n 10% NtA Steps on bank D Nt A gallo ns 30% --:. NtA Steps on bank D NtA gallons 50% NtA Steps on bank D Nt A gallons
** T hese values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-6 2-7 calculated values . The se values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ag Data Valid until three weeks from no [ :.~'- *:.:<;'f;f,; ,J ;";:';; \ :, ~.)~t.c*;{;~:t:'/>:ii~;.;'~k~'; ;::~* ',:,:,SPrev i 0 us 'S bi ft Reactivity Mal1ipulations
'. " .' . ',' .,;'J:;.:,-:.:' ':', .". ,. ., J ." .. ,
.' :", .... ,:"'" -. '.:,,':';','.:" .. . ...' .';c., ~)'. ;.' ":"
Number of dilu tions: 0 I Number of borations: Rod steps in: Gallons per dilution: 0 Gallons per boration : Rod steps out: Total amount diluted : 0 Total amount borated: Net change: IN/Out Number of dilutions: 0 Number of borations: Rod steps in: Gallons per dilution: 0 Gallons per boration: Rod steps out: Total expected dilution: 0 Total expected boration: Net change: In/Out Remarks: Rx Power - 0% MWO/MTU - 150 Xenon - Sama rium -971 pcm Next Unit 1 Flux Map is sched uled- 74% RTP Unit Supervisor: _ ( Name/Date
-~ -
Operations Chemistry Information ( r£tf.~~~i;~~~~:~\.D~\2;~~~:~&~f~(~£~j~:i:~{lf~i~;~~:'~~;~::~i~~~~~;;:~,~~~.~.l ts":f:~{il;~:~~:~~-~~';"~ .~ : . :"Sl~l;;~~i";;~:.:~~:." ,> /;~-~~:*.J(~~ik:<:~~£~~ Sample Point Uni ts Bor on Dat e /Time Goa l Lim it U 1 RCS ppm 1712 Tod ay / Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable U1 RWST ppm 2601 Today / Now 2550 - 2650 2500* 2700 U2 RWST ppm 2569 Today / Now 2550 - 2650 2500 * 2700 BAT A ppm 6850 Today / Now Variable Variable BAT B ppm 6850 Today / Now Variable Variable BAT C ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA #2 ppm 2575 Today / Now 2470*2 630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470*2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today / Now 2470*2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3
-- ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700 ( Spent Fuel Pool ppm 2547 Today / Now z 2050 ~ 2000
:1Z~?}ff~~i~g:r~:~:::,i£If~~~~1f~1i~Sh~~~~}£~:~t~3~Y~~~;-:::~Y:Jl3}~~<~ .';:," /:~:I'~i~~\~A~~X~':::" " , Goal : ~ :':\\' x* *
. ' -.' -i~; ' : ;-:::d.~S'l}::-);'-~\.:_: :
* . * '~*i,M
", <
i dpo!nt ':'~"ct~
:: :l ~:::.'.i?:.L;': :: :!:*.\
U1 RCS ppm Today / Now >1 >1 U2 RCS ppm 2.43 Today / Now 2.18-2.48 2.33
'5 ;;;,~' W,,;;;, ; .: <~\ .%:<t ~ritriill)l t o ~e co n d ~rY. Leakr":M ln lo rm at i qn (Tota).C P M R M~!lq:99/,1 19) " ;.:::..~ ~~ ~.. .., '~ \ ;;..o~;; "~-f~~. "";;":'-,~.IoN ~ *:_~ ~~""; * ';._' ;;':L:t::~~;. ;". ,.....:' "-.< ' . ; ",.J;~~-c'._';'::;:~-;.' '~ ;.* ...~:.~--" :u '"-4 JLC.-_ c..: . ~,;~-';;'~~';lli~:~:~~: S~~~~
Indi cat or Uni ts U1 Date /TIme U2 DatelTime SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137,5 eVE Leakrate gpd < Today / Now < Today / Now 5 gpd leak equivalent cpm 229 Today / Now 68 Today / Now 15 gpd (30 min increase) cpm 567 Today / Now 83 Today / Now 30 gpd leak equivalent cpm 1174 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today / Now 150 gpd leak equivalent cpm 5710 Today /Now 870 Today / Now eVE Air Inleakage clm 10 Today / Now 1 Today / Now Bkgd on 99/119 cl m 40 Today / Now 40 Today / Now (
--=- :~ l~-~----------------------------- SHIFT TURNOVER CHECKLIST Page 1 of 3 Today
", [8J SM [8J US/MCR Unit 1 [8J UO Unit 1 Off-going - Name o AUO Station SON [gJ STA (STA Function) AUO Como Actions On-co ming - Name Part 1 - Completed by Off -going ShifVReviewed by On-coming Shift:
Abnormal Equipment Lineup/Conditions: q
,.~~~, ,~':":~,,,;;,,:, . :~ :.:,> ~,.' ::.~.>;. MAii(9o.NTRO~J!QOMrz6.!J.Q) (~~$.-5~.(}~) '.. ::
~ * * t;; ...... ~...~:""1 ... a;~, > .-::' ~. ~*..!'-" ****** -::7 p~ ,-"I" '." ** : .. ,..l.!':::lr\~ . .* ..-., ., .. ,~ * f'f' . . ,
-: .
p -..IP
". _ ... '. ~l.'~> .~.,:'
Train B Week -
,~. '1'{ '?~"~":'~~. .;7'Y'-:-.' ,' . . -: ,:.::~"";:.'. . -; ..... -~:'.' - ... :- -", :",'7:. h.-.:~j,!*'" ('-.. --;. .--:.y :\: .. :: ..... ~ :",-:~"-~":! '-:..
.-~_"'" ',',".:, .":,'.- ~"'., ;'. ~:.:" _-.' TURBINE BWhPINGf1Z7.1J. (5f!3-54 19) : ,1 ' d *** *.-. >~~5~.**: :',;
* Secondary equipment operating or ready for servic Outside equipment operating or operable and ready for servic AUXILIARY BUILDING (7775) (593-5414)
* Aux. Bldg. equipment operating or operable and ready for servic * 1B-B CCS Pump in service for routine bearing vibration check Re s Leakage (SI-137.0) I T otal : 0.04 gp m; Identified : 0.02 gp m; Unide nt ified : 0.02 gp m (today)
.I J .. ... . _ . _ t _ I SHIFT TURNOVER CHECKLIST Page 2 of 3 Today (
SlfTest in Progress/Planned: (Including Need for New Brief) 0-SI-NUC-000-1.0, Estimated Critical Condition SI-SXX-068-127.0, Minimum Temp for Criticalit Major Activities/Procedures in Progress/Planned: Reactor startup in accordance with 0-GO-3 Section 5.2, step SO-2/3-1 Section 5.16.3 Step 6 Radiological Changes in Plant During Shift: Containment dose rate increase with Rx power increase. Contact Rad Con for all RWP detail ':;~:*';~~'.
.,:,<,..... *::< : '*'::.'<r":
,.. '\~*;
.':. ,';
*~". ~:. .:;;~;},; :"',~~.:: -:'~:C ~:.';:';>{* *' * *(c olb
~.,.;: - , .';.(:::'... .,~ .: -,,\.. . \,.,.':. , . . DCMfTRM . ... .. :'-ACTI
.' ' . 6 N..S'~.,.::irl'*..}.f'\.
/i.*\.;: ., ;":,r:'.':.~ 'y* ,* **~ ' F 'e .,J,'..-s:>' <t* 1
:J.*;" " " -" ., .* ~.
-
None ( Part 2 - Performed by on -co ming shift 0 Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's) 0 Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shill Turnover: 0 Standing Orders 0 LCO(s) in Actions (N/A for AUOs) 0 Immediate Required Reading 0 TACF (N/A for AUO's) Part 3 * Performed by both off-going and on-coming shift 0 Walkdown of MeR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40741 [03-200 I) O PDP- I-I [0 3- 14-2001
.. . v - - .*. ~ .... - ---
SHIFT TURNOVER CHECKLIST Page 3 of 3 Today ( Disabled Annunciators PANEL WINDOW ANNUNCIATOR WO I PER Number Equrprnen
. t Off *Norma I (P'In k T ags UNID And Noun Name Panel Problem Description WO I PER Number --
MCR WO LIST ID And Noun Name Panel Problem Description WOlPER Number
UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron: 1711 ppm Today I BA Controller Setpoint: 48 % * I RCS B-1 0 Depletion: 0 ppm Opera ble BAT: A I BAT A Boron: 6850ppm I BAT C Boron: 6850ppm I RWST Boron: 2601 ppm Nominal Gallons 'per rod step from_ _: N/ A gallons of acid, N/A gallons of water
... Venfy boric acid flow controller IS set at Adjusted BA Controller Setting law 0-SO-62-7 section Gallons of acid: N/A Gallons of water: NIA Rod Steps: N/A .~.: ; ',;;/':~ :" :...';~' .>,~ . :'~~ .: :" .'..:Est imated "r,cids/b o ron fo"r.emergen*cy step 'power .reduction ,,"*:r .~:' :,. : '.:.:.',':/ * . ~ .' ...... ~
0- * . " ..
..",:,
. * '" . -;.'
'.": " ' -:-:-' r:~~
- . .:
;; ......
-
.#~ * * * *
* .
' -: , . : .,. _ :.
*
, _,,:~,~>; ... .. . ; *** *
*
. ..
*
. .. ... . . _
,.
. ", ' 0 ;'
*
_ ;
- --
, "'. ' .'" . ~ ..
* *
". ,.. '
.
"C "" .~
' - -- - _ ** '
':'.; ;,,',"~" ~':'.- \ .;, .:*
. . -.., .... ,:. .. . ",.:._
*
** .- ' *. r__""' ~*-
'*.:~:JAss u m i Jig'Xe.noh~.eq ~ i! i b ri um ~ n d . no. reactivity ettects due to'>;el)()h.:213 tot~.Ire~ctivity ltom rqO.~, ) £.3 ,~r9m ~/:.
