Text

April/May 2007 Exam Nos. 05000327-07-301, 05000328-07-301 - Final Scenarios & Outlines (Part 2 of 2)
	ML072980616
Person / Time
Site:	Sequoyah ; (DPR-077, DPR-079)
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)
	v • d • e

{{#Wiki_filter:( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pa!1e 81 of 93 Date _ ( 5.4 STARTUP No.

Unit __ Powe r Coastdown at End of Life (continued) [10.3] ENSURE that indicated T AVG and Megawatt readings are . acceptable.

[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).

END OF TEXT

( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 82 of 93 5.5 STARTUP No.

_ LOAD FOLLOW OPERATIONS Unit __ Date _ NOTE All load follow operations should be coordinated with Reactor Engineering for guidance concerning rod position, 1\\1limits, dilution/boration rate or quantity, and xenon worth. [C.5] [1] ENSURE Precautions and Limitations have been reviewed.

D NOTE Steps5.5[2] through 5.5[9] may be performed in any order.

[2] ENSURE HUTs have sufficient capacity for the dilution/boration process.

D [3] MAINTAIN TAVG on program. D [4] MONITOR S/G levels on program during the load change.

D [5] MONITOR pressurizer pressure and level.

D [6] MAINTAIN Axial Flux (1\\1) within its target band.

D [71 MONITOR all rod position indicators, group step counters, and power range channels during the load change.

D [81 ENSURE steam dumps in TAVG mode.

D [9] NOTIFY Chemistry Section to sample the boron concentration of the pressurizer and RCS.

D [1O] IF Chemistry 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 pressurizer and the RCS until Chemistry sampling has verified the difference to be less than 50 ppm.

D

( SON NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paqe 83 of 93 Date _ 5.5 STARTUP No.

Unit __ 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-030-415.0.

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 concentrations.

NOTE D ( 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 changed.

D NOTE Lowering load on the Main Generator will cause VARs to trend in the positive direction (toward outgoing). This will require lowering generator 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 S.

[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 escalation.

[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 5.5 STARTUP No.

Unit __ LOAD FOLLOW OPERATIONS (continued) NOTE Date _ 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 performance.

[15] INITIATE a turbine load reduction to the target load.

1st ev [16] MAINTAIN control rods above the low insertion limits or as directed by Reactor Engineering using boration of the ReS as load is reduced.

1st ev [17] HOLD the turbine at the projected load.

[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, OR [1 8.2] MOVE control bank outward when AFD is moving negative below target AFD, AND HOLD AFD at target until oscillation is suppressed.

[18.3] IF this basic first overtone control is insufficient, THEN ( CONTACT Reactor Engineering for assistance.

[19] MAINTAIN.Mwithin limits as xenon builds in by diluting Re S.

o 1st ev 1st ev o o o

( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Pane 85 of 93 5.5 STARTUP No.

Unit __ LOAD FOLLOW OPERATIONS (conti nued) Date _ NOTES 1) Refer to Step 5.5[14] and the associated note.

2) 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 performance.

[20] WHEN a turbine load ascension is required, THEN INITIATE a load ascension.

NOTE Xenon will burn out as load is increased.

o ( [21] HOLD the turbine at the projected load.

[22] MAINTAIN 1'.1within limits as xenon burns out by boration of the Re S.

[23] REPEAT portions of this instruction as required for changing loads.

END OF TEXT

( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 86 of 93 6.0 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 Appendix B (Page 1 of 2) TURBINE RUNBACK RESTORATION 1.0 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] ENSURE governor valve tracking meter is centered close to ZERO.

[3] DEPRESS the rrURB MANUALl mode selector pushbutton.

[3.1 ] VERIFY the [fURB MANUALl lamp LIT.

[3.2] VERIFY IOPER AUTOl iamp DARK.

[3.3] VERIFY reference and setter counters stabilize.

[4] ENSURE governor valve tracking meter is centered close to ~RO.

[5] DEPRESS IOPER AUTO] mode selector pushbutton.

[5.1] [5.2] [5.3] VERIFY IOPER AUTOl iamp LIT.

VERIFY rrURB MANUAL] lamp DARK.

VERIFY reference and setter counters stabiiize.

o o 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 Date _ 1.0 STARTUP No.

Unit __ 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 DARK.

[6.2] [6.3] INCREASE VALVE pas LIMITER setpoint to 10% above current load, ENSURING load does NOT change. GO TO step 1.0[8]. o o . [7J IF VALVE pas LIMIT light is DARK, THEN INCREASE the VALVE POSITION LIMITER setpoint to 10% above current load, ENSURING load does not change.

( [8J RETURN to instruction in effect.

END OF TEXT o

( ( ( SQN NORMAL POWER OPERATION O-GO-S Unit 1 & 2 Rev. 0047 Page 90 of 93 Appendix C (Page 1 of 1) ISOLATION OF MSR STARTUP VENTS 1.0 ISOLATION OF MSR STARTUP VENTS [1] ENSURE the following MSR startup vent isolation valves CLOSED : VALVE DESCRIPTION LOCATION POSITION INITIALS NUMBER MSR A-1 L.P.

HCV-6-2840 TB el. 732 MSR A-1 LP end CLOSED startup vent isol MSR A-1 H.P.

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 L.P.

HCV-6-2842 TB el. 732, MSR B-1 LP end CLOSED startup vent isol MSR B-1 H.P.

HCV-6-2843 TB el. 732, MSR B-1 HP end CLOSED startup vent isol HCV-6-2844 MSR C-1 L.P.

TB el. 732, MSR C-1 LP end CLOSED startup vent isol HCV-6-2845 MSR C-1 H.P.

TB el. 732, MSR C-1 HP end CLOSED startup vent isol MSR A-2 L.P.

U-1: TB el. 732, MSR A-2 LP end U-2: HCV-6-2846 CLOSED startup vent isol el. 706, S. Side Cond A, 12' up MSR A-2 H.P.

U-1: TB el. 732, MSR A-2 HP end U-2: CLOSED HCV-6-2847 startup vent isol el. 706, S. Side Cond A, 15' up MSR B-2 L.P.

U-1: TB el. 732, MSR B-2 LP end U-2: CLOSED HCV-6-2848 startup vent isol el. 706, S. Side Cond C, 15' up MSR B-2 H.P.

U-1: TB el. 732, MSR B-2 HP end U-2: CLOSED HCV-6-2849 startup vent isol el. 706, S, Side Cond B, 15' up MSR C-2 L.P.

TB el. 732, MSR C-2 LP end CLOSED HCV-6-2850 startup vent isol MSR C-2 HP.

U-1: TB el. 732, MSR C-2 HP end U-2: CLOSED HCV-6-285 1 el. 706, S. Side Cond A, 15' up startup vent isol

( ( SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Paae 91 of 93 Appendix 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 subsequently raised above these values if condensate pressure is adequate.

2) 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 guidance.

EQUIPMENT UNAVAILABLE RECOMMENDED REACTOR POWER VALUE One Hotwell Pump 75% One Cond Oemin Booster Pump No power reduction required provided all other pumps in service.

One Condensate Booster Pump No power reduction required for short-term operation without one CBP.

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) Requirements Statement Commitment made that during power increases, monitor NIS, L\\,T and calorimetries utilizing the highest for indication of reactor power. Also.

100% 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 corrective action for PRO 890638P.

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-6-106B.

Following refueling, relocating NIS or modifications affecting the NIS 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 ascension.

Source Document NER 89 0252 INPO SER 89-009 PRO-SOP 89 0638P NER 1187001 SOER-90-003 Implementing Statement C.1 C.2 c SQN NORMAL POWER OPERATION 0-GO-5 Unit 1 & 2 Rev. 0047 Page 93 of 93 Source Notes (Page 2 of 2) Requirements Statement Operations has evaluated the need to proceduralize the process for resetting the electrohydraulic control system following turbine runbacks. Steps for 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 Balance of Plant (BOP) runback.

Commitment made-that requires operations to request coastdown guidelines from Reactor Engineering.

Revise GOI-5 to monitor the Stator Ground Fault Relay 159GN3 during startup.

Required performance of 0-PI-SXX-000-022.1 and -022.2 and 1,2-SI-SXX-068-155.0 if startup is following a refueling.

Source Document LER 328/91001 S10910201894 NCO-91 0023003 S62 910226 839 NER 89 0794 OER 89-3497 II 90072 NER 970015001 WTB-96-007 Implementing Statement CA C,5 C.6 I Appendix 0 Scenario Outline Form ES-D-1 I ( ( Facility: Sequoyah Scenario No.:

Op Test No.: NRC Examiners: Operators: Initial Conditions: 75% Power.

SG BD Rad Monitor OOS B PZR Spray Valve Isolated BCCPOOS TDAFW Pump OOS, but running for return to service post-maintenance Turnover: Raise 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 No.

Mall. No.

Event Type" Event Description

SI02A C-RO/SRO CL Accumulator Nitrogen Leak.

T+5 TS-SRO

THR02 TS-SRO Chemistry reports high RCS activity.

T+15

RX1 2 I-RO First Stage Pressure Transmitter fails low.

T+20 TS-SRO

FW05 C-AII Feed Pump Trip; Power reduction required.

T+35

FW20 M-Ail Feedwater Header rupture; Reactor Trip. Feedwate r Isolation will T+55 terminate the feed line leakage.

TC04 C-BOP Main Turbine Auto Trip failure Main Steam Line Isolation Valves lail to close

RP02 C-RO 8 1actuation failure; Manual actuation required.

FW07A, M-AII TDAFW Pump trip FW09B A MDAFW Pump Trip: Faulty 50 Relay. pump current. discharge pressure, and flow decrease to S/Gs #1 & #2.

B MDAFW Fail to Auto Start: airbound pump which will have no discharge 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

( IAppendix D Scenario Outline Scenario 3 Summary Form ES-D-1 I ( The crew will assume the shift at 75% Power with instructions to raise power.

After turnover a Cold Leg Accumulator N2 leak will develop, requiring action to make up to the CLA, and technical specification entry for the SRO.

After technical 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 turbine 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 pressure mode. The SRO will enter technical specifications.

SUbsequently, a Main Feedwater Pump will trip, requiring a load reduction in accordance 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-O.

When the reactor trips, the turbine will fail to automatically trip and MSIVs fail to close automatically. The crew must manually close MSIVs to isolate the turbine.

Safety Injection will be required, but automatic initiation will fail, requiring manuai initiation.

The 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 manually started. The crew must recognize the pump is air-bound, and take action to restore it in accordance with FR-H.1.

The scenario may be terminated when "B" MDAFW Pump is restored or RCS Feed and Bleed is initiated.

EOP flow: E-O-FR-H.1 PSA significant component OOS: B CCP PSA significant transient: Loss of Feed PSA significant action: Recovery of AFW Appendix D NUREG 1021 Revision 9

ESG-3 SCN File 03/23/07 ( ( EVENT IC/MF/RF/OR # DESCRIPTION/EXPECTED ACTIOl'iSIBOOTH FEEDBACK Simulator IC-14 75%, BOL (-1000 MWD/MTUI IC 'B' Train work week CB ' D' Rods @ 185 steps, all others @ 228 steps; IB] = 1178 ppm; Ba Blender setting: 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 service.
Place I A-A CCP in servi ce and remove IB-B-Place I B-B CCP in P-T-L and tag with HO.
Place Loop I Spray valve in man ual and tag with Pink T ag.
Place Train W eek B slan MFs, RFs, lRF 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 active when IMF Ac'\\' OV 723 f:2 the SeN IMF RC06B f:O Loop I PZR Spray Valve Isolatcd (I-PCV-68-340D)

file is loaded.

IMF CVOIB f:1 m-n CCP OOS T DAFW Pump OOS, but r unning for post-maintenance testing: - TS LCOs 3.7.1.2.a for TD AFW pump. 3.3.3.7.18b action I; Accident Monitoring Instrumentation, ERCW to AFW Valve Position, Turbine Driven Pumps.

IMF TC04 f:1 Turbine Fails To (automatically] Trip; IM F RP02 f:l Safety Injection (SI) automatic actuation sij!ual failure; 1.

Il\\IF SI02A f:l k:1

1 CLA LO-PRESSURE; Prior to inserting Malfunction, ensure you can monitor CLA pressure.

DMF SI02A Delete malfunction when CLA pressure drops to < 624 psig.

Faulty relief valve corresponds to 10 psi/minute decrease at 500 psid CLA-containment pressure.

TS 3.5.1.1. action a should be referenced; Shutdown wli 24 hours per GO-5; 2.

IM F TH09 f:l k:2 Increase in activity released by core.

IRF THR02 f:2 Surmort staffreport: As Chemistry Supervisor: call US and notify him that sample results show Res specific activity is being determined (I OOIE microcuries/gram). Dose Equivalent 1-131 has increased to 55 microcuries/grum during the last 24 hours.

Ifsubsequent call requests recomm endations, the Lab suspects a fuel leak has developed and recommends placing mix bed and cation bed in service.

US refers to TS 3.4.8 & figure, determines shutdown is required.

This malfunction works in association with RCS activity remote function Page I of 3 G:\\Prep week files\\As Sub mitted Operational Exam'ScenartcsiScenarlo 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 activity.

THR02 will be overridden by the malfunction if the malfunction is active.

RF THR02 may be used to indicate core activity with TH09 active.

However, TH09 will have to be removed before remote function THR02 will regain control of RCS activity.

3.

IMF RXllB f:l k:3 PT-I-73, PIMP Ch 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 report to the Me R in - 45 minutes (WDpackage & briefing time).

Ch 1, 11'-1 -73 indicated on l-M-4; directly affects the load reference Tref-. MCR indications are also reflected in the system responds to the Tref program low failure; - Steam Dump Cant Sys: will ann D solenoid, but dumps will not open since they are not armed; - Rod Cant Sys: no-load value-54T F value; Rods will insert - SG LvI Cant Sys: no-load value-33% NR; - Crew may NOT place FWC in MANUAL, but may monitor AUTO control establish! control level at no-load value.

- 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 Instrument Malfunction.

4.

IMF FW05B f:l k:4 IB-B MFW pump trip due to an oil leak at the pressure transmitter.

Support stalfreport:

When personnel dispatched to investigate, wait - 3 minutes and report that oil line is leaking but is containable to this elevation/surrounding area.
IfEnvironmental Controls and/or Fire Protection personnel are dispatched, wait 5 minutesfor each and report on station and implementing appropriate supporting actions.

5.

IMF FW20 f:50 k:5 Feedwater line break in turbine building; failure of common header, downstream of # I FW Heater; 6.

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 results.

4.

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 later.

e:l SUfJIJort staffreport:

When personnel are dispatched to investigate, wait ~5 min. then report the T&Tvalve is closed, valve linkage separated.

7.

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 # DESCRIPTION/EXPECTED ACTIO NS/BOOT H FEEDBACK M-4 or M-6 HSs will manually actuate SI signal as required.

IMF RP16K616A f:l Automatic MSLI actuation signal failure; Il\\IF RP16K616B f:1 IMF RPI6K623A f:1 M-4 MSIV IISs will manually close MSIVs.

IMF RPI6K623B f:1 8.

IMF FW07A f:1 lA-A AFW Pump triplfail to start; lA-A AfW Pump Breaker has a faulty 50 relay and cannot be re-started; IMF FW09B f:1 1B-B AFW Pump AUTO-Start defeated; 1B-B MDAFWP will fail to start on any automatic 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; IMF 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 venting.

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 Pump.

ROLE PLAY: As AB AUO, after 4 minutes notify the MCR that the l B-B MD AFWPump has been vented and is ready to be returned to service.

Termination Criteria Restore feedwaterflo w via lB-B A FW Pump prior to reactor cooling via RCS feed/bleed as directed in FR-H,l.