.
ff;~;~;"*'~r~;~ .:.~\~' ~; .;~\,~:~~ :*~~*~~> ::'*~:*: :~: . . :~.:;:~~t:;~~<~.~_~;:.~~~~,,: : ':* ':)~.~ ;:" .. >>, '.~, ~~:'. 7.. "'~~ .boron) -": ~' * .*:.;i;~/r(,:;.~: .::~. , -: ~" .:';~:,.~':~~ : ' ,: .;:~:.:": '::",t.!.:.\*, ~~': :~' (~.. t,~": }~r:: **.~;'t~: .:';-*~:*:~~~::.~~~r~*: ;. Power reduction amount Estimated Final Rod Position Estimated boron addition 10% N/A Steps on bank D N/A gallons 30% N/A Steps on bank 0 N/A gallons
-
50% N/A Steps on bank D N/A gallons
** These values are approximat ions and not intended nor expecte d to be exact. Th e values may be superceded by Rx Engineering or 5 0-62-7 calculated values. These values are calculated assumin g 100% steady stale powe r operation only. Engineering data last updated one week ago .
Data Valid until three wee ks from no [:i~*:~;i:~~;~~>::'~~;. ~~S~;'~}~J~. :;:t~ ~;;~ ':>:j~>f:;:~'; Previ ous Sl}ift*fleacti \ii.tY Manlpulatlons :~::.*:;<r~t:~<*:)**.[/~'i~*::'::1,;t;~;;,:5~ * 1
;
.~ .
Number of dilutions: 0 Number of borations: Rod steps in: Gallons per dilution: 0 Gallons per boration: Rod steps out: Total amount diluted: 0 Total amount borated: Net change: IN/Out Number of dilutio ns: 0 Number of borations: Rod steps in: Gallons per dilution: 0 Gallons per boration: Rod steps out: Total expected dilution: 0 Total expected boration: Net change: In/Out Remar ks: Rx Power - 0% MWD/MTU -150 Xenon - Samarium -971 pcm Next Unit 1 Flux Map is scheduled- 74% RTP Unit Supervisor: _ ( Name/Date
....._.....:. ... ... . _***1_ *
Operations Chemistry Information ( Boron Limit ppm 1712 Today / Now Variable Variable ppm 816 Today / Now Variable Variable ppm 2601 Today / Now 2550 - 2650 2500 - 2700 ppm 2569 Today / Now 2550*2650 2500 - 2700 ppm 6850 Today / Now Variable Variable ppm 6850 Toda y 1 Now Variable Variable ppm 6850 Today 1 Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400 -2700 U1 CLA #2 ppm 2575 Today 1 Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today 1 Now 2470-2630 2400- 2700 U1 CLA #4 ppm 2589 Today 1 Now 2470-2630 2400-270 0 U2 CLA #1 ppm 2531 Tod ay 1 Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today 1 Now 2470-2630 2400-2700 U2 CLA #3
-- ppm 2522 Today 1 Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today 1 Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Tod ay / Now > 2050 2: 2000 2.18-2.48 2.33 SI 50 S/G Leakage? Yes/No No Today 1 Now No Today 1 Now Sl 137.5 eVE Leakrate gpd < Today 1 Now < Today 1 Now 5 gpd leak equivalent cpm 229 Today 1 Now 68 Today 1 Now 15 gpd (30 min increase) epm 567 Today 1 Now 83 Today 1 Now 30 gpd leak equivalent epm 1174 Today 1 Now 206 Today 1 Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today 1 Now 150 gpd leak equivalent epm 5710 Today 1 Now 870 Today 1 Now e VE Air Inleakage efm 10 Today 1 Now 1 Toda y 1 Now Bkgd on 99/119 cfm 40 Today 1 Now 40 Tod ay 1 Now (
- -til f r SHIFT TUR NOVER CHECKLIST Page 1 of 3 Today o SM o US/ Me R Unit (8) uo Unit a ll- going - Name o AUO Station SON o STA (STA Function) AUO Camp Actions On-coming - Name
* Secondary equipmen t operating or ready for servic AUXILIARY BUILDING (7775) (593-5414) * Aux. Bldg. equipment operating or operable and ready for servic * 1B-B CCS Pump in service for routine bearing vibration check Re s Leakage (5 1-137.0) I Total : 0. 04 gp m; Id entifi ed : 0.0 2 gp m; nldentificd: 0.02 gp m (to day)
'- " , ** ~ - * - - r - J-SHIFT TUR NOVER CHECKLIST Page 2 of 3 Today (
Sirrest in Progress/Planned: (Including Need f or New Brief) 0-SI -NUC-000 -1 .0, Estimated Critical Cond itions . O-SI-SXX-068-127 .0, Mini mum Temp for Criticali t Major Activities/Procedures in Progress/Planned : Reactor startup in acc orda nce with O-GO-3 Section 5.2, step O-SO-2/3 -1 Section 5.16.3 Step 6 Radiolog ical Changes in Plant During Shift: Containment dose rate increase with Rx powe r increase . Contact Rad Con for all RW P detail I " , ' .r, c",,;;'.::* :,' ,i'::;::. ~,,; < '*)'~* c::;:':L: LCO/ODCMr:rRM *ACr I O N S*:'W:;\,~',:;rt!:,"'~0*iv:;j ; ;':;'):.ti,;l/£:{;;: ci'. '. ; ....
-
None Part 2 - Perf orm ed by on-c o mi n g shift 0 Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (NIA for AUO's) 0 Review of Rounds SheetslAbnormal Readings (AUa 's only) Review the Following Programs for Changes Since Last Shift Turnover: 0 Sfand ing Orders 0 LCO(s) in Actions (N/A lor AUOs) 0 Immediate Required Reading 0 TACF (NIA for AUO's) Part 3 * Perf orm ed by both off-going and on-c om ing shift 0 Walkdown of MCR Control Boards (N/A for AUO's) Relief Tim Relief Dat today TVA 4074 1 [0) *20011 OPD P*l - l {O)-14-200 1 (
- , ,--- ---,...--_._.* _.-
SHIFT TUR NOVER CHECKLIST Page 3 of 3 Today ( Disabled Annunciators PANEL WINDOW ANNUNCIATOR WO I PER Number Equlprnent
. Off*Normal (Pink Taqs)
UNID And Noun Name Panel Pro blem Descr iption WOl PER Number
-
MCRWO LIST ID An d Noun Name Panel Probl em Descripti on WOl PER Number (
"f UNIT ONE REACTIVITY BRIEF ( Date: Today Time: Now RCS Boron : 1711 ppm Today I BA Con troller Setpoint: 48 % * I RCS B-10 Depletion : 0 ppm Operable BAT: A I BAT A Boron: 6850 ppm I BAT C Boron: 6850ppm I RWST Boron: 2601 ppm Nom inal Gallons per rod step from_ _ : N/A gallons of acid, N/A gallons of water
* Venfy bonc acid flow controller IS set at Adjusted BA Controller Setting law 0-SO-62-7 section Gallons of acid : N/A Gallons of water: NIA Rod Steps: N/ A
" ': ~>:.:~:)J***: ::".r\*(:',:~\~~:~:: :. :'* *: }~s~i.i:!'a~~p, ro~ s/bo ro n .f.o r emergency ~.t,ep. power reduction *.~,:::::;) .~ , , ;\:\ i~; :.~::,~r::: :* :1*:~>/~,
': (AssUmiri'g"Xenon :equilib'riunf andn o reactivityettscts due toxenon. 2/3 total reactivit{from rods}' 113 fro rr(,~:.
':~ ;~. " ?~~' :i:' :: . : ~:. ~~~~T:1:g<:.X~-\~~::,:-",~: *:::-ii; .' -.; boron) ' <.:-;~; . '". '.. ." -.': .. .. ' .: . :.':'. ':.~ " '.' -;~ ::: * *S<-:';': - ::')~ ;~;;'\
Pow er red uc tion amou nt Estimated Final Rod Pos itio n Esti mated bo ron addition 10% N/A Steps on bank 0 N/A gallons 30% - N/A Steps on bank 0 N/A gallons
-
50% N/A Steps on bank 0 N/A gallons
** The se values are appro xima tions and not intended no r expected \0 be exact. The values may be superceded by Rx Engineering or SO-62-7 calculated values. Thes e values are calcula ted assuming 100% s eady state po.....er operation only. Engineering data last updated one week ag Data Vali d until three weeks from no I'Y:'::>F;;!:?~p;~;:;{ [;;.,; ,~~l:i;::';l/~';\,.:~.~~\:;~:~:J;;;-.~:,,!~,;;,~~,?~ rev i0 US .Shi ft Reactivity ~~nip*~1.ation5 ';
. j" J' . ;-'
.: .,<",.:'. )-." y,,~,:, '.r
. .*. :* ..:.:'; .;:: :--.. . :. ..." " j / ; .;-: \ .:(
*;*:': " \
:.;:.!,:,:
" .' ,: ~.~'...
Number of dilutions : 0 Number o f borations: Rod steps in: Gallons per dilution: 0 Gallons per boration: Rod steps out: Total amount diluted : 0 Total amo unt borated: Net change: IN/Out Number of dilutions : 0 Number of borations: Rod steps in: Gallons per diluti on: 0 Gallons per boration : Rod steps out: Total expected dilution : 0 To tal expected boration: Net change: In/Out Remarks: Rx Power - 0% MVV D/MTU - 150 Xenon - Samar ium -971 pcm Next Unit 1 Flux Map is scheduled- 74% RTP Unit Supervisor: Name/Dale
Operations Chemistry Information ( Sample Point Units Boron Date ITime U1 RCS ppm 1712 To day I Now Variable Variable U2 RCS ppm 816 Today I Now Variable Variable U1 RWST ppm 2601 Today I Now 2550 - 2650 2500 - 2700 U2 RWST ppm 2569 Tod ay / Now 2550 - 2650 2500 - 2700 BAT A ppm 6850 Today / Now Variable Variable BAT B ppm 6850 Today I Now Variable Variable BATC ppm 6850 Today / Now Variable Variable U1 CLA #1 ppm 2556 Today I Now 2470-2630 2400- 2700 U1 CLA #2 ppm 2575 Today / Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 253 1 Today / Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700
--
U2 CLA #3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400- 2700 Spent Fuel Pool ppm 2547 Today / Now ~2050 ~2000 U1 RCS 1~J.:r.S~~.~i~~:W:~~:j~~'~~S:;itt(t';iX~~*:': ppm Today / Now >1
..
*; ;:t!G~mr:';j)<* : .'" '.:; ;.;~.~~'~l::~t~i~t~; : * .< ~v~Egm~/;:;'0;\
>1 U2 RCS ppm 2.43 Today / Now 2.1 8-2.48 2.33 g§~x5~~j \~:~~~:&q~~lm~~~J¥;!~;~*~~P.11~,~r.t.:,;;~>;~~l:~?;A2~.?.~ ~~t!.o~. J.!g~E~lfPM:. R ~~,2 2]:9t.1~~,~) .*..*;:,:';-i~:*~~i%?':~.i:.l:~*~:\i*L Indicator Units U1 Date I Time U2 Date/Tirne SI 50 S/G Leakag e? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < Tod ay / Now < Tod ay / Now 5 gpd leak equivalent cpm 229 Today / Now 68 Today / Now 15 gpd (30 min increase) cpm 567 Today / Now 83 Today / Now 30 gpd leak equival ent cpm 1174 Today / Now 206 Today / Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today / Now 150 gpd leak equival ent cpm 5710 Toda y / Now 870 Today / Now CVE Air Inleakage cfm 10 Today / Now 1 Today / Now Bkgd on 99/119 cfm 40 Today / Now 40 Today / Now
( TENNESSEE VALLEY AUTHORITY ( SEQUOYAH NUCLEAR PLANT SYSTEM OPERATING INSTRUCTION 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Revis ion 46 NON-QUALITY RELATED PR EPA RED BY:. Pat Barbree
-----'--'=-''''-- _
RESPONSIBLE ORGANIZATION: _ _--='-='-"--"-'='-'=- OPERATIONS _ APPROVED BY:_=-- W. T . Leary
-'-'-'---'-'--'=-'-'--- _
( EFFECTI VE DATE: 12/06/2006 LEVEL OF USE: CONTINUOUS USE REVISION DESCRIPTION : Revised to add a precaution and limitation and a note in section 5.1 .1 for hotweillevel instruments reading differently in the three condensers in accordance with CA 103395-0 SECTION 8.815 DESIGNATED AS A CIPTE. INTENT CHANGES TO THIS SECTION REQUIRE PORC APPROVA /3-1 saN CO NDE NSATE AND FEEDWATER SYSTEM ( 1 Rev 46 Pag e 2 of 267 TABLE OF CONTENTS Page 1 of 4 Section Title Page INTRODUCTION 6 Purpose.................................................................................................................. 6 Scope ..................................................................................................................... 6 REFERENCES....................................................................................................... 6 Performance References 6 Developmental References.................... 7 PRECAUTIONS AND LIMITATIONS...................................................................... 8 Main Feedwater Pumps 8 Condensate Pumps.............. 10 PREREQUISITE ACTIONS 13 STARTUP/STANDBY READINESS 14 ( Deaeration of the CSTs.......................................................................................... 14 5. Hotwell Pump Recirculation 14 Placing Hotwell Pumps in Service 20 5. Placing First HWP In Service 20 5. Placing Additional Hotwell Pump(s) in Service....................................................... 24 Placing Condensate Booster Pumps in Service 26 Placing Cond Demin Booster Pumps in Service 33 Placing High Pressure Injection Water System In Service 35 Filling and Deaeration of the Short-Short Cycle 37 Filling and Deaeration of the Short Cycle ............................................................... 43 Filling and Deaeration of the Long Cycle 48 Changing from Long Cycle Deaeration to Normal Valve Alignment for Filling S/Gs With Feedwater 59 5.10 Main Feedwater Pump(s) Oil Pump Test................................................................ 65 5.1 A MFP Oil Pump Tesl.. ......................................................................................... 65 5.1 B MFP Oil Pump Tesl.. ......................................................................................... 71 (,
1-80-2/3- 1 SON CONDENSATE AND FEE DWATER SYSTEM Rev 46 ( 1 Page 3 of 267 TABLE OF CONTENTS Page 2 of 4 Section Title Page 5.11 Main Feedwater Pump(s) Warm-up . 77 5.1 A MFP Warm-up . 77 5.1 B MFP Warm-up . 80 5.1 2 Main Feedwater Pump(s) Turbine Turning Gear . 83 5.1 Placing 1A MFPT on Turning Gear . 83 5.1 Placing 1B MFPT on Turning Gear . 85 5.13 Main Feedwater Pump Turbine - Establishing Vacuum . 87 5.1 A MFPT- Establishing Vacuum . 87 5.1 B MFPT - Establishing Vacuum . 90 5.14 Main Feedwafer Pump Trip Test(s) Prior to Startup . 93 5.1 A MFP Trip Test Prior to Startup . 93 ( 5.1 B MFP Trip Test Prior to Startup . 97 5.1 5 MFPT Steam Supply Warm-up 101 5.1 A MFPT Steam Supply Warm-up ......................................... 101 5.1 B MFPT Steam Supply Warm-up 102 5.1 6 Main Feedwater Pump Startup........... 103 5.1 Preparation of 1A MFP for Startup ......................................................................... 103 5.1 Preparation of 1B MFP for Startup ......................................................................... 106 5.1 Startup of First MFPT 109 5.1 Startup of Second MFPT........................................................................................ 117 5.17 MFP Filling and Venting During Long Cycle Operation 124 5.1 8 Condensate Pumps Motor/Area Cooler Operation........................................................ 125 NORMAL OPERATION..... ..................................................................................... 128 SHUTDOWN 129 Shutdown of Hotwell Pumps 129 Shutdown of Condensate Booster Pumps 130 Shutdown of Cond Demin Booster Pumps .. 133 ( Shutdown of High Pressure Injection Water Pumps .. 136
1-S0 -2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 4 of 267 TABLE OF CONTENTS Page 3 of 4 Section Title Page Shutdown of Main Feedwater Pumps .. 137 7. Shutdown of 1A MFP 137 7. Shutdown of 1B MFP 144 INFREQUENT OPERATION 151 Transferring Duplex Filters 151 8. Bearing Oil (LIP) Duplex Filter (Manual Balancing Valve) 151 8. High Pressure Oil (HIP) Duplex Filter (Automatic Pressure Equalization Valve) .... 154 Swapping Main Feedwater Pump Turbine Oil Coolers. .......................................... 156 8. Swapping Oil Coolers for 1A MFPT........................................................................ 156 8. Swapping Oil Coolers for 1B MFPT........................................................................ 159 Throttling HIP Steam Supply 1501 During MFPT Startup 162 ( 8. Throttling 1A MFPT HIP Steam Supply 1501 During Startup [C.5]......................... 162 8. Throttling 1B MFPT HIP Steam Supply 1501 During Startup [C.5] ......................... 162 Main Feedwater Pump Overspeed Tests ............................................................... 166 8. A MFP Overspeed Test. ....................................................................................... 166 8. B MFP Overspeed Test... ..................................................................................... 177 Resetting Feedwater isolation signal...................................................................... 188 Controlling MFPT via the Governor Valve Positioner 190 Swapping MFPT Main Oil Pumps with MFPT in Service 191 8. Swapping 1A MFPT Main Oii Pumps 191 8. Swapping 1B MFPT Main Oil Pumps 193 Online Main Feed Reg Valve Maintenance 195 8. Dogging SIG #1 Main Feed Reg Valve 195 8. Dogging SIG #2 Main Feed Reg Valve 204 8. Dogging SIG #3 Main Feed Reg Valve 213 8. Dogging SIG #4 Main Feed Reg Valve 222 (
1-S0-2/3-1 SQ N CO ND ENSATE A ND FEEDWATER SYSTEM Rev 46 ( 1 Page 5 of 267 TABLE OF CONTENTS Page 4 of 4 Hotwell Feed and Bleed 231 8.10 Manual Operation of Exhaust Hood Sprays 232 8.11 Swapping High Pressure Injection Water Pumps 233 8.12 Rolling of Second MFWP to 50 psig less than Feedwater Pressure 235 8.1 3 Manual Selection of Controlling Feed / Steam Flow Cha nnels 244 8.14 Operating MFP A Oil Pumps for Maintenance . 247 8.15 Ope rating MF P B Oil Pumps for Maintenance 248 8.16 MFPT HSC Adjustment other than Initial Minimum Speed.................................... 249 8.17 Adjustment Of The CBPs Bearing Oil Temperature 258 8.18 Make up and_dumpback to and from Hotwell using manual bypass val ves 259 RECORDS 260 ( APPENDIXES APPENDIX A: MAIN FEEDWATER PUMP DUPLEX FILTERS 261 APPENDIX B: CONDENSATE STORAGE TANK DISSOLVED OXYGEN REMOVAL VIA NITROGEN PURGE .. 262 APPENDIX C: 1-FCV-2-35A DOG OPERATION 263 APPENDIX D: MAIN FEED REGULATING VALVE DRAWING 266 SOURCE NOTES................................................................................................... 267 A TTACHME NTS ATIACHMENT 1: CONDENSATE AND FEEDWATER SYSTEM POWER CHECKLIST 1-2/3-1.01 ATIACHMENT 2: CONDENSATE AND FEEDWATER SYSTEM POWER CHECKLIST 1-2/3-1.02 ATIACHMENT 3: CONDENSATE AND FEEDWATER SYSTEM VALVE CHECKLIST 1-2/3-1.03 ATIACHMENT 4: CONDENSATE AND FEEDWATER SYSTEM VALVE CHECKLIST 1-2/3-1.04
1-S0-2/3-1 SQN ( 1 CONDENSATE AND FEEDWATER SYSTEM Rev 46
'. Page 6 of 267 INTRODUCTION Purpose This procedure provides instructions for the operation of the Condensate and Feedwater System .2 Scope This procedure provides the deta iled steps to perform the following operations: Filling and deaeration of the short-short cycl Filling and deaeration of the short cycle . Filling and deaeration of the long cycle . Changing from long cycle deaeration to normal alignment for filling S /G with feedwate MairrFeedwater Pump operation (startup , shutd own , and swapping of oil pumps ). Startup and shutdown of: Hotwell Pumps Condensate Booster Pumps Cond Demin Booster Pumps High pressure injection water system startup and shutdow MFPT Overspeed Tes Resetting Feedwater Isolation Signa Manual Operation of 1-FCV-2-35A dog . REFERENCES Performance References Proced ures GO -4, Unit Startup from Less Than 5% Reactor Power to 35% Reactor Power GOI -6, Apparatus Operations SO-12-1 , Auxiliary Steam System SO-24-1 , Raw Cooling Water System (