Page 3 of 3 G:\\Prcp Weekfiles\\As Submitted Operational Exam\\Sccnarios\\Scenario3\\3-20-07 ESG-3.doc

I Appendix D Required Operator Actions Form ES-D-2 I c Op Test No.: NRC Scenario #

Event # Event Description: Cold Leg Accumulator Nitrogen Leak ....:..____ Page

of ..;2=:2=---1 Time I Position I Applicant's Actions or Behavior ( l Booth Instructor: When directed, initiate Event 1 Indications available: 1-AR-M6-D, A1, ACCUMULATOR TANK 1 PRESSURE HI-LOW RO Refer to alarm response procedure CHECK CLA digital pressure indication on [1-PIS-63-128] and RO [1 -PIS-63-126] (M-6).

IF CLA pressure is <624 psig OR >668 psig, THEN DECLARE RO the Accumulator inoperable.

ADJUST accumulator level and/or pressure in accordan ce with RO 1-S0-63-1, Cold Leg Injection Accumulators.

EVALUATE Technical Specifications, LCO 3.5.1.1 for applicability.

US

Enter Action a. if CLA pressure goes below 624 psig 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 # Event Description: Cold Leg Accumulator Nitrogen Leak ....:..___ _ Page

of -:2;=.2---1 Time I Position I Applicant's Actions or Behavior ( Do not cross connect the Cold Leg Accumulators.

CAUTION 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 complete.

RO ENSURE Valve Checklist 1-63-1.02 complete.

RO ENSURE Valve Checklist 1-63-1.06 complete.

RO VERIFY the following valves CLOSED: VALVE NUMBER FUNCTION RO 1-FCV-63-107 NO. 2 CL Accum N2 Supply Isol 1-FCV-63-87 NO. 3 CL Accum N2 Supply lsol 1-FCV-63-63 NO.4 CL Accum N2 Supply Isol RO OPEN [1 -FCV-63-64] N2 Supply to CL Accum.

Appendix 0 NUREG 1021 Revision 9

IAppendix 0 Required Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # Cold Leg Accumulator Nitrogen Leak -'-_ _ _ _ Page

of ..;2=:2=---I Time I Position I Applicant's Actions or Behavior ( IF Unit 1 nitrogen regulator 0-PCV-77-254 is INOPERABLE, THEN OPEN [0-77-865A] to align Unit 2 RO nitrogen regulator 0-PCV-77-253 to supply U-1 cold leg accumulators.

NOTE If CLA pressure is less than 600 psig, then temperature monitoring is required to prevent brittle fracture of nitrogen piping downstream of O-PCV-77-253 or -254.

IF Accumulator 1 pressure is less than 600 psig, THEN - PERFORM the following during pressurization:

MONITOR piping temperature downstream of [1 -63-705] using contact pyrometer.

IF piping temperature approaches 40°F, THEN RO THROTTLE [1-63-705] in close direction as necessary to maintain piping tempe rature greater than 40°F.
WHEN CLA #1 pressure is greater than 600 psig, THEN STOP temperature monitoring and OPEN [1-63-705] as desired.

(Not required) OPEN [1 -FCV-63-1 27] NO. 1 CL Accum N2 Supply isolation to RO admit nitrogen to accumulator.

NOTE Tech Spec operability range for CLA pressure is 624-668 psig.

RO WHEN CLA #1 pressure increases to desired value, THEN Appendix 0 NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

Event # Event Description: Cold Leg Accumulator Nitrogen Leak ....:...____ Page

of ....:2;;0 2---1 Time I Position I Applicant's Actions or Behavior c..

CLOSE [1-FCV-63-1 27].

CLOSE [1-FCV-63-64]. IF [1-63-705] was THROTTLED, THEN ENSURE [1-63-705] is RO FULLY OPEN.

IF [0-77-865A] was OPENED, THEN ENSURE [0-77-865A] is RO CLOSED.

- When Cold Leg Accumulator is within T5 pressure limits, the Lead Examiner may cue the next event Appendix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I c.

OpTest No.: NRC Scenario #

Event# 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 US Reviews Technical Specifications - Determin es TS action 3.4.8.a applies.

US MODES 1, 2 and 3* action a AND MODES 1, 2, 3, 4 and 5 action a US Enters AOP-R.06, High RCS Activity EVALUATE EPIP-1, Emergency Plan Ciassification Matrix.

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 Appendix D NUREG 1021 Revision 9

I Appendix D Reguired Operator Actions Form ES-D-2 I (, Op Test No.: NRC Scenario #

Event Description: High RCS Activity Event #

Time I Position I Aoolicant's Actions or Behavior ( Crew Prepare to perform plant shutdown When Technical Specification actions have been addressed, the Lead Examiner mav cue the next event Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I c OpTest No.: Event Description: NRC Scenario #

Event # _3::.....____ Page

Turbine First Stage PressureTransmitter PT 1-73 failure of

Time I Position I Aoolicant's Actions or Behavior ( ( Booth Instructor: When directed, initiate event 3 Indications available: 1-AR-M5-A, C6, TAVGffREF DEVIATION 1-AR-M5-A, B7, STEAM GEN LVL HIGH-LOW DEVIATION Crew Refer to alarm response procedures 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 bank movement: 1.

CHECK rod control: a.

ENSURErod 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 impulse 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 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I c Op Test No.: Event Description: NRC Scenario #

Event # ...;3::.-____ Page

Turbine First Stage PressureTransmitterPT 1-73 failure of

Time I Position I setpoint below 33% Steam Generator level.

Aoolicant's Actions Dr Behavior l Appendix D RO/BOP BOP CHECK PI-1-73 indicates normal.

PLACE rods in MAN.
EVALUATE placing Main Reg Valves in MAN to maintain SG level on program.

Operators may elect to leave FW Reg valves in auto, S/G will control at a lower level.

PLACE Steam Dumps in Steam Pressure Mode USING 0-SO-1-2, Steam Dump System.

[1] PLACE [HS-H 03Aj Steam Dump A FSV and [HS-1-1036j Steam Dump B FSV handswitches to OFF.

[2] PLACE [HS-1 -103Dj Steam Dump Mode selector to STEAM PRESS.

[3] VERIFY [XI-1-103A16l Steam Dumps Armed white light is LIT.

[4] IF [PIC-1 -33j Steam Dump Controller in MANUAL.

THEN ENSURE demand is Zero on controller.

[5] IF [PIC-1-33] Steam Dump controller in AUTO, THEN ADJUST setpoint to obtain zero output (demand).

[6) PLACE [HS-1-103Aj Steam Dump A FSV and [HS-1-103Bj Steam Dump B FSV handswitches to ON.

[7J ADJUST [PIC-1-33j Steam Dump controller to maintain desired steam pressure.

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 degrees of program:

POSITION control rods.

OR

ADJUST turbine load.

OR

ADJUST RCS boron concentration CHECK PI-1-72 indicates normal.

NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES*D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # -'3::....____ Page

Turbine First Stage Pressure Transmitter PT 1-73 failure of

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 bistables 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 operable status by resetting Eagle rack.

IF PI-1-72 or PI-1-73 has failed, THEN NOTIFY 1M to remove failed channel from service USING Appendix A, P-1-72 (P-US 506) OR Appendix B, P-1-73 (P-505) - EVALUATE the following Tech Specs for applicability: US

3.3.1.1 (3.3.1 ), Reactor Trip System Instrumentation (ACTION B.b applies) When Technical Specifications have been determined, the Lead Examiner may cue the next event Appendix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

Event # Event Description: Feed Pump B trip

Time I Position I Applicant's Actions or Behavior ( l Booth Instructor: When directed, initiate event 4 Indications available: SG levels trending down Main Feedwater flow lowering SG Level deviation alarms Crew Respond to lowering feedwater flow 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 required.

CHECK feedwater flow greater than steam flow.

IF steam flow reduction is needed, THEN PERFORM the following: BOP

REDUCE turbine load USING valve position limiter.

ENSURE control rods inserted as necessary to match T-avg and T-re!.

Appendix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

Event # 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 output.

MONITOR steam generator levels returning to program level.

BOP - CHECK reactor power less than 60%. ENSURE affected Main Feedwater Pump Turbine Condenser isolation valves CLOSED:

MFWP A BOP

FCV-2-205, Condensate Inlet

FCV-2-210, Condensate Outlet OR

MFWP B

FCV-2-211, Condensate Inlet

FCV-2-216, Condensate Outlet Crew ENSURE unit is returning to stable conditions.

US DISPATCH personnel to lnvestlqate MFW pump trip.

Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario # Feed Pump B trip

Event #

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 TAVG.
VERIFY c-r. LOSS OF LOAD INTERLOCK 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 B.

NOTE To ensure unit is within capacity of one MFWP, the following should be considered when determining final power level:

Power should be reduced below 60% (if all cond booster pumps and heater drain tank pumps 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-5.

Crew INITIATE repairs on affected equipment.

US When olant is stable, Lead Examiner may cue the next event Appendix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES*D*2 I Feed Header Rupture, Main Turbine fail to trip, Sl auto actuation failure, loss of feed ( Op Test No.: Event Description: NRC Scenario #

Event # 5.6.7,8 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 steps.

CRITICAL VERIFY turbine TRIPPED: TASK BOP Turbine stop valves CLOSED. (NO)

CLOSE MSIVs VERIFY at least one train of shutdown boards ENERGIZED.

BOP DETERMINE if SI actuated: RO

ECGS pumps RUNNING.

Any SI alarm LIT [M-4D]

Appendix 0 NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I Feed Header Rupture, Main Turbine fail to trip, Sl auto actuation failure, loss of feed c Op Test No.: Event Description: NRC Scenario #

Event # 5,6,7,8 Time I Position I Applicant's Actions or Behavior c . BOP PERFORM ES-0.5, Equipment Verifications WHILE continuing in this procedure.

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. RO c.

Attempt to restore feed - Determines that 1B MD AFW Pump is air bound and places HS in P-T-L and dispatches AUO to check and vent locally.

US Direct Entry to FR-H.1, Loss of Secondary Heat Sink CHECK the following: Total feed flow less than 440 gpm due to operator action directed by another procedure.

US AND Total feed flow capability of greater than 440 gpm AVAILABLE.

(NO) a. GO TO Step 2.

Appendix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I Feed Header Rupture, Main Turbine fail to trip, SI auto actuation failure, loss of feed ( Op Test No.: Event Description: NRC Scenario #

Event # 5,6,7,8 Time I Position I Applicant's Actions or Behavior ( MONITOR RWST level greater than 27%. RO Determines secondary heat sink required: RCS pressure greater than any non-Faulted S/G pressure.

Crew RCS Temperature greater than 350 MONITOR at least one CCP available.

RO - NOTE Pressu rizer pressure greater than or equal to 2335 psig with rising RCS temperature and a low loop delta-T indicates loss of heat removal capability.

MONITOR RCS feed and bleed criteria: CHECK the following:

Any three S/G wide range levels less than 20% [41 % Crew ADVj OR

Pressurizer pressure greater than or equal to 2335 psig due to loss of secondary heat removal.

MONITOR CST level greater than 5%. BOP Appen dix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I Feed Header Rupture, Main Turbine fail to trip, SI auto actuation failure, loss of feed ( Op Test No.: Event Description: NRC Scenario #

Event # S.6.7,8 Time T Position I Aoolicant's Actions or Behavior ( ATTEMPT to establish AFW flow to at least one S/G in the following order of priority-- Intact, Ruptured, Faulted :

CHECK S/G blowdown isolation valves CLOSED.

CHECK control room indications for cause of AFW BOP failure:

CST level

AFW pump power supply

AFW valve alignment May dispatch AUO to check AFW Pumps if not already dispatched.

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 criteria.

CRITICAL - ESTABLISH MD AFW pump flow: TASK ENSURE MD AFW pumps RUNNING.(NO)

DISPATCH personnel to restore MD AFW pump flow USING EA-3-10, Establishing Motor Driven AFW Flow.

BOP ENSURE AFW level control valves OPEN.

ENSURE MD AFW recirculation valves FCV*3-400 and FCV-3-401 CLOSED.

CHECK total flow to S/Gs greater than 440 gpm.

BOP US/RO Stops RCPs Scenario mav be terminated when MD AFW flow is established.

Appendix D NUREG 1021 Revision 9

(' Aooendix D Reauired Operator Actions Form ES-D-2 Op Test No.: NRC Scenario #

Event # ES-O.5 Page

of

- - Event Description: Equipment Verifications Tim e I Position I Applicant's Actions or Behavior ES-O.5 Actions CHECK ERCW system operation: BOP

VERIFY at least four ERCW pumps RUNNING.

VERIFY DIG ERCW supply valves OPEN.

VERIFY CCS pumps RUNNING:

Pump 1A-A (2A-A) - BOP

Pump 1B-B (2B-B)

Pump CoS.

VERIFY EGTS fans RUNNING.

BOP VERIFY generator breakers OPEN.

BOP CRITI CAL VERIFY AFW pumps RUNNING: TASK MD AFW pumps (NO) Must man ually start 1B-B MD

BOP AFWPump

TO AFW pump.

Appendix D NUREG 1021 Revision 9

( ( Aooendix D Reauired Ooerator Actions Form ES-D-2 Op Test No.: NRC Scenario #

Event # ES-0.5 Page

of

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 taken to control S/G levels, to establish flow due to failure, or to isolate a faulted S/G.

CHECK AF1N valve alignment: a. VERIFY MD AF1N LCVs in AUTO. BOP b.

VERIFY TO AF1N LCVs OPEN.

c.

VERIFY MD AF1N pump recirculation valves FCV-3-400 and FCV-3-401 CLOSED.

- VERIFY MF1N Isolation:

MFW pumps TRIPPED

MF1N regulating valves CLOSED BOP

MF1N regulating bypass valve controller outputs ZERO

MF1N isolation valves CLOSED

MF1N flow ZERO.

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 #

Event # ES-O.5 Page

of

-- Event Description: Equipment Verifications Time I Position I Applicant's Actions or Behavior VERIFY CCP flow through CCPIT.

CHECK RCS pressure less than 1500 psig.

BOP

VERIFY SI pump flow.

CHECK RCS pressure less than 300 psig.

VERIFY RHR pump flow.

VERIFY ESF systems ALIGN ED:

Phase A ACTUATED:

CONTAINMENT ISOLATION PHASE A TRAIN - A alarm LIT [M-6C, B5].

CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT [M-6C, B6].

Containment Ventilation Isolation ACTUATED:

CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M*6C, C5].

CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C, C6]. BOP

Status monitor panels:

6C DARK

6D DARK

6E LIT OUTSIDE outlined area

6H DARK

6J LIT.

Train A status panel 6K:

CNTMT VENT GREEN

PHASE A GREEN

Train B status panel 6L:

CNTMT VENT GREEN

PHASE A GREEN Appendix D NUREG 1021 Revision 9

( ( Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario #

Event # ES-O.5 Page

of

-- Event Description: Equipment Verifications Time I Position I Acc licant's Actions or Behavior MONITOR containment spray NOT required:

Phase B NOT ACTUATED BOP AND

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 personnel to perform EA-O-1, Equipment Checks BOP Following ESF Actuation.

Appendix D NUREG 1021 Revision 9

.~:::\\:<~~,?)e(Jma,tY:tQ'~§~~9n~atYJ.l..:~~.kr~~e * H1f~*!m~ti9r(<T<?tEl,I;.~.PM 1,!~M799:"~,~!.1 ;~.~l: :',j,:C' " \\I.. .....

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-, Indicator Units U1 Date I Time U2 DatelTime 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-GQal,"',:";~~i.;-'::,":M idpoJn*t . - ...;. - ~:- ~ ....:..

._.* *-"L--.*

. .~_!.. . 1>

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ppm 1.1 Today / Now >1 >1 ppm 2.43 Today / Now 2.18-2.48 2.33 SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now S1137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 229 Today / Now

Today / Now 15 gpd (30 min increase) cpm 567 Today / Now

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

Today / Now 12.5 Today / Now Bkgd on 99/119 cfm

Today / Now

Today / Now (

SHIFT TURNOVER CHECKLIST [8J SM [8J US/MCR [8J UO o AUO [8J STA (STA Function) Page 1 of 3 Unit

'---

Unit

'---

Station SON

AUO Comp Actions Today Off-going - Name 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-4.