SQN 1-50-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 7 of 267 Performance References (Continued) , Nitrogen System , Main Steam System , Condense r Vacuum System S0 -5-2, NO.3 Heater Drain Tank and Pumps S0-5-4, Feedwater Turbine Condenser Drain Tank and Pumps 10. 1-S0 -5-5, Atm ospheric Condensate Drain Tank Pump Opera tion 11 . 1-S0-14-1, Condensate Demineralizer Operation 12. 1-S0 -41 -3, Steam Generator Recirculation System Tech Specs .3.2 1 and Table 3.3.3. . 3.7. .2 Developmental References FSAR ( . . 10 Procedures GO-3, Power Ascension from Reactor Critical to Less Than 5 Percent Reactor Power GO-5, Normal Power Operation SOI-2.1 & 3.1, Condensate and Feedwater System TVA Drawings W610-2-1 through 5 W610-3-1 and 2 W610-46-3 and 4 W80 1-1 W 803-1 and 2 W804-1 and 2 End of Section (
1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 8 of 267 PRECAUTIONS AND LIMITATIONS Main Feedwater Pumps A At least one Main Feedwater Pump Turbine (MFPT) Trip Bus should be deenergized to ensure an inadvertent ESF actuation does not occur. Trip busses are required operable in Modes 1 and 2 per T.S. 3.3.2.1, Table 3.3.36.f. [C.1] B. Motor driven oil pumps for the MFP should be operating to provide oil to the pump and turbine bearing C. Injection Water should be aligned to Condensate Booster Pump (CBP) and Main Feedwater Pump (MFP) at all times when pumps are runnin D. Oil pressure leaving the MFP oil coolers should be greater than 20 psig and temperature should not be greater than 120° E. Level in each Steam Generator (S/G) should be monitored for possible feedwater (FW) isolation valve leakag F. During secondary plant warm-up, draw steam slowly and regulate FW additions carefully to avoid rapid cooling of reactor coolan G. When a S/G water level channel is out-of-service, the hi-hi level bistable for that channel shall be placed in a tripped mode.
( H. The S/G Feedwater Regulator Bypass Valves' flow capability is limited to 15 percent of full load flo Byron Jackson recommend s a maximum warm-up rate of approximately 1OO°F/hr which corresponds to a warm-up flow of approx. 10 to 15 gp J. The warm-up process should continue until surface temperature of the pump casing near the top of the volute case is within 75°F of hot fluid temperatur If it is determ ined that 75°F differential is difficult to achieve, then 100°F is acceptabl K. After MFP is filled and vented, it should be placed on turning gear for warming. A MFPT shall never be placed on turning gear unless pump is filled and vented . l. With turning gear motor Handswitch in P-A UTO and speed less than 2 rpm, the turning gear motor will auto start when other interlocks are mad M. MFPT should be placed on turning gear 45 min. before rolling with stea N. Normal return operating oil temperature from the feed pump turbine and pump bearings should be maintained between 140°F and 160° O. To ensure a smooth startup of the MFP the temperature of the oil leaving the heat exchangers should be stabilized at approximately 110°F before placing the MFP on minimum spee Normal operating temperature of the turbine and pump bearing metal should not exceed 185° ( Minimum bearing oil temperatu re for the feed pump turbine on turning gear is 70° S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 9 of 267 PRECAUTIONS AND LIMITATIONS (Continued) Main Feed wate r Pumps Gland sealing steam should not be applied to the MFPT with the rotor at res Condenser vacuum should not be placed on MFPT without sealing steam at the glands to prevent air being drawn into MFP Undue heating of low-pressure portion s of the turbine should be avoided . If turb ine has been idle for a considerable period of time, the stop valves should be tripped immediately after starting to see if tripping mechanism functions properl MFPT startup drains should be open on startup and left open until the main turbine load is 40 percent of rated load and opened on shutdown when load is reduced to 25 percen W. MFW pump and turbine thrust bearing wear alarm and trip and bearing vibrati on alarm values are determined each startup. Current values are on the ICS , Seconda ry Mimics, MFP Bearing Data page either on the "Full Database Info" page (for a particular point) or by selecting the "MFP Al B Runout" button . MFW pump and turbine bearing vibration should not exceed 5 mils above baseline (alert value is 3 mils above baseline). Vibr ation should be monitored locally at Bently Nevada vibration monitoring panel (1 -L-598) and ICS (Secondary Mimics, MFP Bearing Data). Bently Nevada thrust bearing monitor will trip the MFPT on high thrust bearing wear setpoint of 10 mils above baseline with 2/2 logic. (Alert value is 7 mils above baseline.) When shuttin g down, should it become necessary to exercise manual control of the turning gear , do so with caution. First observe rotor in exhaust and gland area to be certa in all rotation has stopped before starting turning gea AA . During hot shutdown , FW additions should be controlled to minimize the thermal stress cycles of the FW nozzle AB. MFPTs will trip if Injec tion Water supply header pressure falls below 220 psig on 2/2 pressure switches for 28 sec (MFWP 1A) or 20 sec (MFW P 1B).
AC . Ensure the motor-driven oil pumps for the main feed pump are running if the pumps are not valved out before a Hotwell Pump is started. These pumps will rotate with water flowi ng through the AD. 1-PIS-47-13RLY1, "Turbine Runback From Loss of 1 MFP", is armed when the relay number (1) is illuminated on PaneI 1-L-262 .
~.
1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 10 of 267 PRECAUTI ONS AND LIMITATI ONS (Continued) Main Feedwater Pumps AE . If th e bias of either MFTP Controller (1-SIC-46-20A or 1-SIC-46-20B ) is changed away from 50% and eithe r that controller or the Mas ter Controller (1- PC-46-20) is place d in Manual, then res toration to Automatic without restoring the bias to 50% will result in an instan tane ous spe ed change of the affe cted MFP .2 Condensate Pumps Do not exceed maximum number of starts on 6,900V motors in accordance with GOI-6 . The tempe rature of th e water in the Hotwell (HW) should not exce ed 120° HW mu st not be filled greater tha n 18 inches above normal, unless w ater tem perature is greater than 60°F (prevent stressing the conden ser wall we lds).
( Do not pump water from the HW to Condensa te Storag e Tanks (CSTs) after condenser vacuum is broken, due to increas ing the Oxygen level in th e CST, unless given permission by the Radiochemical Laboratory (RC L) Shift Su perviso The motor-driven oil pump for each CBP should start when each pump suction FCV is opened . Condensate flow through condensate dem ineralizer polishers should not be established if condensate Oxygen level is not within specifications as determined by the RC L Shift Superviso Do not allow HWP flow through an idle CBP . With CBP sucti on FCV open and subjected to HWP disch arge pressure, water can contaminate the bearing oi When charg ing Condensate System , valves shoul d be opened slow ly to prevent a sudden pressure drop and loss of Injection Water to the MFP Ts . This could cause a main feed pump trip and auto start of auxiliary fee d pumps. [C.1] Before the first HWP is started , the discharge val ve should be unlocked and throttled to about 25 turns open. The valve should be opened fully and locked or the second HWP started once HWP discharge pres sure , flow , and HW level has stab ilized to a point wh ere filling of the HWP discharge piping can be verified. [C.2]
SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM ( 1 Rev 46 Page 11 of 267 PRECAUTIONS AND LIMITATIONS (Continued) A HWP must be running to supply suction to Injection Water Pump Do not run Injection Water Pumps for extended periods (over 4-5 min .) unless at least one MFP is receiving sea l water since Injection Water Pumps do not have a recirculation flowpath . Prior to starting first HWP, an operator shall be stationed locall y at the pumps during initial start and fillin g of the syste m and sha ll immediately notify the Unit Operator if any abnormal pump op eration occurs (e.g ., unusual noise, discharge or suction pre ssure abnorma l). Do not exceed 98% level in CST The demineralized wate r for filling the CSTs must be w ithin acceptable limits as required by O-TI-CEM-OOO-001 .1 with the exception of dissolved oxygen . ( Self venting of the CBP will occur through recirculation pipi ng. As the suction FCV is opening , air will be removed as flow is directed into the condenser through the recirc line . MIG sup port is required to ensure correct sea l inje ction water press ure prior to placing a CBP in service or remo ving a CBP from service. If injection water pressure is too high follow ing shutdown , water can contaminate the bearing oi Intermed iate and atmospheric sealleakoffs must be OPENED prior to aligning injection water to a Condensate Booster Pump . If injection water is aligned without a leakoff path, bearing oil may be displaced by the high pressure injection wate When a CBP is subjected to condenser vacuum (through the recirculation line ) without seal injection aligned, th e pump shaft seals become a condenser vacuum boundary. Air may be pulled in through seals and cause condenser in leakage to increas Wh en adjusting seal differential pressu re, lea koff line movement may be obse rved . Th is is caused from flashing. By increasing the seal delta-P, the lea koff line temp erature is reduced wh ich causes less flashing . Target for leakoff line temp is < 220 °F.