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-12.

None (

II AUXILIARY BUILDING (7775) (593-5414)

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 leak.

Tech Support and MMG determined and completed repairs necessary. Post maintenance testing is in progress.

Res Leakage (SI-137.0) Total 0.03 gpm I Identified 0.02gpm I Unidentified 0.01 gpm. (Today 0600) I I

SHIFT TURNOVER CHECKLIST Page 2 of 3 Today ( 51fTest in Progress/Planned: (Including Need for New Brief)

51-401 release package (wi Chem Supvr) for SGBD releases to the river.

U1 TDAFW Pump post-maintenance testing is in progress.

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 problem.

Maintain current plant conditions until evaluation is complete.

Radiological Changes in Plant During Shift:

NONE expected.

l ~ft'~- : J;'; t};t:':l;} ~~'~ - 'jC!' ~3;:,; \\~t :!;,H'~ i~ ~ - ", -*~ j_

LCO/ODCMfTRM ACTIONS ]:;';

- j, ;,; ,".,, ;,,~ --' ; - '-;'1';<

";X,c

-- -',;" 'j-j. " ",

TS 3.5.2.a, TRM 3.1.2.2. for 1B-B CCP 005.

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 Orders D LCO(s) in Actions (N/A for AUOs) D Immediate 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 Controller Setting law 0-50-62-7 section 5.1 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

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 assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until three weeks from now.

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 ago.

Next Unit 1 Flux Map is scheduled-three weeks from now ( Jnit Supervisor: Name/Date

Operations Chemistry Information ( .;;.. ~%::o.;<.; ",...;,. ".8 '....R . It c,,,,',,";!,.' 't.v*,,':* " ... ". oron esu s ,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

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U1 RCS ppm 1.1 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 Units 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 < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent epm 229 Today / Now

Today / Now 15 gpd (30 min increase) cpm 567 Today / Now

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

Today / Now 12.5 Today / Now Bkgd on 99/119 ctrn

Today / Now

Today / Now (,

SHIFT TURNOVER CHECKLIST Page 1 of 3 Today r ( Train a Week

1-PCV-68-340D Valve Controller is drifting; (WO 06-080000-000). Pink tag on 1-M-4.

l8] SM l8] US/Me R Unit

[8) UO Unit

Off-going - Name

AUG Station SON t8J STA (STA Function) AUO Comp Actions On-comlnq - Name Part 1. Completed by OH-going ShiftJReviewed by On-coming Shift: Abnormal Equ ipment Lineup/Conditions: ':. "' *~ ~::;'ll** :;*!* "Il!t*~* :,-: 7.... *J '~t~........ *J .......".~

.r....ro-: ..l-:.' -... ~ *.

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,,~;,r, :..~.'...c*..:~*.;;:~<.:-,.*.' MAJN*CONtROL*ilbbM{7,69dJ'(~5409) "-* -,~A;J;) ;;'* ::*'': :.:.~. ~:~*. !,;\\ -. '-1~" :\\~~-i~'m";,'H~* *

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_ -T:" ... _ ****~ _... _ _ *~_tJ ~":' ....,~~~-:f),o.~...t ..-f.. ~... }....~.. a......~.'/'

1-RM-90-120&121 SG aD Rad Monitor 005; Investiga te th e pump/instrument failure (Wa 06-080880-000). Pink tag on 1-M-12.

None AUXILIARY BUILDING (7775) (593-5414)

CCP 1a-a Out of Service: 005 for previo us 8 hrs. to repa ir leakage on pump discharge; exp ected 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 leak.

Tech Support and MMG determined and completed repairs necessary. Post maintenance testing is in progress.

Re s Leakage (SI-137.0) I Total 0.03 gpm / Identified 0.02gpm / 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 river.

U1 TDAFW Pump post-maintenance testing is in progress.

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 problem.

Maintain current plant conditions until evaluation is complete.

Radiological Changes in Plant During Shift:

NONE expected.

1',:'-,: *;;*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 005.

TS 3.7.1.2.a for TDAFWPp

ODCM 1.1.1 action 31 for 1-RM*90-1201121 005 Part 2 - Performed by on-co ming 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 Walkdown 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 Dis abled Annunciators Today PANEL WINDOW ANNUNCIATOR.

WO I PER Number ( Eouipment Off* Normal (Pink Taqs) UNID And Noun Name Panel Problem Description WO I PER Numbe r -- MCRWO LIST ( ID And Noun Name Panel Probl em 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 I 65 gallons of water

Venfy boric acid flow controller IS set at Adjusted BA Controller Settinq law 0-SO-62-7 section 5.1 Gallons of acid: 25 Gallons of water: 119 Rod Steps: 2

....-:

...

~'..*..*: ~;-;: ;:,:-< E*st i rriate d 'rods/boron' for'emergency step power reduction ~~

<~ :.~ ~;: '..; ':~~:;,;, " :.~~. ',~_ ~ '.':' '!.. ..... -." ". ...~.-...., - " .... ~ ..... :

-

'.. ** **. *~...- . ">.1 ...

~. ~ . ~t . -. (:':'- <t.*. /. (Assuming Xenon equilibrium and no reactivity eHeets due to Xenon, 2/3 total reactivity from rods,'1/3 from"boron) ' ",:';::: ".,:~ Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 175 Steps on bank D

gallons 30% 154 Steps on bank D 280 gallons 50% - 129 Steps on bank D 474 gallons -

- These 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 operation only. Engineering data last updated one week ago. Data Valid until three weeks from now.

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 ago.

Next Unit 1 Flux Map is scheduled-three weeks from now Jnit Supervisor: Name/Date

I

I Operations Chemistry Information ( \\. Sample Point U1 RCS U2 RCS U1 RWST U2 RWST BAT A BATB BATC U1 CLA #1 U1 CLA#2 U1 CLA #3 U1 CLA #4 U2 CLA #1 U2 CLA #2 U2 CLA #3 U2 CLA #4 Spent Fuel Pool

0f~¥~!(,T~ ;~~:i};~::i:~:: ~; ~', :'>'" :H:~~g!1~7'v~4~ ~~~s ". :,:i'*:i~":;~ ", ;

Units Boron Date I Time ppm 1178 Today / Now ppm 816 Today / Now ppm 2601 Today / Now ppm 2569 Today / Now ppm 6850 Today / Now ppm 6850 Today / Now ppm 6850 Today / Now ppm 2556 Today / Now ppm 2575 Today / Now ppm 2591 Today / Now ppm 2589 Today / Now ppm 2531 Today / Now ppm 2650 Today / Now ppm 2522 Today / Now ppm 2526 Today / Now ppm 2547 Today / Now

~\\;;*~E~~~:~;~;m~!5.~~,~1ts '~.t:t~~frlj~?;~li;r~X: *.': ": :~....'::'::;'\\.:~t; ;,;;

ppm 1.1 Today Now ppm 2.43 Today / Now Goal Limit Variable Variable Variable Variable 2550*2650 2500 - 2700 2550 - 2650 2500 - 2700 Variable Variable Variable Variable Variable Variable 2470-2630 2400-2700 2470*2630 2400-2700 2470-2630 2400-2700 2470-2630 2400*2700 2470*2630 2400-2700 2470-2630 2400-2700 2470*2630 2400-2700 2470-2630 2400-2700 ~ 2050 ~2000 ",9()~Jl{{~iiki~;0 ;~(,..:' ;/}~1t2P'~J.n~~, *. :X~; >1 >1 2.18-2.48 2.33 .;'Y2, :;tt>/: :::;!:q{;EI~m~lj;,~,Ci;§;~§8:tlg~K~\\~a~,~:~~*~::l~1?0~m.~tion::<:Ig!~!. c,p.~ R~:~~"q;~~U} ~),'.."",.. Indicator 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 < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 229 Today / Now

Today / Now 15 gpd (30 min increase) cpm 567 Today / Now

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 CVE Air Inleakage cfm

Today / Now 12.5 Today / Now Bkgd on 99/119 cfm

Today / Now

Today / Now (

! * ,*. SHIFT TURNOVER CHECKLIST Page 1 of 3 Today ( [gJ SM [gJ US/MCR Unit

~ UO Unit

Off-going - Name

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 Shift: 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;:: -;~~ ~

,.<"' 1"':"" '" '~"<")'Y' ~ v. '>-.';f~ v ~ I* :';'it.",; "r,, ;" '.' " :'..'MAIN CONTROL'ROOM(7690r(59~5409)-,.' (.,'~~,.,, {.<r., ': "YO)' .. ~v : ' '- ' ',""..' ',~'I.\\!.. \\" :... ~~..("

~~:~:".li~ t~.~:.t..~~~,;. l~~.;.(~~~**~~.,.Ji.4~l:~. ; ~ ~ * :';,,".,~">.:

'0 '.' . ,. *

,,'

.- '. '- 0/ 1 " "~' \\...__ -.-. . ~., . _ _,',... ~ ... ~:;=.. ~"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-4.

1-RM-90-120&121 SG BD Rad Monitor 005; Investigate the pump/instrument failure (WO 06-080880-000). Pink tag on 1-M-12.

( AUXILIARY BUILDING (7775) (593-5414)

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 leak.

Tech Support and MMG determined and completed repairs necessary. Post maintenance testing is in progress.

Res Leakage (SI-137.0) Total 0.03 gpm /Identified 0.02gpm / Unidentified 0.01 gpm. (Today 0600) I

'-' ... 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 river.

U1 TDAFW Pump post-maintenance testing is in progress.

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 problem.

Maintain current plant conditions until evaluation is complete.

Radiological Changes in Plant During Shift:

NONE expected.

I~~? ;:;~ :' :".~'.'" >.,.

'. <. :'.~'? ' "; "~..':~::,;"...';."').;" :,,:,,", :.:, ' LCO/ODCMfTRM ACTlbNS ' ~' J. '.:.".: '>~ l:~i;: :~<'.,:~::1~~5*jt;::~~.~/?:~~: :r;~\\:?::~~ *~~'. :. ~~~.~~':~~?': :; ::~;~:..:.. I

, N ~ '.. ';.,."}.:' ;. t:,'>:~~*..~ >.'.. ~~.

'::~ ~~ -,

- ,

TS 3.5.2.a, TRM 3.1.2.2. for 1B-B CCP 005.

TS 3.7.1.2.8 tor TDAFWPp I

ODCM 1.1.1 action 31 for 1-RM-90-1201121 005 Part 2 - Perfor med by on-coming shift

Review of Operating Log Since Last Shift Held or 3 Days. Whichever is Less (N/A for AUO's)

Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs lor Changes Since Last Shift Turnover:

Standing Orders

LCO(s) in Actions (N/A lor AUOs)

Immediate Required Reading

TACF (N/A for AUO's) Part 3 - Performed by bo th off-going and on-co ming shift

Walkdown 01 MCR Control Boards (N/A lor AUO's) Relief Time : Relief Date: today ( TVA 40741 [03-2001] OPDP-1-1 [03-14-2001

.

( SHIFT TURNOVER CHECKLIST Page 3 of 3 Disabled Annunciators Today PANEL WINDOW ANNUNCIATOR. Equipment Off-Normal (Pink Tags) WO I PER Number ( UNID And Noun Name Panel Problem Description w e I PER Number -_.

MCR we LIST ID And Noun Name Panel Probl em Description WOlPER Number

I ( UNIT ONE REACTIVITY BRIEF Date: Today Time: Now Verify boric acid flow controller IS set at Adjusted SA Controller Setting law 0-50 -62-7 section 5.1 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 . Gallons of acid: 25 Gallons of water: 119 Rod Steps: 2 .,.~:/.,./:~.":;.::" . :.V~\\~::~*:.~~~! ~:la~~e. rp'd5/bor~~.fp r emergency step power r~~u~tion' ~~.:: ";"~ S ;~rs~ \\~~:\\~~,:~;.:~ ~:~_ .,: '; -~J..:.... (Assuming Xenon eqUlhbnurn and no reactivity eHects due to Xenon. 2/3 total reactivity from rods,.1/3 from boron) ~. " ~ ';'.\\.,: >. Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 175 Steps on bank 0

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 now.

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% MWO/MTU - 1000 Xenon - 2538 PCM Equilibrium Samarium -1019 PCM Last Dilution Complete -1 hour ago.

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 ( c '. Facility: Sequoyah Scenario No.:

Op Test No.: NRC Examiners: Operators: Initial Conditi ons: 10.3 % power or higher in Intermediate Range Turnover: Raise Power to POAH.

Target CTs: Start at least 1 EDG prior to placing equipment in PTL in ECA-O.O Start at least 1 CCP prior to completion of E-O Start CCS Pump 1A-A prior to completion of E-O Event No.

Mall. No.

Event Type' Event Description

R-RO Raise power T+O

RC05 C-RO/SRO PORV 68-334 Leakage - Tech Spec evaluation - T+10 TS-SRO

CV09 I-RO/SRO VCT Level Channel 130 fails high T+20

CC1 0B C-BOP/SRO 1B-B CCS Pump trip and failure of backup pump auto start ; Manual start T+30 CC09A-of backup required pre-insert

CC05A C-BOP/SRO RCP TBHX Supply Line Leak.

T+40

TS-SRO Call from Engineering - SI Pumps 1A-A and 1B-B are found to have the T+55 wrong grade of lube oil, affecting operability of both pumps.

TH02C M-AII SBLOCA resulting in reactor trip and safety injection.

T+60

EDOl M-AII Loss of Off-Site Power resulting in a ioss of power to both 6.9 KV Shutdown Boards.

EG03A-C-BOP lA-A EDG fails to start in auto pre-insert 1B-B EDG trips and cannot be started EG02B-pre-insert

SI01A C-RO 1A-A 81 Pump Trip Cv35a=-1 1A-A CCP fails to auto start , (N)orma l, (R)eactivlty, (I)nstrument, (C)omponent, (M)ajor Appe ndix D NUREG 1021 Revision 9

( '. IAppendix D Scenario Outline Scenario 4 Summary Form ES-D-1 ( The crew will assume the shift with the unit in a startup, power in the Intermediate Range, with instructions to continue raising power to the Point of Adding Heat After the RO raises power, PORV 68-334 will leak, requiring the crew to close the associated PORV Block Valve to isolate the leak. Technical Specification actions apply.

When the plant is stable, VCT level transmitter 130 will fail high, requiring the RO to manually control VCT level by stopping the diversion of letdown.

When VCT level is stable, 1B*B CCS Pump will trip. The backup pump will fail to automatically start, and must be manually started in accordance with AOP-M.03.

When the standby CCS pump is running, an RCP Thermal Barrier Heat Exchanger supply line leak will develop. The crew will respond in accordance with AOP-R.05.

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 from 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 start, and must be started manually. 1B-B EDG trips and cannot be started.

The crew must start 1A-A EDG and place it on the bus to avoid entering ECA-O.O and performing the coping steps.

Additionally, 1A-A SI Pump trips and 1A-A CCP fails to auto start. Starting the pump is critical to a SBLOCA with the 1B-B CCP unavailable due to loss of power. Starting CCS Pump 1A-A is also critical to the continued operation 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 completion of FR-Z.1 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 03/23/07 ( ( EVENT IC/MF/RF/OR # DESCRIPTION/EXPECTED ACTIONSIBOOTH FEEDBACK Simulator IC-97 IC - 10-3%, BOL [-1000 I\\IWD/I\\ITUI CB ' 0 ' Rods @ 150 steps, all others @ 228 steps; [BI =17IIppm; Ba Blender setting: 48% Xe/Sm equilihrium Console Operator actions: Place simulator ill run and perform the Isllssiss:

Place the 1\\1ODE 2 sign on 1-1\\1-4
Place Train Week B sign MFs, RFs, IM F CC09A f: I lA-A CCS Defeat Pump Auto-Start DRsare II\\IF EDO I f:I d:30 Loss of Off-Site Power resulting in a loss of power to both 6.9 KV Shutdown active when the e:I Boards.

seNtile is l;\\lF EG08A f:1 lA-A EDG fails to start in AUTOMATIC; loaded.