(
SQN 1-80-2/3-1 CONDENSATEAND FEEDWATERSYSTEM Rev 46 ( 1 Page 12 of 267 PRECAUTIONS AND LIMITATIONS (Continued) T . If condensate system is to be placed on hotwe ll recirculation. with system drained and LP heaters isolated . 1-FCV-2-329A and 329 B should be isolated to preven t inadvertent cycling when filling and venting LP heaters and dow nstream piping . 1-FCV-2-329A has a mechanical stop externally inserte d on the stem to maintain the valve partially open at all times . This helps prevent a water hammer cond ition if the valve closes with steam generator blowdown inservice to the heat excha nger. The open position results in a contin uous flowpath around the LP heaters and will resul t in filling the system downstream of the LP heaters during system filling and venting for hotwell reci rculation. 1-FCV-2-329A and 329 B are con tro lled by 1-PDI S-2-329, wh ich sen ses differential pressu re across the LP heaters . U. Th e hot well level indica tors may read differently on each condense This is caused by various water inputs into each condenser.
( "A" Condenser receives wa ter from 8 /G blowdown from 1st stage HX , Atmospheric Cond Dr Tk and MFPC Dr Tk byp ass .
"B" Condenser level indicator is erratic due to the valve/sparger header for 1-FCV-2-35 at 5,500 gpm flow rate being in the close proximity of the level transmitte "C" Conden ser receives Conde nsate Boos ter Pump recirc flow .
Pressu re differences betwe en the Conde nser sections can be ca used by CCW water box outages, dirty tube sheets, dirty debris filters. All these thing s affect actual hotweill eveis and the ability to contro l leve l at a normal 18" setpoin Plant modes of operation such as: Long cycl e, Main Feed Water Pump recirc V alve opening, Condensate Booster recirc operatio n, #3 and #7 Heater Dr Tk bypas s Val ve operation can cause Hotweillevel deviations.
( End of Section S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 13 of 267 Date nlJlhj PREREQUISITE ACTIONS NOTE 1 Throughout this instruction where an IF/THEN statement occurs, the step may be N/A if the condition does not exis NOTE 2 Throughout this instruction where the verb " VENT" is a directed action, the following actions should be performed: THROTTLE OPEN the specified valve(s). WHEN a steady stream of water flows from vent, THEN CLOSE the opened valve(s).
[1] ENSURE instruction is a copy of the effective version .
[2] ENSURE Precautions and Limitations, Section 3.0 has been reviewed . [3] ENSURE Power Checklist 0-2/3-1.03 (2-S0 -2/3-1 Att. 3) COMPL ET [4] ENSURE Valve Checklist 0-2/3-1.06 (2-S0 -2/3-1 All. 6) COMPLET [5] ENSURE each performer documents their name and initials:
Print Name Initia ls
[6] INDICATE below which performance section of this instruction will be used and the reason for this performance :
o STARTUP/STANDBY READINESS W NORMAL OPERATION o SHUTDOWN o INFREQUENT OPERATION Reason: _ End of Section SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 109 of 267 5.16.3 Startup of First MFPT
[1] ENSURE MFP condenser drain tank is aligned in accordance with 1-S0-5- NOTE Throughout this section , N/A the non selected MFPT handswitches and valves . [2] RECO RD MFPT selected to be started firs [3] ENSURE applicable Preparation for Startup has beem completed:
MFPT PREPARATIO N FOR STARTUP INITIALS 1A Section 5.16.1 of this instruction 11f 1B Section 5.16.2 of this instruction rP( NOTE Drain valves in the following step will open automatically when LS-47-184 actuates. If these valves are open, MFWP gland seal steam supply pressure may be abnormally low resulting in MFWPT condenser air inleakage and inadequate vacuum. If the level switch has actuated, the valves will remain open until reset using local handswitc [4] ENSURE drain valves on MFPT gland steam supply CLOSED:
[a] ENSURE [1-HS-47-292] in CLOSE [1-M-2]. [b] IF [1-FCV-47-291] or [1-FCV -47-292] do NOT indicate CLOSED on 1-XX-47-1 [1-M-2], THE N RESET drain valves USING reset switch [1-HS-47-1951 [TB el. 685, east of common steam header] . [5] ENSURE applicable MFP outlet valve OPEN:
DESCR IPTION VALVE N POSITION INITIALS FWP 1A Outlet Flow Contro l Valve 1-FCV-3-67 OPEN Ii? FWP 1B Outlet Flow Control Valve 1-FCV-3-81 OPEN ;)/
(
SQ N 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 110 of 267 Date To .1 Startup of Firs t MFPT
[6] ENSURE MFPT Speed Control Bias dial at 50%. o [7] PLACE MFPT speed controller for the MFPT to be started in AUT SPEED SWITCH ,f DEMAND ,f MFPT CONTROLLER POSITION SETPOINT A SIC-46-20A AUTO 0 ZERO 0 B SIC-46-20B AUTO 0 ZERO 0 [8] DISPATCH personnel to determine if electri c speed chang er outlet pressure on 1-PI-46-5100 for A MFPT or 1-PI-46-5105 for B MFPT indicating between 18-22 psig . o ( [9] IF electric speed changer outlet pressure is NOT correct, THEN NOT IFY IMs to evaluate EH speed change signa o NOTE Either stop valve handswitch will open both high pressure and low pressure stop valves for the applica ble MFP [10] OPEN Stop Valves for the MFPT to be started by placing either the HIP or LIP handswitch to the RAISE positio MFPT DESCRIPTION HANDSWITCH ' VALVE POSITION INITIALS 1A HI P Stop Valve 1-HS-46-15A OPEN LIP Stop Valve 1-HS-46-16A OPEN 18 HIP Stop Valve 1-HS-46-43A OPEN LIP Stop Valve 1-HS-46-44A OPEN [11] VERIFY Stop Valves are OPEN by RED lights LIT and GREEN lights DARK for both the HIP and LIP Stop Valve o [12] VERIFY MFPT OFF Turning Gea o (
1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev46 ( 1 Page 111 of 267 Date _ 5.16.3 Startup of First MFPT (Continued) NOTE 1 . Vibration and thrust bearing wear should be monitored on local Bently Nevada panel and ICS (Secondary Mimics, MFP Bearing Data). Max allowable vibration (danger limit) is 5 mils above baseli ne; alert value is 3 mils above baseli ne. Thr ust bearing wea r trip setpoint is 10 mils above base line (7 mils alert above baseline).
NOTE 2 1A MFWP condenser vacuum may be monitored using 1-PI-2-33 1A (TB el. 685), ICS computer point 1U2082 , or by monitoring condense r drain temperature (ICS point 1T2360A). 1B MFWP condenser vac uum may be monitored using 1-PI-2-331B (TB el. 685), ICS computer point 1U2084, or by monitoring condenser drain temperature (ICS point 1T2361A). Drain temp " 160°F indicates vacuum of at least 20" H MFWP trip setpoint of 12.2 psia corresponds to - 5 "Hg vac uum or drain temp of - 200° NOTE 3 Max allowable bearing temperature is 225° [13] MONITOR the following parameters during MFWP startup :
* V ibration and thrust bearing wear (at local panel) o * MFWP Condenser vacuum/drain temperatu r o * Oil system and beari ng temperature o
1-5 0 -2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 112 of 267 Date _ 5.16 .3 Startup of First MFPT (Continued) CAUTION . If unstable or unexpected results are encounte red following man ipulations the n return the plant to the last known stable cond it ion. Startup should not proceed until problem is evaluate NOTE The feedwater pump speed controller will take control at the minimum speed setting and run the governor valve positioner out to its upper limit. Minimum speed on high pressure steam is 3100 to 3,300 rpm and 3650 to 3850 rpm on low pressure steam. This value may vary based on previous hand speed changer adjustment by MI [14] ACCELERATE the MFPT between 2500 and 3300 rpm by PERFORMING one of the following:
[A] I ~ MCR operation of Governor Valve Positioner is available, THEN BUMP the applicable Governor Valve Positioner in the RAISE direction'
( MFPT DESCRIPTION HANDSWITCH POSITION INITIALS A GV Positioner 1-HS-46-13A OPEN B GV Positioner 1-HS-46-40A OPEN
[B] IF MCR operation of Governor Valve Positioner is unavailable, THEN ESTABLISH direct communications between the personnel operating the U1 MFP speed control locally and the U1 Main Control Roo D DIRECT MIG to slowly adjust U1 MFP Speed Control using local manual control of the MFP Governor Valve Positioner to throttle steam chest vales and control MFPT spee D
1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 113 of 267 Date _ 5.16.3 Startup of First MFPT (Continued)
[15] WHEN MFPT speed is between 2500 and 3300 rpm, THEN PERFORM the following : [a] ENSURE MFPT oil temperature is stable (approx. 110°F). o [b] SET speed controller to zero (0) output in MC o [16] IF MFP bearing vibration is greater than 3 mils above baseline at 2500-3300 rpm , THEN OBTAIN Vibration Engineer's concurrence prior to increasing MFPT spee o - [17] NOTIFY MIG to adjust the MFPT Speed Hand Changer as the MFWP is accelerated for a minimum speed on high pressure steam between 3100 to 3,300 rp o [18] FULLY OPEN the Steam Chest Valves for the MFPT by PERFORMING one of the following: [a] IF MCR operation of Governor Valve Positioner is available, THEN PLACE the applicable Governor Valve Positioner in the RAISE direction'
MFPT DESCRIPTION HANDSWIT CH POSITION INITIALS A GV Positioner 1-HS-46-13A OPEN B GV Positioner 1-HS-46-40A OPEN
[b] IF MCR operation of Governor Valve Positioner is unavailable, THEN ESTABLISH direct communications between the personnel operating the U2 MFP speed control locally and the U2 Main Control Roo . DIRECT MIG to slowly adjust U2 MFP Speed Control using local manual control of the MFP Governor Valve Positioner to fully open steam chest valve o
1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM ( 1 Rev 46 Page 114 of 267 Oate _ 5.16.3 Startup of First MFPT (Continued)
[19] VERIFY Governor Valve Positioner has a RED light LIT and a GREEN light DAR D NOTE MFPT speed may swing at low loads due to the large pressure drop across the HIP governor valve. The magnitude of the swing is related to MFPT control system temperature. If MFWP has been out of service for a long time (several days), speed swings of - 400 rpm have been observed. If MFWP has been out of service for a short time, speed swings of 50-100 rpm have been observed. If desired, HP steam supply isolation valve may be throttled using Section to reduce swinging. Swinging should lessen as MFWP control system warms up and should eventually disappear as MFWP load is increased. (Reference: PER 03-002665-000) [20] IF MFPT speed starts swinging and will not stabilize, ( THEN PERFORM the following: [a] ENSURE recirc valve for affected MFW pump is FULLY OPE D [b] EVALUATE throttling HP steam to MFPT in accordance with Section D [e] IF swingin g is excessive (indicating malfunction of MFWP governor valve or speed controls), THEN PERFORM the following : STABLIZE plant at last stable conditio D CONSULT Systems Engineering for assistanc D INITIATE WO for repair of MFPT. [C.5] D IF necessa ry to swap to other MFPT , THEN GO TO Section 7.0 for shutdown of MFP D
1-S0-2/3-1 SQN CONDENSATE AND FEEDWATER SYSTEM Rev 46 ( 1 Page 115 of 267 Date _ 5.16.3 Startup of First MFPT (Continued) CAUTION 1 MFP discha rge pressure m ust be increased in 10 psi increments to prevent uncontrolled overfilling of S/Gs due to possible leakage past main feed reg valves and main feed reg bypass valves. [C Al CAUTIO N 2 Anticipate steam gene rato r sh rink or swell ANYTIME system fl ow o r pressure changes. DO NOT use reactor powe r changes as a means to shrink or swell levels. [CAl NOTE 1 The master speed controller deviation meter will indicate if the actual DP is higher or lower than program (e.g. if the deviation is to the right, then the pressure is too high, move controller to left to reduce MFPT speed and feedwater pressure).
( NOTE 2 The ICS may be used as an indication of feedwater/steam system DP (ICS point 1PAC05). This display comes from
[1-PT -3-34] and [1-PT-1-33]. However, DO NOT use the ICS S/G LEVEL indication due to its long update interva [21] INCREASE MFP speed with the Master Speed Controller, [1-PC-46-20] in MANUAL by 10 psig increments until feedwater header pressure is approximately 80 psi greater than Steam Header Pressur o [22] ENSURE MFP Injection Water Intermediate Leakoff Pressure for pump started is 200-250 psi [a] [1*PI-54-2]. 1A MFP OR [b] [1-PI-54-6]. 1B MFP [23] ENSURE MFP Injection Water Differential Pressure for pump started is equal to or greater than 25 psi [a] [1-PDI-54-1] , 1A MFP OR [b] [1-PDI-54-5] , 1B MFP
1-S0-2/3-1 SON CONDENSATE A ND FEEDWATER SYSTEM Rev 46 ( 1 Page 116 of 267 Date _ 5.16.3 Startup of First MFPT ( continued)
[24] WHEN [1-PI-3-1]. FW Header Pressure is approximately 80 psi greater than [1-PI-1-33] , Steam Header Pressure, THEN ADJUST MFP Master Speed Controller [1-PC-46-20]
to obtain ZERO deviation on the controlle o NOTE MFPT speed control program is 80 psid from 0% to 20%, then ramps from 80 psid to 194.2 psid at 100% powe Ramp is linear between 20 and 100%.
[25] PLACE [1-PC-46-20]. MFP Master Speed Controller in AUT CAUTION 1 MFP Recirc valves controllers should NOT be operated in AUTO MATIC due to the potential for isolating all three ( intermediate heater strings and resulting MFP damag (Reference: PER 00-002540-000).
CAUTION 2 Clos ure of th e MFP recirc valves on runni ng MFWP w ith out ensuring su fficient forwa rd flow could result in overheating and pump damag CAUTION 3 Operation of MFP RECIRC valve should be performed slowly due to affect on MFP !l.P prog ra [26] WHEN main feedwater fiow is greater than 1.7 x 106 Ibm/h THEN ENSURE recirc valve for running MFWP [1-FCV-3-70] or
[1-FCV-3-84] CLOSED and in MANUA [27] MONITOR MFP discharge for stability and on progra o [28] IF program !l.P cannot be maintained. THEN OBTAIN SM concurrence to operate in MANUAL. [C.5]
( End of Section 5.1 ( , Sequoyah Nuclear Plant ( Unit 1 & 2 General Operating Instructions O-GO-3 POWER ASCENSION FROM REACTOR CRITICAL TO LESS THAN 5 PERCENT REACTOR POWER Revision 0018 Quality Related Level of Use: Continuous Use ( Effective Date: 05-05-2006 Responsible Organization: OPS, Operations Prepared By: Jimmy Morris Approved By: W. T. Leary Current Revision Description Added step to section 4.0 concerning Con 01 operation, ref. NB05080 (
SQN POWER ASCENSIO N FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Paq e 2 of 24 Table of Co nten ts INTRODUCTION 3 Purpose 3 Scope 3 REFERENCES 3 Performan ce References 3 Develop mental References 4 PRECAUTIONS AND LIMITATIONS 5 Precautions 5 Limitations 5 PREREQUiSITES 6 INSTRUC1] ONS 8 Act ions To Be Performed Prior To Increasing Reactor Power 8 Power Ascens ion To Approximately 1% RTP 10 ( Transferring Feedwater From Auxiliary To Main Feedwater 16 RECORDS 23 Source Notes 24 ATT ACH MENTS Attachment 1: Procedure Checklist
SQN POWER ASC ENSION FROM REACTOR 0-GO-3 Un it 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Paqe 3 of24 INTRODUCTIO N Purpose This General Operating (GO) Instruction provide s necessary instruc tions to raise reactor power to appro ximately 1% for main feed pump startup and to transitio n from auxiliary feedwater to main feedwater with the feedwater bypass reg. valves in AUTO . Scope T his GO contains the following sections: .1 Actions To Be Performed Prior To Increasing Reactor Power .2 Power Ascension To Appro ximately 1% RTP .3 Transfe rring Feedwater From Auxiliary To Main Feedwater RE FERE NCES ( Performan ce Refe rences , Steam Dump System ,2-80-15-1,2, Steam Generator Blowdown C 1,2-80-5-1, Feedwater Heaters and Moisture Separator Reheaters ,2-80-5-2, NO.3 Heater Drain Tank and Pumps ,2-$ 0 -5-3, NO.7 Heater Drain Tank and Pumps ,2-80-5-4, Feedwater Turbine Condenser Drain Tank and Pumps ,2-8 0-5-5, Atmosph eric Condensate Drain Sump and Pumps ,2-80-2/3-1 , Condensate and Feedwater System ,2-80-3-2, Auxiliary Feedwater System ,2-80-1-1, Main Steam System MI-20.154 Controller Tuning Instruction ( ,2-81 -0P8-000-002.0, Shift Log O-RT-NU C-OOO-00 1.0, Restart Test Program
SQN POWER ASCENSION FROM REACTOR 0-GO -3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Pane 4 of 24 Performance References (continued) O-PI-OPS -OOO-001.0, Initial Startup System Parameter Log Developmental References O-GO-1, Unit Startup from Cold Shutdown to Hot Standby O-GO-4 , Power Ascension from Less Than 5% Reactor Power to 30% Reactor Po wer SPP - FSAR Section 13.5 (
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THA N 5 PERCENT Rev. 0018 (' REACTOR POWER Paqe 5 of 24 PRECAUTIONS AND LIMITATIONS Precaution s Reactor Engineering should be contacted for guidance on core operating recommendations during unusual power maneuvers such as startup during end of core life. (C.5] Reactor power should be monitored using the following indications: Average loop IlT (U0485). Considered to be the most accurate power indication when less than 15% powe . NIS power rang . Steam dump demand. (REFER TO graph in 0-SO-1-2).
NOTE Pressurizer heaters and sprays may be operated, as required, to maintain pressurizer and RCS boron concentration within 50 ppm.
( The boron concentration in the pressurizer should be maintained within 50 ppm of the RCS by use of pressurizer heaters and spra Control rod bank 0 should be ~ 165 steps at steady state power levels below 85% RTP. This guidance is to preclude long term operation at greater than 165 steps to avoid potential impact on safety analysis assumptions. Short term operation at less than 165 steps is NOT a concer .2 Lim ita tions Do NOT exceed a steady startup rate of + 1 DP After refueling operations , the NIS indications may be inaccurate until calibration at higher power levels . The NIS calibration procedures will adjust the PRM trip setpoints to ensure that the excore detectors do NOT contribute to an overpo wer condition. Prior to startup , the PRM high range flux trip setpoint will be adjusted from 109 to 60%, with the rod stop (C-2) remaining at 103%.
[C .2] If fuel defects are present, Preconditioned Power Levels and Maximum Allowable Rates of Power Increase specified in TI-40, Determination of Preconditioned Reactor Power shall appl (
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Page 6 of 24 Startup Number I~o I Unit ..............