II\\IF EGOm f:1 1B-B EDG trios and cannot be re-started; 1;\\11' SIOI A f:1 lA-A SI Pump trips on auto start.

set yp_cv35a=-1 1A-A CCP fails to auto start-CONSOLE NOTE: cannot sec status on malfunction screen. Will require sim svs to verifv malfunction is active.

I.

_.

Raise Power to POAH.

2.

IMF RC05 f:5 k:2 I-FCV-68-334 Fails 5% Op en; Pressurizer PORV fails open; TS evaluation; Support staf]'renort: IfAUOs dispatched to remove powerfrom POR I' Block Valve, 1-FCV-68-333, wait - 3 minutes and use the remote/ unction RCR041:0 to remove powerfrom the block valve.

3_ 1MF CV09 1': I k:3 VCT Level Ch 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 malfunction was activated; - Auto makeup to VCT is defeated; - CVCS VCT to RWST low-level transfer is defeated.

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 minutes.

4.

IM F CCIOB 1':1 IB-B CCS Pump trip; TS evaluation; k:4 Support sta([report: When personnel dispatched, wait - 3 minutes then report motor hot to the touch, burned electrical insulation smell at the CCS Pump 1I10tor.

IMF CC09A 1': I IA-A CCS Pump auto start failure; Manual start required; (pre-insert) The lA pump will fail to start on a blackout, SI or low pressure signals; Manual start is available.

Page I of 2 G:\\Prep Week files\\As Submitted Oper ational E:u m\\Sccnari os\\Scenal'"io 4\\.' -21-07 ESG-4.doe

ESG-4 SC N File 03 /23/07 ( ( EVENT IC /MF/RF/OR # DESCRIPTlOi'/EXPECT ED ACTIO NS/BO OT H FEEDBACK 5.

IMF CC05A f:l

1 RCP TBHX CCS Leak@ - 200 gpm; TS evaluation; k:5 Component Cooling Pipe Break Inside Containment; #1 RCP thermal 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 ofCCS water to containment w/ surge tank level decrease and containment sump level increase.

6.

ROLE PLAY: As Engineering -Call MCR and inform SRO that stPumps tA-A and IB-B arefo und to huve the IITOllg grade of/ube oil. affecting cperobillty ofboth pumps.

7.

D lF TH02C f:.09 SBLOCA resulting in reactor trip and safety inj ection; k:7 Small RCS Leak on LOOD 3; S.

IM F EDOI f:1 d:30 Tota 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.OI when Step 9 CA restoration is completed.

9.

I!\\-IF EGOSAf: I IA-A EDG fails to sta rt in auto; - Start at least I EDG prior to placing equipment in PTL in ECA-O.O l A-A EDG fails to start from a SI Signal, 6.9KV SDBd BIO or UV; M-26A and L-4A emergency manual start PBs an d M-l emergency start liS remain operable; Mannal EDG start is active from these locations with this malfunction active.

IMF EG02B f:l 1B-B EDG trips and cannot be started; EDG current differential relay trips. locks out output breaker 1912; 6.9kY SDBd IA-A is not damaged by the malfunction; 10.

set yp_cv35a-l lA-A Cent rifugal Charging Pump (CCP) Auto Start Failure; (Malfunction is pre-inserted) Manual CCP starting is available to the operator.

IRF IAR12 f:l k:9 RESET Control Air CompoTRIPS. HS-32-25B IRF lAR02f:l k:9 AIR COMP-B Local Operation - ON d: 30 When requested by crew lAWEA-32-2; NOTE: Only IA CA Compressor is available; IRF IAR06 f:2 OPENS FCV-32-80, 102, & 110 after all isolation signals reset.

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.OI; U2 will d:60 k:l0 accept/complete AOP*P.OI after Step 9. CA restoration is completed.

Termination Criteria Complete ES-I.2 Step 14, RCS cooldown initiated.

PaRI: 2 of 2 G:\\Prep Week files\\As Submitted Operational Exam'Scenarios'Scenario ~ \\3* 2I -0 7 ESC-4.doc

IAppendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # Raise Power -'-____ Page

of _ 3:::2=--; Time I Position I Aoolicanf s Actions or Behavior ( ( Booth Instructor: No action required fo r Event 1 Indications available: None. Crew will perform startup lAW O-GO-3, Section 5.2 NOTE Average 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 monitored.

(REFER TO 0-SO-1-2 tor steam dump demand program.)

RO WITHDRAW RODS OR DILUTE to bring reactor power to between 1 and 2% RTP, while continuina with this instruction.

NOTE After refueling 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 calorimetric calculations). If significant differences occur (approx. 5%) between the alternate power indications then Engineering should be notified.

IF startup is after a refueling or maintenance on NIS, THEN INITIATE performance of 0-PI-OPS-000-001.0, Initial Startup System Parameter Log. COMPARE NIS power range US instrumentation with loop eT indicators and steam dump demand to evaluate accuracy of PRMs.

This SteD N/A SELECT the highest reading IRM or ""I and PRM channels to RO be recorded on NR 45.

Crew REVIEW plant parameters and indications to determine plant stabilitv prior to startup of Main Feed Pump.

Appendix D NUREG 1021 Revision 9

I Append ix D Reguired Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event ~ Raise Power -'- Page

of _ 3:;::2'---1 Time I Position I Aoolicant's Actions or Behavior ( ( MAINTAIN reactor power approximately 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], BOP AFW PUMP A RECIRC ISOL VLV, and PLACE handswitch [HS-3-400A] in the PULL TO LOCK position.

WHEN total Aux FW flow to SGs 3 and 4 is constant and greater than or equal to 300 gpm, THEN CLOSE [FCV-3-401], BOP AFW PUMP B RECIRC ISOL VLV, and PLACE handswitch [HS-3-401A] in the PULL TO LOCK position.

NOTE Control rod bank D should be <165 steps at steady state power levels below 85% RTP.

This guidance is to preclude long-term operation at <165 steps to avoid potential impact on safety analysis assumptions. Short-term operation at <165 steps is NOT a concern.

RO ENSURE the plant is stabilized between 1 and 2% reactor Dower.

RO COMPARE NIS intermediate range instrumentation with loop ~T indications to evaluate accuracv of IRMs.

RO RECORD IRM readings: N35 % RTP N36 % RTP When power has been raised sufficiently to record a reactivity manipulati on, lead examiner may cue the next event Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Fo rm ES-D-2 I C' " Op Test No.: Event Description: NRC Scenario #

PORV 68*334 Leakage Event #

of

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 ( Appendix D Crew Crew Resp ond in ac cordan ce with Alarm Respon se Procedures (AOP-R.OS Sect 2.1 Step 10.c RNO actions are similar to ARP actions; see following) US may use or refer to AOP-R.05, RCS Leakage Identification Section 2.1 Small Reactor Coolant System Leak: 1.

CONTROL charging flow to maintain pzr level on program.

2.

MONITOR pzr level >10% & STABLE or RISING.

3.

MAINTAIN VCT level with make up.

4.

MONITOR containment pressure STABLE or DROPPING.

5.

MONITOR RCS pressu re STABLE or RISING.

6.

CHECK secondary side radiation NORMAL 7.

CHECK leak inside containment 8.

CHECK containment airborne activity RISING (RM-90-106 or 112) 9.

ENSURE containment purging and venting STOPPED: 10. DETERMINE leakage source: a.

CHECK leakage source UNKNOWN (YES) b.

ISOLATE letdown and charging (YES) c.

CHECK pressurizer PORVs NORMAL (NO)

Tailpipe temperature (elevated)

Acoustic monitors (elevated) Go to RNO NUREG 1021 Revision 9

Required Operator Actions Form ES-D-2 I c I Appendix D Op Test No.: Event Description: NRC Scenario #

PORV 68-334 Leakage Event #

of

Time I Position I Aoolicant's Actions or Behavior c Evaluator Note: The following steps are from the ARP. AOP-R.05 Sect 2.1 Step 10.c RNO actions are similar.

IF PZR pressure is less than 2315 psig (PORV reset) THEN ENSURE both power relief valves closed.

RO

RO attempts to close but has no position indication.

RO closes block valve 333 CHECK temperature on PORV discharge line to determine 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 CHECK 1-XX-68-363A "PZR PORV ACCOUSTIC MONITORS (M-4) to determine which PORV or safety valve is leaking.

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 Evaluator Note: t-hour Tech Spec to close and de-energize the associated PORV Block Valve. Ensure action is addresse d.

Lead Examiner may cue next event when Technical Specifications are addressed.

Appendix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # VCT level transmitter 130 fails high

Time I Position I Applicant's Actions or Behavior ( Booth Instructor: When directed, initiate Event 3 Indications available: 1-AR-M6-C-A3, LS-62-129A1B VOLUME CONTROL TANK LEVEL HI-LOW 1-LT-62-130 Indication failing high Crew Respond to alarm response procedure Note: If actual level is permitted to become low, charging pump gas intrusion could occur.

Evaluator Note: There are several notes in the alarm response that do not apply to this failure. The notes listed are the ones that do apply. There are several sections of procedure steps.

ONLY the applicable step (step 3) is listed in this guide.

NOTE 2 High failure of 1-LT-62-129A will divert letdown flow with NO affect on Auto makeup.

NOTE 3 High failure of 1-LT-62-130A will divert letdown and prevent Auto makeup. 1-L1-62-129 will indicate actual level.

Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES*D*2 I ( Op Test No.: Event Description : NRC Scenario #

Event # 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 level.

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>>

Event >>

Event Description: CCS Pump Trip. Manual start of backup required Time I Position I Applicant's Actions or Behavior ( Booth Instructor: When directed, Initiate Event 4 Indications 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 indication on 1B-B CCS Pump (Red light off, Green and white lights off) Crew Responds to alarm response procedure(s) US Enter AOP-M.03, Loss of Component Cooling Water US Determine section 2.1 applies (CCS Pump Trip or Failure) CAUTION: The Containment Spray Pumps may experience bearing failure after 10 minutes of loss of CCS cooling.

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 SRO.

Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I CCS Pump Trip. Manual start of backup required ( Op Test No.: Event Description: NRC Scenario #

Event #

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 evaluated to be OPERABLE and AVAILABLE.

These pumps can run indefinitely without CCS cooling water to mechanical 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 US Go to Step 10 IDENTIFY and LOCK OUT failed CCS Pump.

CAUTIONS:

Loss of component cooling water flow to the RCP motor, requires RCP be stopped within two (2) minutes.

Containment Spray Pumps may experience bearing failure during operation after 10 minutes of loss of CCS coolina.

Appendix D NUREG 1021 Revision 9

IAppendix 0 Required Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # _4.:....-____ Page

CCS Pump Trip. Manual start of backup required of

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 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 SRO.

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 OPERABLE and AVAILABLE.

These pumps can run indefinitely without CCS cooling water to mechanical seal HXs ENSURE affected Unit's standby CCS Pump (aligned to Train BOP A) RUNNING.

Must manuallv start CCS Pump 1A-A CHECK Train A CCS Heat Exchanger inlet pressure NORMAL for present plant conditions.

[1-PI-70-24A, 1A1/1A2 CCS HXj BOP [2-PI-70-17A, 2A1/2A2 CCS HXl

Between 87 psig and 110 psig Determines pressure aoorcxlrnatelv 105 ps ia US Go to Procedure and step in effect Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I CCS Pump Trip. Manual start of backup required ( Op Test No.: Event Description: NRC Scenario #

Event #

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 RO handswitch 1-62-79Ain the DEMIN position when ces is 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 #

Event # 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 procedures Evaluator Note: Crew may start a second Thermal Barrier Booster Pump per the ARP; US Go to AOP-M.03, Loss of Compon ent Cooling Water US Determine Section 2.3 applies CAUTION: During operation, the Containment Spray Pumps may experience bearing failure after 10 minutes of a loss of CCS cooling.

Appendix 0 NUREG 1021 Revision 9

Reguired Operator Actions c I Appendix D Op Test No.: Event Description: NRC Scenario #

Event # TBHX Supply Line break

Form ES-D-2 I 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 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 SRO.

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 OPERABLE and AVAILABLE.

These pumps can run indefinitely without CCS cooling water to mechanical seal HXs MONITOR REACTOR COOLANT PUMPS MOTOR THRUST BOP BEARING TEMP HIGH annunciator DARK [M-5B, E-3]. DISPATCH operators with radios to Aux Bldg to locate failure US/BOP and perform valve manipulations.

DISPATCH an operator with radio to perform Appendix A, US/BOP Operation of Appendix R Valves Required by Section 2.3.

ENSURE all affected Unit's CCS Pumps RUNNING.

BOP Appendix D NUREG 1021 Revision 9

I Appendix 0 Required Operator Actions Form ES-O-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # TBHX Supply Line break

Time I Position I Aoolicant's Actions or Behavior ( ( CHECK ERCW flows NORMAL for 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 baffle prevents the "B" train from draining to less than 57% indicated level.

- MONITOR Train A CCS surge tank level between 65% and 85%. BOP

1(2)-L1-70-63A, Unit 1(2) A CCS Surge Tank Level.

ENSURE surge tank auto makeup starts at 64% level.

BOP MONITO 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.

Appendix 0 NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I ( Op TestNo.: Event Description: NRC Scenario #

Event # TBHX Supply Line break

Time I Position I Aoolicant's Actions or Behavior MONITOR Rx Bldg Supply Hdr flow NORMAL [1,2-FI-70- 142]. BOP

Between 800 gpm and 1100 gpm without Excess Letdown

Between 900 corn and 1300 oom with Excess Letdown NOTE: With RCP oil coolers isolated, 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 Barrier Return Flow NORMAL BOP [1,2-FI-70-81] (160 - 200 gpm).

Flow Indicates aceroxlmatelv 135 GPM IF indications of abnormal flow exist OR CCS to Thermal Barrier Heat Exchangers has isolated, THEN PERFORM the following for the affected Unit: a.

STOP and LOCK OUT affected Unit's Thermal Barrier Booster Pumps.

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 NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I ( '- Op Test No.: NRC Scenario #

Event # Event Description: TBHX Supply Line break

of

Time I Position I Aoolicant's Actions or Behavior ( ( CAUTION: Isolation of the Mise Equipment Header will also isolate the Rx Bldg Supply Header.

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 inadequate flow to the RCP oil coolers.

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, BOP Misc Equipment & Rx Bldg Equipment List.

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.: Event Description: NRC Scenario #

Event # TBHX Supply Line break

Time I Position I Applicant's Actions or Behavior ( NOTE: With SFP Heat Exchangers isolated and a maximum heat load in the SFP, a heatup rate of 15°F/hr could be experienced.

CHECK SFP Heat Exchanger A & B CCS Header INTACT:

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

Between 5.3 gpm and 12 gpm (Unit 1)

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] (between 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.: Event Description: NRC Scenario #

Event # TBHX Suppiy Line break

of

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, BOP Operation of Appendix R Valves Required by Section 2.3.

- STOP any unnecessary CCS Pumps.

BOP CHECK Train A CCS header pressure between 90 psig and 110 psig: BOP

1-PI-70-24A, 1A1/1A2 CCS HX

2-PI-70-17A, 2A1/2A2 CCS HX CAUTION : A LOCA on a Unit makes that Unit unavailable for SFP Cooling.

CHECK SFP Cooling CCS Supply/Return Header INTACT.

BOP Appendix D NUREG 1021 Revision 9

IAppendix D Reguired Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

Event # 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-BOP 1, Component Cooling Water System "A" Train.

CHECK Misc Equipment Header INTACT.

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.: Event Description: NRC Scenario #

Event # Diesei Generator Inoperability

Page

of

Time I Position I Aooiicant's Actions or Behavior ( c, Booth Instructor: When directed, call in report of Sl Pump oil problem Receives report; Refers to Technical Specifications section 3.5 SRO and 3.0.3 SRO Determines T.S. 3.0.3 applies.

When Technical Specifications have been addressed, the Lead Examiner may cue the next event.

Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

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 rapidly Containment parameters increasing rapidly Reactor Tri p Safety Injection US Direct entry to E-O, Reactor Trip or Safety Injection 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 DISCONNECTED 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 VERIFY turbine TRIPPED: Appendix D NUREG 1021 Revision 9

I Appendix 0 Required Operator Actions Form ES*D*2 I ( Op Test No.: NRC Scenario #

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 CLOSED.

CRITICAL VERIFY at least one train of shutdown boards ENERGIZED.

TASK Attempt to rest ore power to at least ONE train of

shutd own boards BOP Place DG 1A*A control switch in START

Verify Train A Shutdown Boards ENERGIZED DETERMINE if SI actuated: -

ECCS pumps RUNNING.

RO

Any 81 alarm LIT [M-4D] (SI will be actuated) PERFORM ES-0.5, Equipment Verifications WHILE continuing in this procedure.

BOP (Actions for ES-0.5 are contained in attachment at back of scenario guide) Critical Task to start 1A*A CCP is contained in ES*O.5 actions DETERMINE if secondary heat sink available: a.

CHECK total AFW flow greater than 440 gpm.

b.

CHECK narrow range level greater than 10% [25 ADVj in at least one S/G. RO CONTROL feed flow to maintain narrow range level c.

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 #

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 ( (, CHECK if main steam lines should be isolated : a, CHECK if any of the following conditions have occurred:

Any S/G pressure less than 600 psig AND STEAMLINE PRESS ISOL Sl BLOCK RATE ISOL ENABLE permissive DARK [M-4A, A4] OR RO

Any S/G pressure dropping UNCONTROLLED.

OR -

Phase B actuation b.

ENSURE MSIVs and MSIV bypass valves CLOSED.

(Main Steam lines will isolate on Phase B) NOTE: Loss of seal injection flow could adversely affect RCP seals.

CHECK RCP trip criteria: a.

CHECK the following:

RCS pressure less than 1250 psig.

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 Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

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 CHECK T-avg stable at or trending between 547 degrees F and 552 degrees F.

RO OR

IF RCPs stopped, THEN CHECK T-cold stable or trending to between 547 degrees F and 552 degrees F.

- CHECK pressurizer PORVs, safeties, and spray valves: a.

Pressurizer PORVs CLOSED.

b.

Pressurizer safety valves CLOSED. RO c.

Normal spray valves CLOSED.

d.

Power to at least one block valve AVAILABLE.

e.

At least one block valve OPEN.

CHECK S/G secondary pressure boundaries INTACT:

All S/G pressures CONTROLLED or RISING RO

All S/G pressures greater than 140 psig.

CHECK S/G tubes INTACT: RO a. CHECK all S/G narrow range levels CONTROLLED or DROPPING. Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenarto #

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 NORMAL.

Condenser exhaust recorder RR-90-119 NORMAL.
S /G blowdown recorder RR-90-120 NORMAL.

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) Monitor Status Trees Crew Go To E-1, Loss of Reactor or Secondary Coolant Appendix D NUREG 1021 Revision 9

I Appendix D Reguired Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

Event # 7,8,9,10 Event Description: SBLOCA, Loss of off-site power, EDG failure, 1A*A CCP,1A*A CCS Pp start failure Time I Position I Applicant's Actions or Behavior c.

Determines Orange condition exists on Containment CSF Crew Status Trees Directs entry to FR-Z.1, Response to High Containment US Pressure NOTE If this procedure has been entered for an orange path and performance of ECA-1.1 (Loss of RHR Sump Recirculation) is required, FR-Z.1 may be performed concurrently with ECA-1.1.

RO MONITOR RWST level greater than 27%. VERIFY Phase B valves CLOSED,

Panel 6K PHASE B GREEN RO

Panel 6L PHASE B GREEN ENSURE RCPs STOPPED.

RO Appendix D NUREG 1021 Revision 9

I Appendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: NRC Scenario #

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 pressure DROP PING in an uncontrolled manner OR

Any S/G pressure less than 140 psig.

RO b.

CHECK containment pressure less than 12 psig.

c.

CHECK at least one containment spray pump RUNNING and delivering flow.

d.

CHECK at least one containment air return fan RUNNING e.

RETURN to procedure and step in eHect.

US Directs entry to E-1, Loss of Reactor or Secondary Coolant Scenario may be terminated upon transition to E-1 Appendix D NUREG 1021 Revision 9

I Append ix 0 Required Operator Actions Form ES-O-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # Equipment Verifications ES-Q.5 Time I Position I Aoolicant's Actions or Behavior ( ( CHECK ERCW system operation: BOP

VERIFY at least four ERCW pumps RUNNING.

VERIFY DIG ERCW supply valves OPEN.

CRITICAL VERIFY CCS pumps RUNNING: TASK Pump 1A-A (2A-A) Must Manually Start

BOP

Pump 1B-B (2B-B)

Pump C-S.

- VERIFY EGTS fans RUNNING.

BOP VERIFY generator breakers OPEN.

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

IAppendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # Equipment Verifications ES-O S Time I Position I Aoolicant's Actions or Behavior ( c.

CHECK AFW valve alignment: a.

VERIFY MD AFW LCVs in AUTO.

BOP b.

VERIFY TD AFW LCVs OPEN.

c.

VERIFY MD AFW pump recirculation valves FCV-S-400 and FCV-S-401 CLOSED.

VERIFY MFW Isolation:

MFW pumps TRIPP ED -

MFW regulating valves CLOSED BOP

MFW regulating bypass valve controller outputs ZERO

MFW isolation valves CLOSED

MFW flow ZERO.

CRITICAL MONITOR ECCS operation: TASK VERIFY ECCS pumps RUNNING: BOP

CCPs - MANUALLY START 1A-A CCP

RHR pumps

SI pumps VERIFY CCP flow through CCPIT.

CHECK RCS pressure less than 1500 psig.

BOP

VERIFY SI pump flow.

CHECK RCS pressure less than SOO psig.
VERIFY RHR pump flow.

Appendix D NUREG 1021 Revision 9

IAppendix D Required Operator Actions Form ES-D-2 I ( Op Test No.: Event Description: NRC Scenario #

Event # Equipment Verifications ES-O.5 of

Time I Position I Applicant's Actions or Behavior ( ( VERIFY ESF systems ALIGNED:

Phase A ACTUATED:

CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT [M-6C, B5].

CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT [M-6C, B6].

Containment Ventilation Isolation ACTUATED:

CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M-6C, C5].

CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C, C6]. - BOP

Status monitor panels:

6C DARK

6D DARK

6E LIT OUTSIDE outlined area

6H DARK

6J LIT.

Train A status panel 6K:

CNTMT VENT GREEN

PHASE A GREEN

Train B status panel 6L:

CNTMT VENT GREEN

PHASE A GREEN MONITOR containment spray NOT required:

Phase B NOT ACTUATED BOP AND

Containment pressure less than 2.81 psig

Ensure Containment 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 #

Event # Event Description: Equipment Verifications ES-O.5 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 B.

DISPATCH personnel to perform EA-0-1, Equipment Checks BOP Following ESF Actuation.

Appendix D NUREG 1021 Revision 9

( . to SHIFT TURNOVER CHECKLIS T Page 1 of 3 Today [8] SM [8] US/MeR o uo o AUO [8] STA (STA Function) Unit Unit Station

1 SON AUO Comp Actions Off-going - Name On-coming - Name

Secondary equipment operating or ready for service.

( ( AUXILIARY BUIL DING (7775) (593-5414)

Aux. Bldg. equipment operating or operable and ready for service.

1B-B CCS Pump in service for routine bearing vibration checks.

Res Leakage (51-137.0) T otal: 0.04 gpm; Identified: 0.02 gpm; nidentified: 0.01 gpm (today) I

"' _ " ' ,.0--- ' - SHIFT TURNOVER CHECKLIST ( Page 2 of 3 Today ( Sirrest in Progress/Planned: (Including Need for New Brief) Q*SI*NUC*000*1.0, Estimated Critical Conditions.

0-SI*SXX*06S*127.Q, Minimum Temp for Criticality.

Major Activities/Procedures in Progress/Plann ed: Reactor startup in accordance with Q*GO*3 Section 5.2, step 1.

0-SO-213-1 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 details.

I,:'1";- '.' ';",;';:::."" " ' ":~~:1:~ '

,

', ';*;;);i} \\ *~:~>i::;~:::,. LCO/ODCMrrRM ACTIONS.. ** ~ ' \\ *"

:'" c e, -,,,,.*,,,,,.'"., -." ":" '>.:'.'"

.:... :\\. :,', ".'. ", ,.*.*.**..,..,.".':...."..,.. ~':;,"}.. ~.,..,"..".A"".": ....,.>',..,,'.* '.',:- _, '.. ~ ;t:'~ ':':,';',-;'\\1' f.::~ ',,'.*',\\,...-:....: " ,: ' : :<*i:", ;~ ;' ~"'~' .~~ t.':, :*r"" . ', ~:: None Part 2 - Performed by on-coming shift

Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's)

Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shilt Turnover:

Standing Orders

LCO(s) in Actions (NiA for AUOs)

Immediate Required Reading

TACF (NiA for AUO's) Part 3 * Perfo rmed by both oft-going and on-coming shift

Walkdown of MCR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA40W (0)-20011 ( OPOP*I * ! (0)- 14.2001

-.-. _.~ ....*...-_... SHI FT TURNOVER CHECKLIST Page 3 of 3 Today ( Disabled Annunciators PANEL WINDOW ANNUNCIATOR WO I PER Num ber I (P' k T t Off N E . quopmen . orma on ags UNID And Noun Name Panel Probl em Description WOI PER Number - ( MCR WO LIST ID And Noun Name Panel Probl em Descrip tion WOlPER Numbe r (

( UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron: 1711 ppm Today I BA Controller Setpoint: 48 % * I RCS B-10 Depletion: 0 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__: N/A gallons of acid, N/A gallons of water

Venfy boric acio flow contro ller IS set at Adjusted BA Controller Setting law 0-80-62-7 section 5.1 Gallons of acid: N/A Gallons of water: NIA Rod Steps: NtA

i.: ',:::..,.: '.': ';>,':,L.:' ;:{:>:*\\:~, :\\~s! i m at.~9 rodsrooron..for emergency step.power reduction ~~. :;.,;....".:'.::;\\~~; ~ : ::.:

.. \\,;t~;,~':>

(As~JJm i rig; Xe no ri :eq (i ilihr i u.m. :and. no reactivity ~ffects due to Xenon. 213 total reactivity trornrods, 1/3 from",

. ~: ' .::, ~.~. :-:. ' ~" " ~:';';'.:..::~~::- <::'~j "';/::(~' " - ; :'~>-" .. ~: ".::: boron) .. >:~;--; . '.::' .:. ...;.,;.....:....~' --i . :~ ~.." ;.'. ~::<..'/<: Power red uction amount Estimated Final Rod Position Est imated boron additio n 10% NtA Steps on bank D NtA gallons 30% --:. NtA Steps on bank D NtA gallons 50% NtA Steps on bank D NtA gallons

- These values are approximations and not intended nor expected to be exact. The values may be superceded by Rx Engineering or SO-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 now.

[ :.~'- *:.:<;'f;f,;,J ;";:';; \\ :, ~.)~t.c*;{; ~:t:'/>:ii~;.;'~k~'; ;::~ *',:,:,SPrevi0 us'Sbift Reactivity Mal1ipulations '. ".' . ',' .,;'J:;.:,-:.:' ':',.".,. ., J.".., .':",....,:"'" -. '.:,,':';','.:"......'.';c., ~)'. ;.' ":" Number of dilutions: 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 Samarium -971 pcm Next Unit 1 Flux Map is scheduled-74% RTP Unit Supervisor: _ Name/Date Xenon -

( ( ( -~ - 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 Units Boron Date /Time Goal Lim it U1 RCS ppm 1712 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 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*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 CLA - Today / Now U2

3

- ppm 2522 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,M i dpo!nt ' :'~"ct~

. '-.' -i~; ' : ;-:::d.~S'l}::-);'-~\\.:_: : ", ~ <:: :l ~:::.'.i?:.L;': :: :!:*.\\ U1 RCS ppm 1.1 Today / Now >1 >1 U2 RCS ppm 2.43 Today / Now 2.18-2.48 2.33 '5 ;;;,~' W,,;;;, ; .: <~\\.%:<t ~ritriill)l to ~e cond ~rY. Leakr":M ln lo rm at i qn (Tota).CPM RM~!lq:99/,1 19) " ~,;~-';;'~~';lli~:~:~~:S~~~~

.: ::..~ ~~ ~....,

'~ \\ ;;..o~;; "~ -f~~. "";;":'-,~.IoN ~ *:_~~~""; * ';. _' ;;':L:t::~~;. ;".,.....:' "-.< '.

",.J;~~-c'. _';': :;:~-;. '

'~

.*...~: .~--" :u '"-4 JLC.-_ c..:.

Indi cator Units U1 Date /TIme U2 DatelTime SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137,5 eVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 229 Today / Now

Today / Now 15 gpd (30 min increase) cpm 567 Today / Now

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

Today / Now 12.5 Today / Now Bkgd on 99/119 clm

Today / Now

--=-:~ l~-~----------------------------- ", SHIFT TURNOVER CHECKLIST Page 1 of 3 Today [8J SM [8J US/MCR [8J UO o AUO [gJ STA (STA Function) Unit Unit Station

1 SON AUO Como Actions Off-going - Name On-coming - Name Part 1 - Completed by Off-going ShifVReviewed by On-coming Shift: Abnormal Equipment Lineup/Conditions: ~ ** t;;...... ~...~:""1... a;~, q > .-::' ~. ~*..!'-"

-::7 p~ p -..IP ,-"I" '."

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". _... '. ~l.'~>.~.,:' -:. Train B Week - ,~. '1'{ '?~"~":'~~..;7'Y'-:-.','..-: ,:.::~"";:.'... -; ..... -~:'.' -... :- -",

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.-~_"'" ',',".:, .":,'.- ~"'., ;'. ~:.:" _-.' TURBINE BWhPINGf1Z7.1J. (5f!3-5419)

,1

' d ***

.-.>~~5~.**: :',;

Secondary equipment operating or ready for service.

Outside equipment operating or operable and ready for service.

AUXILIARY BUILDING (7775) (593-5414)

Aux. Bldg. equipment operating or operable and ready for service.

1B-B CCS Pump in service for routine bearing vibration checks.

Re s Leakage (SI-137.0) T otal: 0.04 gpm; Identified: 0.02 gp m; Unident ified: 0.02 gpm (today) I

.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 Conditions.

0-SI-SXX-068-127.0, Minimum Temp for Criticality.

Major Activities/Procedures in Progress/Planned: Reactor startup in accordance with 0-GO-3 Section 5.2, step 1.

0-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 details.

':;~:*';~~'.

<

'*': '<r": '\\~*;

, *~". ~ :.;~;},; :"',~~.:: -:'~:C ~:.'; :';>{* *' * *(colbDCMfTRM -ACT I 6NS'::ir /i.*\\.;::.,;":, ' F 'e .,J,'..>' <t*1 .,:,<,.....

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-" .,.* ~. -s: - None Part 2 - Performed by on-coming shift

Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (N/A for AUO's)

Review of Rounds Sheets/Abnormal Readings (AUO's only) Review the Following Programs for Changes Since Last Shill Turnover:

Standing Orders

LCO(s) in Actions (N/A for AUOs)

Immediate Required Reading

TACF (N/A for AUO's) Part 3 * Performed by both off-going and on-coming shift

Walkdown of MeR Control Boards (N/A for AUO's) Relief Time: Relief Date: today TVA 40741 [03-200 I) OPDP-I-I [03-14-2001

.. . v--.*. ~.... - --- SHIFT TURNOVER CHECKLIST Page 3 of 3 Today ( Disabled Annunciators PANEL WINDOW ANNUNCIATOR WO I PER Number I (P' k T t Off N E . qurprnen

orma In 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 Operable 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 5.1 Gallons of acid: N/A Gallons of water: NIA Rod Steps: N/A

. ~ 0-

. "..