/_ Date III !OV") PREREQUISITES NOTES 1) T hroughout this Instruction wh ere an IFITHEN statement exists, the step should be N/A 'd if condition does NOT exis ) Prerequ isites may be completed in any orde ) Th is ins truction may be ente red from a partial shutdown, N/A sections NOT applicab le and annotate reaso [1 ] ENSURE Instruction to be use d is the latest cop y of effective version . [2] ENSURE Pre cautions and Limitati ons have been reviewe [3] ENSURE main steam system aligned with MSIVs open in accordance with 1,2-S0 -1- [4] ENSURE the reactor is critical w ith powe r at app roxima tely 1 X 10.3% . [5] MAINTAIN pressur izer press ure within the normal operating ba nd by use of the pressu rize r heaters and spra y valve [6] MAINTAIN pressurizer level greater than or equa l to 25%. [7] MAINTAIN T AVG stable with the stea m dum ps in pressure mode or with the SG atmospheric relief valves set at 84%
or 1005 psi [8] MAINTAIN SG levels within the normal operating range using Auxilia ry Feed wate NOTE During start up after a cold shutdown the Condensate 01 normally will be aligned for full flow polishing until the MSRs are in servic [9] ENSURE Co ndensa te 0 1polishing operation in acc orda nce with RCL reco mmendations .
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 (-, REACTOR POWER Page 7 of 24 Startup Number I uIJI Unit--!...f_ Date~ PREREQUISITES (continued)
[10j ENSURE each performer documents their name and initials:
Print Name Initials Print Name Initials End of Secllon
SON POWER ASCENSION FROM REACTOR 0-GO*3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Page 8 of 24 Startup Number flOI Unit ( Date nJ.., INSTRUCTIONS CAUTION Steps of this procedure must be performed sequentially, unless specifically stated otherwis .1 Actions To Be Performed Prior To Inc reasing Reactor Power
[1] ENSURE Section 4.0, Prerequisites complet NOTE Steps 5.1[2] through 5.1 [7] may be performed in any orde [2] ENSURE two Hotwell pumps in service in accordance with 1,2-S0-2/3-1 .
( [3) ENSURE one condensate booster pump in service in accordance with 1,2-S0-2/3-1 . CAUTION The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolate NOTE Step 5.1[4] may be performed out of sequence (later) due to plant conditions as approved by the S [4) ENSURE secondary plant is aligned for startup in accordance with the following: INSTRUCTIONS INITIALS 1,2-S0 -5-1, Feedwater Heaters and Moisture Separator Reheaters Itt 1,2-S0-5-2, NO.3 Heater Drain Tank and Pumps tll( 1,2-S0-5-3, NO .7 Heater Drain Tank and Pumps //rt
SQN POWER ASCE NSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Page 9 of 24 Startup Number loul Unit I
* Date ~ Actions To Be Performed Prior To Increasing Reacto r Power (continued)
INSTRUCTIONS INITIALS 1,2-S0-5-4, Feedwater Turbine Condense r Drain Tank and Pumps Jlltr 1,2-S0 -5-5, Atmos pheric Condensate Drain Sump and Pumps If/!-( NOTE Steps to prepare for MFPT startup may be performed in parallel with power ascension to 1-2%. MFPT trip busses should be energized, otherwise action 20 of LCO 3.3.2.1 (3.3.2) is applicable . lC.1]
[5] IF any MFPT trip buss is NOT energized , THEN ENSURE action 20 of LCO 3.3.2.1 (3.3.2) has been entere tift ( US/SRO [6] WH EN MFPT designated for startup is available, THE N PERFORM 1,2-S0 -2/3-1, Preparation of Main Feedwater Pumps for Startup. (N/A if previously performed) [7] IF startup is on Unit 2, AND Secondary System Boric Acid Injection has been in service, THEN ENSURE System has been removed from service in accordan ce with 0-SO-36-3 , Secondary System Boric Acid Inj ectio End of Section
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO L ESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Page 10 of 24 Startup Number Un it _ _ Date _ Power Ascension To App rox imately 1 % RTP NOTE Average loop L\T (U0 485) is considered to be the most accurate power indicat ion below 15% power. NIS power range and steam dump demand should also be monitore (REFER TO 0-SO- 1-2 for steam dump demand program.) [C.3j
[1] W ITHDRAW RODS OR DILUTE to bring reactor power to between 1 and 2% RTP, while continu ing with this instructio o NOTE After refueling operations the "Initial Startup System Parameter Log" is perform ed during power escalations to provide the operat or with alternate indications of power level (indications independent of calorimetric calculations ). If significant differences occur (approx. 5%) between the alternate power indications then Engineering should be notifie [2] IF startu p is after a refueling or maintenance on NIS, THEN INITIATE performance of 0-PI-OPS-000-001.0, Initial Startup System Parameter Log. [C.3] 0 [3] COMPARE NIS power range instrumentation with loop L\T indicators and steam dump demand to evaluate accuracy of PRMs . [C.3] 0 [4] SELECT the highest reading IRM or L\I and PRM channels to be recorded on NR 45. [C.3) 0 [5] REVIEW plant parameters and indications to determine plant stability prior to startup of Main Feed Pum [6] MAIN TAIN reactor power appro ximately 1%. 0 (
SQN POWER ASCE NSIO N FRO M REACTOR 0-GO- 3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERC ENT Rev. 0018 ( REACTOR POWER Page 11 of 24 Startu p Number Unit _ _ Date _ Powe r Ascension To Appro ximately 1% RTP (contin ued) NOTE Steps 5 .2[7] and 5.2[81may be performed in any orde [7] WHE N total Au x FW flow to SGs 1 and 2 is constan t and greater than or equal to 300 gpm . THEN CLOSE [FCV-3-4001. A FW PUMP A RECIRC ISOL VLV. and PLACE handswitch [HS-3-400Al in the PUL L TO LOCK positio st IV
[8] WHEN total Aux FW flow toSGs 3 and 4 is constant and greater than or equal to 300 qprn, THEN CLOS E [FC V-3 -4011. AFW PUMP B RECIRC ISOL VLV. and PLACE handswitch [HS-3-401Al in the PULL TO LOCK positio st IV NOTE Control rod bank D should be ~ 165 steps at steady state power levels below 85% RTP .
This guidance is to preclude long term ope ration at < 165 steps to avoid potential impact on safety analysis assumptions. Short term operation at < 165 steps is NOT a conc er [9] ENSURE the plant is stabil ized between 1 and 2% reactor power. [C.l ] [C.3] 0
[10 ] CO MPARE NIS intermed iate range instrumentation with loop t. T indications to evaluate accuracy of IRM*s. (C.l] 0
[11] RECORD IRM readings: [C.3]
( N35
- - - - -
% RTP o N36 % RT P o
- - - -
SON POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Paqe 12 of 24 Startup Number Unit _ _ Date _ Power Ascension To Approximately 1% RTP (continued) NOTE Step 5.2[12] may be performed out of sequence or in parallel with subsequent step [1 2J OPEN Turbine Exhaust Hood cooling valves
[FSV-47-215A, -215B, -215C] by placing [HS-47-2151. in ON position. [located on LP Htr Mezz] [1 3] WHEN startup of the first MFPT is desired, THEN PROCEED with step 5.2[14].
NOTE The following steps ensure MFPT trip busses energized and MFPTs reset if entering from 0-80-2 with no MFPT availabl [1 4] ENSURE MFPT designated for startup has been tested and ready for start up per 1, 2-80-2/3-1 PRIOR to proceeding with the next ste Initials Date Time (
SON POWER ASCENSION FROM REACTOR 0-GO-3 Uni t 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev . 0018 ( REACTOR POWER Page 13 of 24 Startup Number Uni t _ _ Date _ Power Ascension To App rox imately 1% RTP (continued) NOTES 1) The MFPT trip busses should be energized , otherwise action 20 of LCO 3.3.2.1 (3.3.2) is applicable. [C.1] 2) If both MFPT trip busses are de-energized, power should be placed on only ONE trip bus to prevent inadvertent AFW P star [15] IF both MFPT trip busses de-energized, THE N RESTORE power to ONLY ONE MFPT trip bus on the applicable unit. (N/A breakers NOT applicable.) [C.l ) PUMP BR EAKER N ELECTRICA L BREAKER INITIALS
-
BOARD POSITIO N 250v DC MFPT 1A 1-BKRD-4 6-KN523 Battery Bd I CLOSED 1st CV 250v DC MFPT 1B 1-BKR D-46-KN524 Battery Bd I CLOSED 1st CV 250v DC MFPT 2A 2-BKR D-46-KB/523 Battery Bd 2 CLOSE D 1st CV 250v DC MFPT 2B 2-BKRD-46-KB/524 Battery Bd 2 CLOSED 1st CV (
SQN POWER ASCENSION FROM REACTOR O-GO-3 Un it 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWE R Paqe 14 of 24 Startup Number Unit _ _ Date _ Power Ascens ion To Approx imately 1% RTP (continued) CAUTION Failure to reset a MFPT prior to energizing the remaining MFPT trip buss will initiate an ESF actua tio NOTE If an SI signal or a Hi/Hi steam generator level has occurred, the Reactor Trip Breakers will have to be cycled .
[1 6] ENSURE at least one energized MFPT trip bus is RESE Initials Date Time CV Date Time NOTE If the remaining NON-running MFPT is NOT availab le, steps 5.2[17] and 5.2[18] may be N/ [17] ENSURE power to the remaining MFPT Trip Bus on the applicable unit. (N/A breakers NOT applicable)
PUMP BREAKER N ELECTRICAL BREAKER INITIA LS BOARD POSITION 250v DC MF PT 1A 1-BKRD-46-KA/523 Battery Bd I CLOSED 1st CV 250v DC MFPT 1B 1-BKRD-46-KA/524 Battery Bd I CLOSED 1st CV (
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Uni t 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Paqe 15 of 24 Startup Number Unit _ _ Date _ Pow er Ascension To Approxima tely 1 % RTP (contin ued) PUMP BREAKER N ELECTRICAL BREAKER INITIALS BOARD POSITION 250v DC MFPT 2A 2-BKRD-46-KB/523 Battery Bd 2 CLOSED 1st CV 250v DC MFPT 2B 2-BKRD-46-KB/524 Battery Bd 2 CLOSED 1st CV
[18] ENSURE second MFPT is RESE Initials Date Time CV Date Time [19J START the first MFPT in accordance with 1,2-S0-2/3-1 . o End of Section (
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev . 0018 ( REACTOR POWER Page 16 of 24 Startup Number _ Unit _ _ Date _ Transferring Feedwater From Auxiliary To Main Feedwater
[1] VERIFY SG levels between 34 and 44%. o CAUTION Antic ipate a change in MFPT delta P when SG reg. bypass valves are adjuste ICAI NOTE The bypass reg. flow controller must be in MANUAL prior to adjusting setpoint value to prevent control ler gain input change. [CAl [2] ENSURE the reg. bypass valves are in MANUAL ICAI -
DESCRIPTION SG-1 Reg Bypass Flow Control CONTROLLER L1C-3-35 POSITION MANUAL
"
SG-2 Reg Bypass Flow Control L1 C-3-48 MANUAL 0 SG-3 Reg Bypass Flow Control L1C-3-90 MANUAL 0 SG-4 Reg Bypass Flow Control L1 C-3-103 MANUAL 0 (3) ENSURE the bypass reg. valve controller setpoints are set for a level of 39%. (C.4] o
[4] IF the NON-running MFPT trip buss is de-energized, ENSURE action 20 of LCO 3.3.2.1 (3.3.2) has been entere NOTE The following step will assure that a trip of the running MFP will initiate an AFW pump auto start . (Ref: TS LCO 3.3.2, PER 03-006930-000).
[5] IF the NON-running MFPT trip buss is energized, THEN TRIP the NON-runninGMFPT ' (N/A the running MFPT) MFPT HANDSWITCH INITIALS CV A HS-46-9A ( B HS-46-36A
SON POWER ASCENSION FROM REACTOR 0-GO -3 Uni t 1 & 2 CRITICA L TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Pac e 17 of 24 Startup Num ber Uni t _ _ Date _ Transfe rr i ng Feedwater From Auxilia ry To Main Feedwater (con tinu ed) CAUTION DO NOT increase reactor power above 2% until main feedwater reg. bypass valves are in control of SG level and Auxiliary Feedwater is shutdown . NOTES 1) Review plant parameters and indications to verify plant stability prior to transfer of AFW LCV to its associated MFW reg. bypass valv ) Transfer to only one main reg. bypass valve at a time. Stable level control shall be achieved in each steam generator before placing another reg. bypass valve in AUTO . Stable level control is defined as a stable oscillation of less than or equal to 5% or an oscillation that is decreasin ) The SG level operator is in control of unit startup until the main feedwater reg. valves are in AUTO . [C.4]
[6] PERFORM the following to transfer the SG level control from the AFW LCVs to the main feedwater reg. bypass valves :
SG-1 SG-2 SG-3 SG-4
[a] PLACE the reg. bypass valve controller in the AUTO positio D D D D [b] SLOWLY DECREASE AFW flow to the associated SG to ZERO gp D D D D [c] WHEN total AFW flow to both SGs is less than 300 gpm, THEN ENSURE AFW PUMP RECIRC ISOL valves are D D OP EN [d] ALLOW SG level to stabiliz D D D D [e] WHE N reg. bypass valve is controll ing SG level, THEN PROCEED TO another SG loop D D D D SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Page 18 of 24 Startup Number Unit _ _ Date _ Trans fe rring Feedwa ter From Auxil iary To Main Feedwater (continued) [7] IF SG level oscillations occur, THEN PERFORM the following to dampen the oscillations during SG level control with the reg. bypass in AUTO, (NJA if NOT required):
SG*1 SG-2 SG*3 SG-4
[a] PLA CE the reg. bypass valve controlle r in MANUA [b] ADJUST valve demand position less than 10% in the opposite direction of valve 0 0 0 0 trave [c] PLACE the reg. bypass valve
( controller in AUT NOTE Should reg. bypass valves NOT control properly in AUTO, then unit startup SHALL NOT continu e until correct ive actions have been taken to allow prope r operation of the re bypass controllers in AUTO unless waived by Plant Manage [8] IF the reg. bypass is NOT operating properly in AUTO, THEN STABILIZE plant conditions and NOTIFY the SM for corrective actions. [CA l Initials Date Time
[9] WHEN # 1 and 2 SG reg. bypass valves are in AUTO and SG levels have stabilized, THEN PERFORM the following steps (Steps may be performed later if unstable conditions exist or if the SM prefers to maintain the MDAFW pump A-A on recirc): [9.1] ENSURE AFW flow to SG #1 and 2 is ZER SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev . 0018 ( REACTOR POWER Paqe 19 of 24 [9.8] CLOSE [FCV-3-400j, AFW PUMP A RECIRC ISOL VLV with [HS-3-400A st IV [9.9] PLACE [HS-3-400Al. AFW PUMP A RECIRC ISOL VLV handswitch to the PULL TO LOCK positio st IV [10] WHEN #3 and 4 5G bypass reg. valves are in AUTO and SG levels have stabilized, THEN PERFORM the following steps (Steps may be performed later if unstable conditions exist or if the SM prefers to maintain the MDAFW pump B-B on recirc): [10 .1] ENSURE AFW flow to SG #3 and 4 is ZERO . ( [10.2] ENSURE #3 and 4 SG levels are stabl o
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Page 20 of 24 St artup Num ber Unit _ _ Date _ Transfe rring Feedwater From Aux iliary To Main Feedwater (continued) 1st IV
[1 0.7L PLAC E LCV-3-171 in AUT st IV [10.8] CLOSE [FCV-3- 4011, AFW PUMP B RECIRC ISOL VLV with [HS-3-401AJ, 1 st IV [10.9] PLACE [HS-3-401Al, AFW PUMP B RECIRC ISOL VLV handswitch to the PULL TO LOCK positio st IV [11J VERIFY the following: SG levels stabilized between 34 and 44%. 0 Reactor power stabilized between 1 and 2%. 0 Main Feed Pump in AUT Main Feed Reg Bypass Valves in AUTO (N/A if waived by plant manager or designee.). 0 (
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Page 21 of 24 Startup Number Unit _ _ Date _ Transferring Feedwater From Auxiliary To Main Feedwater (continued)
[12J VERIFY all motor driven AFW LeV controllers in AUT Initials Date Time IV Date Time [13] VERI FY all turbine driven ARN LCV controllers in NORMAL Initials Date Time IV Date Time NOTE All four reg. bypass valves shall be in AUTO and reactor power less than 2% prior to performing the next ste [14) IF fine tune of bypass reg. level controllers is required, THEN REQUEST IMs to perform MI-20.154 Controller Tuning Instructio o CAUTION After refueling operation, the NIS indications may be inaccurate until calibration at higher power levels has been performed . Reactor power shall NOT be allowed to exceed 4%
prior to the verification of the proper (or conservative) IR and PR setpoints. [C 2]
[15] MAINTAIN reactor power greater than 1% and less than or equal to 4%. o [1 6] CONTACT Reactor Engineering to determine if O-PI-NUC-092-082 should be performed prior to exceeding 4%
reacto r powe o (
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Page 22 of 24 Startup Number Unit _ _ Date _ Tra nsferr ing Feedwater From Aux iliary To Main Feedwa ter (co ntinued)
[17) IF initial restart after refueling and a low power flux map is required, THEN PERFORM applicable portions of the low power physics testing in accordance with O-RT-NUC-OOO-001 .0, Restart Test Progra Reactor Date Time Engineering [18J IF power escalation is desired, THEN GO TO O-GO-4, Power Ascension From Less Than 5%
Reactor Power To 30% Reactor Powe [19) IF Unit shutdown is desired, THEN GO TO O-GO-5, Power Reduction From 30% Reactor Power To Hot Standb End of Sect ion (
SQN POWER ASCE NSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Pane 23 of 24 RECORDS Completed copies shall be transmitted to the Operations Superintendent's Secretary.
(
(
SQN POWER ASCENSION FROM REACTOR 0-GO-3 Uni t 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 ( REACTOR POWER Pace 24 of 24 Source Notes (Page 1 of 1) Implementing Requirements Sta tement Source Document Statement Revise GO I-2 to require verification of NCO 890118002 intermediate range (IR) status at LER 328/8 9006S53 approximately 20 and 25 percent, 890531 844JRB to NRC verify source range (SR) status and chann el check at lower power, monitor core delta Ts at low-power levels and during power escalation and compare with NIS response and verify that the IR rod stop and trip bistables come in at the appropriate power level during power ascensio Following refueling operations SOER-90-003 relocation of NIS or modifications NCO 900107009 affect ing the NIS response, provide NER 1187001 ade quate reductions of trip setpoint LER 327/90 011 R1 ( and limita tions of reactor power until accura cy of the NIS is verified. Also provide alternate indications of power independent of calorimetric calculations during power ascension INPO SER on miscalibration of NIS SER 89-009NER 890252 Power Range detectors Revise GOI-2 prior to restarting Unit 2 LER 328/89005 CA to incorporat e industry Feedwater RIMS S53 890512 811 startup experience, add guidelines for RIMS L44 890505 805 each crew member, control the use of manual bypass control, add cautionary statements prior to important feedwater evolutions, and add hardware operability requirements for important feedwater evolution Consult Reactor Engineering for NER 89 07940ER 89 3497 guidance during evolutions of unusual power maneuvers at end of core life. }}