.

'" . -;.' - .. : -

.

,. -

- - -

. ' - -- - _

- '

.~.: ;',;;/':~ :" :...';~'.>,~. : '~~.: :".'....:Estimated "r,cids/boron fo"r.emergen*cy step 'power.reduction,,"*:r.~:' :,. : '.:.:.',':/':'.; ;,,',"~" ~':'.- \\.;,.:* .'...... ~ ..",:, '.":"' -:-:-' r:~~

......

.#~ ** * * ' -:,. :.,. _ :. , _,,:~,~>;..... .

. .. . ..... . . _ . ", 1. ' 0 ;' _

, "'. '.'" . ~.. ". ,.. ' "C "" .~ ... -..,....,:.... ",.:._ **.- ' *. r__""' ~*- '*.:~:JAssum i Jig'Xe.noh~.eq ~ i ! ib ri um ~nd. 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 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 assumin g 100% steady stale power operation only. Engineering data last updated one week ago.

Data Valid until three weeks from now.

[:i~*:~;i:~~;~~>::'~~ ;. ~~S~ ;'~}~J ~..:;:t~ ~;;~ ':>:j~>f:;:~'; Prev ious Sl}ift*fleacti\\ii.tYManlpulatlons

.~.

~: :.*:;<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 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% MWD/MTU -150 Samarium -971 pcm Next Unit 1 Flux Map is scheduled-74% RTP Unit Supervisor: _ Name/Date Xenon -

....._.....:..... .... _***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 Today 1Now Variable Variable ppm 6850 Today 1Now Variable Variable U1 CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 U1 CLA #2 ppm 2575 Today 1Now 2470-2630 2400-2700 U1 CLA #3 ppm 2591 Today 1Now 2470-2630 2400-2700 U1 CLA #4 ppm 2589 Today 1Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today 1Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today 1Now 2470-2630 2400-2700 U2 CLA #3 - Today 1Now - ppm 2522 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today 1Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today / Now > 2050 2: 2000 2.18-2.48 2.33 SI 50 S/G Leakage? Yes/No No Today 1Now No Today 1Now Sl 137.5 eVE Leakrate gpd < 0.1 Today 1Now < 0.1 Today 1Now 5 gpd leak equivalent cpm 229 Today 1Now

Today 1Now 15 gpd (30 min increase) epm 567 Today 1Now

Today 1Now 30 gpd leak equivalent epm 1174 Today 1Now 206 Today 1Now 75 gpd leak equivalent cpm 2875 Today / Now 455 Today 1Now 150 gpd leak equivalent epm 5710 Today 1Now 870 Today 1Now e VE Air Inleakage efm

Today 1Now 12.5 Today 1Now Bkgd on 99/119 cfm

Today 1Now

Today 1Now (

-til f r SHIFT TUR NOVER CHECKLIST Page 1 of 3 Today o SM o US/Me R (8) uo o AUO o STA (STA Function) Unit Unit Station SON AUO Camp Actions a ll-going - Name On-coming - Name

Secondary equipment operating or ready for service.

AUXILIARY BUILDING (7775) (593-5414)

Aux. Bldg. equipment operating or operable and ready for service.

1B-B CCS Pump in service for routine bearing vibration checks.

Re s Leakage (51-137.0) Total : 0.04 gpm; Id entified : 0.02 gpm; nldentificd: 0.02 gpm (today) I

'-",

- ~- * - - r - J-SHIFT TURNOVER CHECKLIST (

Page 2 of 3 Today Sirrest in Progress/Planned: (Including Need for New Brief) 0-SI -NUC-000-1.0, Estimated Critical Conditions.

O-SI-SXX-068-127.0, Minimum Temp for Criticality.

Major Activities/Procedures in Progress/Planned: Reactor startup in accordance with O-GO-3 Section 5.2, step 1.

O-SO-2/3-1 Section 5.16.3 Step 6 Radiological Changes in Plant During Shift: Containment dose rate increase with Rx powe r increase. Contact Rad Con for all RWP details.

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 - Performed by on-coming shift

Review of Operating Log Since Last Shift Held or 3 Days, Whichever is Less (NIA for AUO's)

Review of Rounds SheetslAbnormal Readings (AUa 's only) Review the Following Programs for Changes Since Last Shift Turnover:

Sfanding Orders

LCO(s) in Actions (N/A lor AUOs)

Immediate Required Reading

TACF (NIA for AUO's) Part 3 * Perform ed by both off-going and on-c oming shift

Walkdown of MCR Control Boards (N/A for AUO's) Relief Time.

Relief Date.

today ( TVA 40741 [0) *20011 OPDP*l -l {O)-14-200 1

-,,--- ---,...--_._.*_.- SHIFT TURNOVER CHECKLIST ( Page 3 of 3 Disabled Annunciators Today PANEL WINDOW ANNUNCIATOR WO I PER Number E . qulprnent Off*Normal (Pink Taqs) UNID And Noun Name Panel Problem Description WOl PER Number - MCRWO LIST ID And Noun Name Panel Problem Description WOlPER Number (

"f ( UNIT ONE REACTIVITY BRIEF Date: Today Time: Now RCS Boron : 1711 ppm Today I BA Controller Setpoint: 48 % * IRCS B-10 Depletion: 0 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_ _

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 5.1 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<-:';': - ::')~ ;~;;'\\

Power red uction amount Estimated Final Rod Pos ition Estimated boron 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

- These values are approximations and not intended nor 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 ago.

Data Valid until three weeks from now.

I'Y:'::>F;;!:?~p; ~;:;{ [;;.,;,~~l:i;::';l/~';\\,.:~.~~\\:;~ :~:J;;;-.~:,,!~,;;,~~,?~revi0US.Shift Reactivity ~~nip*~1.ation5 '; .:.,<",.:'.)-." y,,~,:, '.r

'
- " \\

. j" J'. ;-' ..*. :*..:.:';.;:::--... :...." " j/

.;-: \\.:(

".',: ~.~'...:.;:.!,:,: 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 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% MVVD/MTU - 150 Samarium -971 pcm Next Unit 1 Flux Map is scheduled-74% RTP Unit Supervisor: Name/Dale Xenon -

Operations Chemistry Information Variable Variable Variable Variable 2550 - 2650 2500 - 2700 2550 - 2650 2500 - 2700 Variable Variable Variable Variable Variable Variable 2470-2630 2400-2700 2470-2630 2400-2700 2470-2630 2400-2700 2470-2630 2400-2700 2470-2630 2400-2700 2470-2630 2400-2700 2470-2630 2400-2700 2470-2630 2400-2700 ~2050 ~2000

t!G~mr

';j)<
:.'" '.:; ;.;~.~~'~l::~t~i~t~;;:... **.<~v~Egm~/;:;'0;\\

>1 >1 2.1 8-2.48 2.33 Sample Point Units Boron Date ITime U1 RCS ppm 1712 Today I Now U2 RCS ppm 816 Today I Now U1 RWST ppm 2601 Today I Now U2 RWST ppm 2569 Tod ay / Now BAT A ppm 6850 Today / Now BAT B ppm 6850 Today I Now BATC ppm 6850 Today / Now U1 CLA #1 ppm 2556 Today I Now U1 CLA #2 ppm 2575 Today / Now U1 CLA #3 ppm 2591 Today / Now U1 CLA #4 ppm 2589 Today / Now U2 CLA #1 ppm 2531 Today / Now U2 CLA #2 ppm 2650 Today / Now - U2 CLA #3 - ppm 2522 Today / Now U2 CLA #4 ppm 2526 Today / Now Spent Fuel Pool ppm 2547 Today / Now 1~J.:r.S~~.~i ~~:W:~~:j~~'~~S:;itt(t';iX~~*:': U1 RCS ppm 1.1 Today / Now U2 RCS ppm 2.43 Today / Now ( g§~x5~~j \\~:~~~:&q~~lm~~~J¥;!~;~*~~P.11~,~r.t.:,;;~>;~~l:~?;A2~.?.~~~t !.o~.J.!g~E~lfPM:.R~~,22]:9t.1~~,~).*...*;:,:';-i~:*~~i%?':~.i:.l:~*~:\\i*L Indicator Units U1 Date I Time U2 Date/Tirne SI 50 S/G Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 229 Today / Now

Today / Now 15 gpd (30 min increase) cpm 567 Today / Now

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 CVE Air Inleakage cfm

Today / Now 12.5 Today / Now Bkgd on 99/119 cfm

Today / Now

(

( TENNESSEE VALLEY AUTHORITY SEQUOYAH NUCLEAR PLANT SYSTEM OPERATING INSTRUCTION 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Revision 46 NON-QUALITY RELATED Pat Barbree PREPARED BY:. -----'--'=-''''-- _ OPERATIONS RESPONSIBLE ORGANIZATION:__--='-='-"--"-'='-'=- _ W. T. Leary APPROVED BY:_=-- -'-'-'---'-'--'=-'-'--- _ ( 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 103395-02.

SECTION 8.815 DESIGNATED AS A CIPTE. INTENT CHANGES TO THIS SECTION REQUIRE PORC APPROVA ( saN 1-8 0 -2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 2 of 267 TABLE OF CONTENTS Page 1 of 4 Section Title Page 1.0 1.1 1.2 2.0 2.1 2.2 3.0 3.1 3.2 4.0 5.0 ( 5.1 5.1.1 5.2 5.2.1 5.2.2 5.3 5.4 5.5 5.6 5.7 5.8 5.9 5.10 5.10.1 5.1 0.2 (, INTRODUCTION

Purpose..................................................................................................................

Scope.....................................................................................................................

REFERENCES.......................................................................................................

Performance References

Developmental References....................

PRECAUTIONS AND LIMITATIONS......................................................................

Main Feedwater Pumps

Condensate Pumps..............

PREREQUISITE ACTIONS

STARTUP/STANDBY READINESS

Deaeration of the CSTs..........................................................................................

Hotwell Pump Recirculation

Placing Hotwell Pumps in Service

Placing First HWP In Service

Placing Additional Hotwell Pump(s) in Service.......................................................

Placing Condensate Booster Pumps in Service

Placing Cond Demin Booster Pumps in Service

Placing High Pressure Injection Water System In Service

Filling and Deaeration of the Short-Short Cycle

Filling and Deaeration of the Short Cycle...............................................................

Filling and Deaeration of the Long Cycle

Changing from Long Cycle Deaeration to Normal Valve Alignment for Filling S/Gs With Feedwater

Main Feedwater Pump(s) Oil Pump Test................................................................

1A MFP Oil Pump Tesl...........................................................................................

1B MFP Oil Pump Tesl...........................................................................................

( SON 1-80-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 3 of 267 TABLE OF CONTENTS Page 2 of 4 Section Title 5.14.1 1A MFP Trip Test Prior to Startup . 5.14.2 1B MFP Trip Test Prior to Startup . ( 5.11 5.11.1 5.11.2 5.1 2 5.1 2.1 5.12.2 5.13 5.13.1 5.13.2 5.14 Main Feedwater Pump(s) Warm-up . 1A MFP Warm-up . 1B MFP Warm-up . Main Feedwater Pump(s) Turbine Turning Gear . Placing 1A MFPT on Turning Gear . Placing 1B MFPT on Turning Gear . Main Feedwater Pump Turbine - Establishing Vacuum . 1A MFPT-Establishing Vacuum . 1B MFPT - Establishing Vacuum . Main Feedwafer Pump Trip Test(s) Prior to Startup . Page

77

83

85

87

93

97 5.1 5 MFPT Steam Supply Warm-up 101 5.15.1 1A MFPT Steam Supply Warm-up......................................... 101 5.15.2 1B MFPT Steam Supply Warm-up 102 5.1 6 Main Feedwater Pump Startup........... 103 5.1 6.1 Preparation of 1A MFP for Startup......................................................................... 103 5.16.2 Preparation of 1B MFP for Startup......................................................................... 106 5.16.3 Startup of First MFPT 109 5.16.4 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 6.0 NORMAL OPERATION.......................................................................................... 128 7.0 SHUTDOWN 129 7.1 Shutdown of Hotwell Pumps 129 7.2 Shutdown of Condensate Booster Pumps 130 ( 7.3 7.4 Shutdown of Cond Demin Booster Pumps .. Shutdown of High Pressure Injection Water Pumps .. 133 136

( SQN 1-S0 -2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46

Page 4 of 267 TABLE OF CONTENTS Page 3 of 4 Section Title Shutdown of 1A MFP 137 Shutdown of 1B MFP 144 INFREQUENT OPERATION 151 Transferring Duplex Filters 151 Bearing Oil (LIP) Duplex Filter (Manual Balancing Valve) 151 High Pressure Oil (HIP) Duplex Filter (Automatic Pressure Equalization Valve).... 154 Swapping Main Feedwater Pump Turbine Oil Coolers........................................... 156 Swapping Oil Coolers for 1A MFPT........................................................................ 156 Swapping Oil Coolers for 1B MFPT........................................................................ 159 Throttling HIP Steam Supply 1501 During MFPT Startup 162 Throttling 1A MFPT HIP Steam Supply 1501 During Startup [C.5]......................... 162 Throttling 1B MFPT HIP Steam Supply 1501 During Startup [C.5]......................... 162 Main Feedwater Pump Overspeed Tests............................................................... 166 1A MFP Overspeed Test........................................................................................ 166 1B 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 Swapping 1A MFPT Main Oii Pumps 191 Swapping 1B MFPT Main Oil Pumps 193 Online Main Feed Reg Valve Maintenance 195 Dogging SIG #1 Main Feed Reg Valve 195 Dogging SIG #2 Main Feed Reg Valve 204 Dogging SIG #3 Main Feed Reg Valve 213 Dogging SIG #4 Main Feed Reg Valve 222 7.5 7.5.1 7.5.2 8.0 8.1 8.1.1 8.1.2 8.2 8.2.1 8.2.2 8.3 ( 8.3.1 8.3.2 8.4 8.4.1 8.4.2 8.5 8.6 8.7 8.7.1 8.7.2 8.8 8.8.1 8.8.2 8.8.3 8.8.4 ( Shutdown of Main Feedwater Pumps .. Page 137

( SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46

Page 5 of 267 8.9 8.10 8.11 8.12 8.1 3 8.14 8.15 8.16 8.17 8.18 9.0 ( TABLE OF CONTENTS Page 4 of 4 Hotwell Feed and Bleed 231 Manual Operation of Exhaust Hood Sprays 232 Swapping High Pressure Injection Water Pumps 233 Rolling of Second MFWP to 50 psig less than Feedwater Pressure 235 Manual Selection of Controlling Feed / Steam Flow Channels 244 Operating MFP A Oil Pumps for Maintenance.

247 Operating MFP B Oil Pumps for Maintenance 248 MFPT HSC Adjustment other than Initial Minimum Speed.................................... 249 Adjustment Of The CBPs Bearing Oil Temperature 258 Makeup and_dumpback to and from Hotwell using manual bypass valves 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 ATTACHMENTS ATIACHMENT 1: ATIACHMENT 2: ATIACHMENT 3: ATIACHMENT 4: CONDENSATE AND FEEDWATER SYSTEM POWER CHECKLIST 1-2/3-1.01 CONDENSATE AND FEEDWATER SYSTEM POWER CHECKLIST 1-2/3-1.02 CONDENSATE AND FEEDWATER SYSTEM VALVE CHECKLIST 1-2/3-1.03 CONDENSATE AND FEEDWATER SYSTEM VALVE CHECKLIST 1-2/3-1.04

('. ( SQN 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 6 of 267 1.0 INTRODUCTION 1.1 Purpose This procedure provides instructions for the operation of the Condensate and Feedwater Systems.

1.2 Scope This procedure provides the detailed steps to perform the following operations: A.

Filling and deaeration of the short-short cycle.

B.

Filling and deaeration of the short cycle. C.

Filling and deaeration of the long cycle.

D.

Changing from long cycle deaeration to normal alignment for filling S /G with feedwater.

E.

MairrFeedwater Pump operation (startup, shutdown, and swapping of oil pumps).

F.

Startup and shutdown of: 1.

Hotwell Pumps 2.

Condensate Booster Pumps 3.

Cond Demin Booster Pumps G.

High pressure injection water system startup and shutdown.

H.

MFPT Overspeed Test.

I.

Resetting Feedwater Isolation Signal.

J.

Manual Operation of 1-FCV-2-35A dog.

2.0 REFERENCES 2.1 Performance References A.

Proced ures 1.

0-GO-4, Unit Startup from Less Than 5% Reactor Power to 35% Reactor Power 2.

GOI-6, Apparatus Operations 3.

0-SO-12-1, Auxiliary Steam System 4.

0-SO-24-1, Raw Cooling Water System

( ( ( SQN 1-50-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46

Page 7 of 267 2.1 Performance References (Continued) 5.

0-50-77-9, Nitrogen System 6.

1-50-1-1, Main Steam System 7.

1-50-2-9, Condenser Vacuum System 8.

1-S0 -5-2, NO.3 Heater Drain Tank and Pumps 9.

1-S0-5-4, Feedwater Turbine Condenser Drain Tank and Pumps 10. 1-S0 -5-5, Atmospheric Condensate Drain Tank Pump Operation 11. 1-S0-14-1, Condensate Demineralizer Operation 12. 1-S0 -41 -3, Steam Generator Recirculation System B.

Tech Specs 1.

3.3.2 1 and Table 3.3.3.6.f 2.

3.7.1.3 2.2 Developmental References A.

FSAR 1.

9.2.6 2.

104.7 B.

Procedures 1.

0-GO-3, Power Ascension from Reactor Critical to Less Than 5 Percent Reactor Power 2.

0-GO-5, Normal Power Operation 3.

SOI-2.1 & 3.1, Condensate and Feedwater System C.

TVA Drawings 1.

47W610-2-1 through 5 2.

47W610-3-1 and 2 3.

47W610-46-3 and 4 4.

47W801-1 5.

47W803-1 and 2 6.

47W804-1 and 2 End of Section ( SQN 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 8 of 267 ( ( 3.0 3.1 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 bearings.

C.

Injection Water should be aligned to Condensate Booster Pump (CBP) and Main Feedwater Pump (MFP) at all times when pumps are running.

D.

Oil pressure leaving the MFP oil coolers should be greater than 20 psig and temperature should not be greater than 120°F.

E.

Level in each Steam Generator (S/G) should be monitored for possible feedwater (FW) isolation valve leakage.

F.

During secondary plant warm-up, draw steam slowly and regulate FW additions carefully to avoid rapid cooling of reactor coolant.

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 flow.

I.

Byron Jackson recommends a maximum warm-up rate of approximately 1OO°F/hr which corresponds to a warm-up flow of approx. 10 to 15 gpm.

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 temperature.

If it is determined that 75°F differential is difficult to achieve, then 100°F is acceptable.

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-AUTO and speed less than 2 rpm, the turning gear motor will auto start when other interlocks are made.

M.

MFPT should be placed on turning gear 45 min. before rolling with steam.

N.

Normal return operating oil temperature from the feed pump turbine and pump bearings should be maintained between 140°F and 160°F.

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 speed.

P.

Normal operating temperature of the turbine and pump bearing metal should not exceed 185°F.

Q. Minimum bearing oil temperature for the feed pump turbine on turning gear is 70° ( ~. SQN 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 9 of 267 3.0 PRECAUTIONS AND LIMITATIONS (Continued) 3.1 Main Feedwater Pumps R.

Gland sealing steam should not be applied to the MFPT with the rotor at rest.

S.

Condenser vacuum should not be placed on MFPT without sealing steam at the glands to prevent air being drawn into MFPT.

T.

Undue heating of low-pressure portions of the turbine should be avoided.

U.

If turbine has been idle for a considerable period of time, the stop valves should be tripped immediately after starting to see if tripping mechanism functions properly.

V.

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 percent.

W.

MFW pump and turbine thrust bearing wear alarm and trip and bearing vibration alarm values are determined each startup. Current values are on the ICS, Secondary Mimics, MFP Bearing Data page either on the "Full Database Info" page (for a particular point) or by selecting the "MFP AlB Runout" button.

X.

MFW pump and turbine bearing vibration should not exceed 5 mils above baseline (alert value is 3 mils above baseline). Vibration should be monitored locally at Bently Nevada vibration monitoring panel (1 -L-598) and ICS (Secondary Mimics, MFP Bearing Data).

Y.

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.)

Z.

When shutting 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 certain all rotation has stopped before starting turning gear.

AA. During hot shutdown, FW additions should be controlled to minimize the thermal stress cycles of the FW nozzles.

AB. MFPTs will trip if Injection Water supply header pressure falls below 220 psig on 2/2 pressure switches for 28 sec (MFWP 1A) or 20 sec (MFWP 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 flowing through them.

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.

( ( SQN 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 10 of 267 3.0 PRECAUTIONS AND LIMITATIONS (Continued) 3.1 Main Feedwater Pumps AE. If the bias of either MFTP Controller (1-SIC-46-20A or 1-SIC-46-20B) is changed away from 50% and either that controller or the Master Controller (1-PC-46-20) is placed in Manual, then restoration to Automatic without restoring the bias to 50% will result in an instantaneous speed change of the affected MFPT.

3.2 Condensate Pumps A.

Do not exceed maximum number of starts on 6,900V motors in accordance with GOI-6.

B.

The temperature of the water in the Hotwell (HW) should not exceed 120°F.

C.

HW must not be filled greater than 18 inches above normal, unless water temperature is greater than 60°F (prevent stressing the conden ser wall welds).

D.

Do not pump water from the HW to Condensate Storage Tanks (CSTs) after condenser vacuum is broken, due to increasing the Oxygen level in the CST, unless given permission by the Radiochemical Laboratory (RCL) Shift Supervisor.

E.

The motor-driven oil pump for each CBP should start when each pump suction FCV is opened.

F.

Condensate flow through condensate demineralizer polishers should not be established if condensate Oxygen level is not within specifications as determined by the RCL Shift Supervisor.

G.

Do not allow HWP flow through an idle CBP. With CBP sucti on FCV open and subjected to HWP discharge pressure, water can contaminate the bearing oil.

H.

When charg ing Condensate System, valves should be opened slowly to prevent a sudden pressure drop and loss of Injection Water to the MFPTs.

This could cause a main feed pump trip and auto start of auxiliary fee d pumps. [C.1] I.

Before the first HWP is started, the discharge valve 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 stabilized 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 Rev 46 Page 11 of 267 3.0 PRECAUTIONS AND LIMITATIONS (Continued) J.

A HWP must be running to supply suction to Injection Water Pumps.

K.

Do not run Injection Water Pumps for extended periods (over 4-5 min.) unless at least one MFP is receiving seal water since Injection Water Pumps do not have a recirculation flowpath.

L.

Prior to starting first HWP, an operator shall be stationed locally at the pumps during initial start and filling of the syste m and shall immediately notify the Unit Operator if any abnormal pump operation occurs (e.g., unusual noise, discharge or suction pressure abnormal).

M.

Do not exceed 98% level in CSTs.

N.

The demineralized wate r for filling the CSTs must be within acceptable limits as required by O-TI-CEM-OOO-001.1 with the exception of dissolved oxygen. O.

Self venting of the CBP will occur through recirculation piping. As the suction FCV is opening, air will be removed as flow is directed into the condenser through the recirc line.

P.

MIG support is required to ensure correct seal injection water press ure prior to placing a CBP in service or removing a CBP from service. If injection water pressure is too high following shutdown, water can contaminate the bearing oil.

Q.

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 water.

R.

When a CBP is subjected to condenser vacuum (through the recirculation line) without seal injection aligned, the pump shaft seals become a condenser vacuum boundary. Air may be pulled in through seals and cause condenser inleakage to increase.

S.

When adjusting seal differential pressu re, leakoff line movement may be obse rved. This is caused from flashing. By increasing the seal delta-P, the leakoff line temperature is reduced which causes less flashing. Target for leakoff line temp is < 220° ( ( ( SQN 1-80-2/3-1

CONDENSATEAND FEEDWATERSYSTEM Rev 46 Page 12 of 267 3.0 PRECAUTIONS AND LIMITATIONS (Continued) T. If condensate system is to be placed on hotwell recirculation. with system drained and LP heaters isolated. 1-FCV-2-329A and 329B should be isolated to preven t inadvertent cycling when filling and venting LP heaters and downstream piping. 1-FCV-2-329A has a mechanical stop externally inserted on the stem to maintain the valve partially open at all times. This helps prevent a water hammer condition if the valve closes with steam generator blowdown inservice to the heat exchanger. The open position results in a continuous flowpath around the LP heaters and will result in filling the system downstream of the LP heaters during system filling and venting for hotwell recirculation.

1-FCV-2-329A and 329B are controlled by 1-PDIS-2-329, which senses differential pressure across the LP heaters.

U. The hot well level indicators may read differently on each condenser.

This is caused by various water inputs into each condenser.

"A" Condenser receives water from 8/G blowdown from 1st stage HX, Atmospheric Cond Dr Tk and MFPC Dr Tk bypass.

"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 transmitter.

"C" Condenser receives Condensate Booster Pump recirc flow.

Pressure differences between the Condenser sections can be caused by CCW water box outages, dirty tube sheets, dirty debris filters. All these things affect actual hotweilleveis and the ability to contro l level at a normal 18" setpoint.

Plant modes of operation such as: Long cycle, Main Feed Water Pump recirc Valve opening, Condensate Booster recirc operation, #3 and #7 Heater Dr Tk bypass Valve operation can cause Hotweillevel deviations.

End of Section ( SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46

Page 13 of 267 4.0 PREREQUISITE ACTIONS Date nlJlhj NOTE 1 NOTE 2 Throughout this instruction where an IF/THEN statement occurs, the step may be N/A if the condition does not exist.

Throughout this instruction where the verb "VENT" is a directed action, the following actions should be performed: A.

THROTTLE OPEN the specified valve(s).

B.

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) COMPLETE.

[4] ENSURE Valve Checklist 0-2/3-1.06 (2-S0 -2/3-1 All. 6) COMPLETE.

[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 5.0 STARTUP/STANDBY READINESS W 6.0 NORMAL OPERATION o 7.0 SHUTDOWN o 8.0 INFREQUENT OPERATION Reason: _ End of Section ( SQN 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 109 of 267 5.16.3 Startup of First MFPT [1] ENSURE MFP condenser drain tank is aligned in accordance with 1-S0-5-4.

NOTE Throughout this section, N/A the non selected MFPT handswitches and valves. [2] RECORD MFPT selected to be started first.

[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 handswitch.

[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], THEN 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: ( DESCRIPTION VALVE NO.

POSITION INITIALS FWP 1A Outlet Flow Ii? Control Valve 1-FCV-3-67 OPEN FWP 1B Outlet Flow

)/

Control Valve 1-FCV-3-81 OPEN

( SQN 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 110 of 267 Date ToJ..7 ( 5.16.3 Startup of First MFPT [6] ENSURE MFPT Speed Control Bias dial at 50%. [7] PLACE MFPT speed controller for the MFPT to be started in AUTO.

MFPT SPEED SWITCH ,f DEMAND ,f CONTROLLER POSITION SETPOINT A SIC-46-20A AUTO

ZERO

B SIC-46-20B AUTO

ZERO

[8] DISPATCH personnel to determine if electric speed changer outlet pressure on 1-PI-46-5100 for A MFPT or 1-PI-46-5105 for B MFPT indicating between 18-22 psig.

[9] IF electric speed changer outlet pressure is NOT correct, THEN NOTIFY IMs to evaluate EH speed change signal.

o o o NOTE Either stop valve handswitch will open both high pressure and low pressure stop valves for the applicable MFPT.

( [10] OPEN Stop Valves for the MFPT to be started by placing either the HIP or LIP handswitch to the RAISE position.

MFPT DESCRIPTION HANDSWITCH' VALVE POSITION INITIALS 1A HIP Stop Valve 1-HS-46-15A OPEN LIP Stop Valve 1-HS-46-16A OPEN

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 Valves.

[12] VERIFY MFPT OFF Turning Gear.

o o

( SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev46

Page 111 of 267 5.16.3 Startup of First MFPT (Continued) Date _ NOTE 1 NOTE 2 NOTE 3 . 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 baseline; alert value is 3 mils above baseline. Thrust bearing wea r trip setpoint is 10 mils above baseline (7 mils alert above baseline).

1A MFWP condenser vacuum may be monitored using 1-PI-2-331A (TB el. 685), ICS computer point 1U2082, or by monitoring condense r drain temperature (ICS point 1T2360A). 1B MFWP condenser vacuum 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" Hg.

MFWP trip setpoint of 12.2 psia corresponds to - 5 "Hg vacuum or drain temp of - 200°F.

Max allowable bearing temperature is 225°F.

[13] MONITOR the following parameters during MFWP startup:

Vibration and thrust bearing wear (at local panel)

MFWP Condenser vacuum/drain temperature.

Oil system and bearing temperatures.

o o o

( SQN 1-50 -2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 Page 112 of 267 5.16.3 Startup of First MFPT (Continued) Date _ ( CAUTION . If unstable or unexpected results are encountered following man ipulations then return the plant to the last known stable condition. Startup should not proceed until problem is evaluated.

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 MIG.

[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 1.

ESTABLISH direct communications between the personnel operating the U1 MFP speed control locally and the U1 Main Control Room.

D 2.

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 speed.

D

( SQN 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 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).

[b] SET speed controller to zero (0) output in MCR.

[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 speed.

- [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 rpm.

[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 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 1.

ESTABLISH direct communications between the personnel operating the U2 MFP speed control locally and the U2 Main Control Room.

2.

DIRECT MIG to slowly adjust U2 MFP Speed Control using local manual control of the MFP Governor Valve Positioner to fully open steam chest valves.

o o o o o

( SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46

Page 114 of 267 5.16.3 Startup of First MFPT (Continued) [19] VERIFY Governor Valve Positioner has a RED light LIT and a GREEN light DARK.

Oate _ 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 8.3 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 OPEN.

D [b] EVALUATE throttling HP steam to MFPT in accordance with Section 8.3.

D [e] IF swinging is excessive (indicating malfunction of MFWP governor valve or speed controls), THEN PERFORM the following: 1.

2.

3.

4.

STABLIZE plant at last stable condition.

CONSULT Systems Engineering for assistance.

INITIATE WO for repair of MFPT. [C.5] IF necessary to swap to other MFPT, THEN GO TO Section 7.0 for shutdown of MFPT.

D D D D

( SQN 1-S0-2/3-1 CONDENSATE AND FEEDWATER SYSTEM Rev 46

Page 115 of 267 5.16.3 Startup of First MFPT (Continued) Date _ CAUTION 1 MFP discha rge pressure must 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. [CAl CAUTION 2 Anticipate steam gene rator sh rink or swell ANYTIME system fl ow or pressure changes. DO NOT use reactor power 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 interval.

[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 Pressure.

[22] ENSURE MFP Injection Water Intermediate Leakoff Pressure for pump started is 200-250 psig.

[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 psid.

[a] [1-PDI-54-1], 1A MFP OR [b] [1-PDI-54-5], 1B MFP o

( SON 1-S0-2/3-1

CONDENSATE AND FEEDWATER SYSTEM Rev 46 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 controller.

o NOTE MFPT speed control program is 80 psid from 0% to 20%, then ramps from 80 psid to 194.2 psid at 100% power.

Ramp is linear between 20 and 100%. ( [25] PLACE [1-PC-46-20]. MFP Master Speed Controller in AUTO.

CAUTION 1 MFP Recirc valves controllers should NOT be operated in AUTOMATIC due to the potential for isolating all three intermediate heater strings and resulting MFP damage.

(Reference: PER 00-002540-000).

CAUTION 2 Clos ure of the MFP recirc valves on running MFWP with out ensuring sufficient forward flow could result in overheating and pump damage.

CAUTION 3 Operation of MFP RECIRC valve should be performed slowly due to affect on MFP !l.P program.

[26] WHEN main feedwater fiow is greater than 1.7 x 106 Ibm/hr.

THEN ENSURE recirc valve for running MFWP [1-FCV-3-70] or [1-FCV-3-84] CLOSED and in MANUAL.

( [27] MONITOR MFP discharge for stability and on program.

[28] IF program !l.P cannot be maintained. THEN OBTAIN SM concurrence to operate in MANUAL. [C.5] End of Section 5.16.3 o

( ,

( ( ( 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 Paqe 2 of 24 Table of Contents 1.0 1.1 1.2 2.0 2.1 2.2 3.0 3.1 3.2 4.0 5.0 5.1 ( 5.2 5.3 6.0 INTRODUCTION

Purpose

Scope

REFERENCES

Performance References

Developmental References

PRECAUTIONS AND LIMITATIONS

Precautions

Limitations

PREREQUiSITES

INSTRUC1]ONS

Actions To Be Performed Prior To Increasing Reactor Power

Power Ascension To Approximately 1% RTP

Transferring Feedwater From Auxiliary To Main Feedwater

RECORDS

Source Notes

ATTACH MENTS Attachment 1: Procedure Checklist

( SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Paqe 3 of24 1.0 INTRODUCTION 1.1 Purpose This General Operating (GO) Instruction provides necessary instructions to raise reactor power to approximately 1% for main feed pump startup and to transition from auxiliary feedwater to main feedwater with the feedwater bypass reg. valves in AUTO.

1.2 Scope A.

This GO contains the following sections: 1.

5.1 Actions To Be Performed Prior To Increasing Reactor Power 2.

5.2 Power Ascension To Appro ximately 1% RTP 3.

5.3 Transfe rring Feedwater From Auxiliary To Main Feedwater 2.0 REFERE NCES ( 2.1 Performance Refe rences 1,2-80-5-5, Atmospheric Condensate Drain Sump and Pumps 1,2-80-2/3-1, Condensate and Feedwater System 1,2-80-3-2, Auxiliary Feedwater System 1,2-80-1-1, Main Steam System MI-20.154 Controller Tuning Instruction 1,2-80-5-2, NO.3 Heater Drain Tank and Pumps 1,2-$ 0 -5-3, NO.7 Heater Drain Tank and Pumps 1,2-80-5-4, Feedwater Turbine Condenser Drain Tank and Pumps 1,2-80-5-1, Feedwater Heaters and Moisture Separator Reheaters 0-80-1-2, Steam Dump System 1,2-80-15-1,2, Steam Generator Blowdown 1,2-81-0P8-000-002.0, Shift Log M.

O-RT-NUC-OOO-001.0, Restart Test Program A.

B.

C D.

E.

F.

G.

H.

I.

J.

K.

( ( ( 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 2.1 Performance References (continued) N.

O-PI-OPS -OOO-001.0, Initial Startup System Parameter Log 2.2 Developmental References A.

O-GO-1, Unit Startup from Cold Shutdown to Hot Standby B.

O-GO-4, Power Ascension from Less Than 5% Reactor Power to 30% Reactor Power C.

SPP-2.2 D.

FSAR Section 1 (' ( ( SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Paqe 5 of 24 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Precautions A.

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] B.

Reactor power should be monitored using the following indications: 1.

Average loop IlT (U0485). Considered to be the most accurate power indication when less than 15% power.

2.

NIS power range.

3.

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.

C.

The boron concentration in the pressurizer should be maintained within 50 ppm of the RCS by use of pressurizer heaters and spray.

D.

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 concern.

3.2 Lim itations A.

Do NOT exceed a steady startup rate of + 1 DPM.

B.

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 overpower 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] C.

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 4.0 Startup Number I~o I PREREQUISITES Unit............../_ Date III!OV") NOTES 1) Throughout this Instruction where an IFITHEN statement exists, the step should be N/A'd if condition does NOT exist.

2) Prerequisites may be completed in any order.

3) This instruction may be ente red from a partial shutdown, N/A sections NOT applicable and annotate reason.

[1 ] [2] [3] [4] ENSURE Instruction to be used is the latest copy of effective version.

ENSURE Precautions and Limitations have been reviewed.

ENSURE main steam system aligned with MSIVs open in accordance with 1,2-S0 -1-1.

ENSURE the reactor is critical with powe r at approximately 1 X 10.3%. [5] [6] [7] MAINTAIN pressurizer pressure within the normal operating band by use of the pressurizer heaters and spray valves.

MAINTAIN pressurizer level greater than or equal to 25%. MAINTAIN TAVG stable with the steam dum ps in pressure mode or with the SG atmospheric relief valves set at 84% or 1005 psig.

[8] MAINTAIN SG levels within the normal operating range using Auxiliary Feedwater.

NOTE During start up after a cold shutdown the Condensate 01 normally will be aligned for full flow polishing until the MSRs are in service.

[9] ENSURE Condensate 0 1polishing operation in accordance with RCL recommendation (-, 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 4.0 Startup Number I uIJI PREREQUISITES (continued) Unit--!...f_ Date~ [10j ENSURE each performer documents their name and initials: Print Name Initials End of Secllon Print Name Initials

( 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 5.0 INSTRUCTIONS Unit ( CAUTION Date nJ.., Steps of this procedure must be performed sequentially, unless specifically stated otherwise.

5.1 Actions To Be Performed Prior To Increasing Reactor Power [1] ENSURE Section 4.0, Prerequisites complete.

NOTE Steps 5.1[2] through 5.1 [7] may be performed in any order.

[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 isolated.

NOTE Step 5.1[4] may be performed out of sequence (later) due to plant conditions as approved by the SM.

[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 ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Page 9 of 24 5.1 Startup Number loul Unit I* Actions To Be Performed Prior To Increasing Reacto r Power (continued) Date ~ INSTRUCTIONS INITIALS 1,2-S0-5-4, Feedwater Turbine Condenser Drain Tank and Pumps Jlltr 1,2-S0 -5-5, Atmospheric 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 entered.

[6] WHEN MFPT designated for startup is available, THEN 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 accordance with 0-SO-36-3, Secondary System Boric Acid Injection.

End of Section tift US/SRO

( SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Page 10 of 24 5.2 Startup Number Unit __ Power Ascension To Approximately 1% RTP NOTE Date _ Average loop L\\T (U0 485) is considered to be the most accurate power indication below 15% power. NIS power range and steam dump demand should also be monitored.

(REFER TO 0-SO-1-2 for steam dump demand program.)

[C.3j [1] WITHDRAW RODS OR DILUTE to bring reactor power to between 1 and 2% RTP, while continuing with this instruction.

o ( NOTE After refueling 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 calorimetric calculations). If significant differences occur (approx. 5%) between the alternate power indications then Engineering should be notified.

[2] IF startup 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]

[3] COMPARE NIS power range instrumentation with loop L\\T indicators and steam dump demand to evaluate accuracy of PRMs.

[C.3]

[4] SELECT the highest reading IRM or L\\I and PRM channels to be recorded on NR 45.

[C.3)

[5] REVIEW plant parameters and indications to determine plant stability prior to startup of Main Feed Pump.

[6] MAINTAIN reactor power approximately 1%.

( SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Page 11 of 24 5.2 Startup Number Unit _ _ Power Ascension To Approximately 1% RTP (contin ued) Date _ NOTE Steps 5.2[7] and 5.2[81may be performed in any order.

[7] WHEN total Aux FW flow to SGs 1 and 2 is constan t and greater than or equal to 300 gpm. THEN CLOSE [FCV-3-4001.AFW PUMP A RECIRC ISOL VLV. and PLACE handswitch [HS-3-400Al in the PULL TO LOCK position.

[8] WHEN total Aux FW flow toSGs 3 and 4 is constant and greater than or equal to 300 qprn, THEN CLOSE [FCV-3-4011. AFW PUMP B RECIRC ISOL VLV. and PLACE handswitch [HS-3-401Al in the PULL TO LOCK position.

1st IV 1st 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 operation at < 165 steps to avoid potential impact on safety analysis assumptions. Short term operation at < 165 steps is NOT a concern.

[9] ENSURE the plant is stabilized between 1 and 2% reactor power.

[C.l ] [C.3]

[10] COMPARE NIS intermed iate range instrumentation with loop t.T indications to evaluate accuracy of IRM*s. (C.l]

[11] RECORD IRM readings: [C.3] ( N35 N36 % RTP - - - - - % RTP - - - - o 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 5.2 Startup Number Unit __ Power Ascension To Approximately 1% RTP (continued) Date _ NOTE Step 5.2[12] may be performed out of sequence or in parallel with subsequent steps.

[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 available.

[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 step.

( Initials Date Time

( SON POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Page 13 of 24 5.2 Startup Number Unit __ Power Ascension To Approximately 1% RTP (continued) Date _ ( 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 AFWP start.

[15] IF both MFPT trip busses de-energized, THEN RESTORE power to ONLY ONE MFPT trip bus on the applicable unit. (N/A breakers NOT applicable.)

[C.l ) PUMP BREAKER NO.

ELECTRICAL BREAKER INITIALS - BOARD POSITION 250v DC MFPT 1A 1-BKRD-46-KN523 Battery Bd I CLOSED 1st CV 250v DC MFPT 1B 1-BKRD-46-KN524 Battery Bd I CLOSED 1st CV 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

( SQN POWER ASCENSION FROM REACTOR O-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Paqe 14 of 24 5.2 Startup Number Unit __ Power Ascension To Approximately 1% RTP (continued) CAUTION Date _ Failure to reset a MFPT prior to energizing the remaining MFPT trip buss will initiate an ESF actuation.

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 RESET.

Initials CV Date Date Time Time ( NOTE If the remaining NON-running MFPT is NOT available, steps 5.2[17] and 5.2[18] may be N/A.

[17] ENSURE power to the remaining MFPT Trip Bus on the applicable unit. (N/A breakers NOT applicable) PUMP BREAKER NO.

ELECTRICAL BREAKER INITIALS BOARD POSITION 250v DC MFPT 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 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Paqe 15 of 24 5.2 Startup Number Unit _ _ Power Ascension To Approximately 1% RTP (continued) Date _ PUMP BREAKER NO.

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 RESET.

Initials CV Date Date Time Time ( [19J START the first MFPT in accordance with 1,2-S0-2/3-1. End of Section o

( 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 _ 5.3 Transferring Feedwater From Auxiliary To Main Feedwater [1] VERIFY SG levels between 34 and 44%. CAUTION Anticipate a change in MFPT delta P when SG reg. bypass valves are adjusted. ICAI NOTE o 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 CONTROLLER POSITION " - SG-1 Reg Bypass Flow Control L1C-3-35 MANUAL

SG-2 Reg Bypass Flow Control L1C-3-48 MANUAL

SG-3 Reg Bypass Flow Control L1C-3-90 MANUAL

SG-4 Reg Bypass Flow Control L1C-3-103 MANUAL

(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 entered.

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 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Pace 17 of 24 5.3 Startup Number Unit __ Transferring Feedwater From Auxiliary To Main Feedwater (continued) CAUTION Date _ 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 valve.

2) 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 decreasing.

3) 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 position.

D D D D [b] SLOWLY DECREASE AFW flow to the associated SG to ZERO gpm.

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 OPEN [d] ALLOW SG level to stabilize.

D D D D [e] WHEN 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 5.3 Startup Number Unit__ Transferring Feedwater From Auxiliary 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): Date _ ( SG*1 SG-2 SG*3 SG-4 [a] PLACE the reg. bypass valve controlle r in MANUAL.

0

0 [b] ADJUST valve demand position less than 10% in the opposite direction of valve

0

0 travel.

[c] PLACE the reg. bypass valve controller in AUTO.

0

0 NOTE Should reg. bypass valves NOT control properly in AUTO, then unit startup SHALL NOT continue until corrective actions have been taken to allow proper operation of the reg.

bypass controllers in AUTO unless waived by Plant Manager.

[8] IF the reg. bypass is NOT operating properly in AUTO, THEN STABILIZE plant conditions and NOTIFY the SM for corrective actions.

[CAl 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-3-400AJ.

[9.9] PLACE [HS-3-400Al. AFW PUMP A RECIRC ISOL VLV handswitch to the PULL TO LOCK position.

[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 stable.

1st IV 1st IV 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 5.3 Startup Number Unit __ Transferring Feedwater From Aux iliary To Main Feedwater (continued) [1 0.7L PLACE LCV-3-171 in AUTO.

Date _ 1st IV 1st IV ( [10.8] CLOSE [FCV-3-4011, AFW PUMP B RECIRC ISOL VLV with [HS-3-401AJ, 1st IV [10.9] PLACE [HS-3-401Al, AFW PUMP B RECIRC ISOL VLV handswitch to the PULL TO LOCK position.

1st IV [11J VERIFY the following: A.

SG levels stabilized between 34 and 44%.

B.

Reactor power stabilized between 1 and 2%.

C.

Main Feed Pump in AUTO.

D.

Main Feed Reg Bypass Valves in AUTO (N/A if waived by plant manager or designee.).

( 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 5.3 Startup Number Unit __ Transferring Feedwater From Auxiliary To Main Feedwater (continued) [12J VERIFY all motor driven AFW LeV controllers in AUTO.

Date _ Initials IV Date Date Time Time [13] VERIFY all turbine driven ARN LCV controllers in NORMAL Initials IV NOTE Date Date Time Time All four reg. bypass valves shall be in AUTO and reactor power less than 2% prior to performing the next step.

[14) IF fine tune of bypass reg. level controllers is required, THEN REQUEST IMs to perform MI-20.154 Controller Tuning Instruction.

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%. [1 6] CONTACT Reactor Engineering to determine if O-PI-NUC-092-082 should be performed prior to exceeding 4% reactor power.

o 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 5.3 Startup Number Unit __ Tra nsferring Feedwater From Auxiliary To Main Feedwater (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 Program.

Date _ Reactor Engineering [18J IF power escalation is desired, THEN Date Time ( GO TO O-GO-4, Power Ascension From Less Than 5% Reactor Power To 30% Reactor Power.

[19) IF Unit shutdown is desired, THEN GO TO O-GO-5, Power Reduction From 30% Reactor Power To Hot Standby.

End of Section

( ( ( SQN POWER ASCENSION FROM REACTOR 0-GO-3 Unit 1 & 2 CRITICAL TO LESS THAN 5 PERCENT Rev. 0018 REACTOR POWER Pane 23 of 24 6.0 RECORDS Completed copies shall be transmitted to the Operations Superintendent's Secretar ( 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 Statement Source Document Statement Revise GOI-2 to require verification of NCO 890118002 C.1 intermediate range (IR) status at LER 328/89006S53 approximately 20 and 25 percent, 890531 844JRB to NRC verify source range (SR) status and channel 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 ascension.

Following refueling operations SOER-90-003 C.2 relocation of NIS or modifications NCO 900107009 affecting the NIS response, provide NER 1187001 adequate reductions of trip setpoint LER 327/90011R1 ( and limitations of reactor power until accuracy of the NIS is verified. Also provide alternate indications of power independent of calorimetric calculations during power ascensions.

INPO SER on miscalibration of NIS SER 89-009NER 890252 C.3 Power Range detectors Revise GOI-2 prior to restarting Unit 2 LER 328/89005 CA to incorporate 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 evolutions.

Consult Reactor Engineering for NER 89 07940ER 89 3497 C.5 guidance during evolutions of unusual power maneuvers at end of core life. }}

IR 05000327/2007301

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ML072980616
Site:	Sequoyah (DPR-077, DPR-079)
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)
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v t e Inspection Report - Sequoyah - 2007301 (Operator Exams)
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2007 Quarterly Integrated 1Q (0) 2Q (0) 3Q (0) 4Q (1) Assessments Mid Cycle End of Cycle 7(0) 8(0) Security 201(0) 403(0) 404(0) Operator Exams 301(0) Emergency Planning 501(0) Other

IR 05000327/2007301

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