Text

RB-09-2004 - Final - Written Exam - SRO
	ML042990539
Person / Time
Site:	River Bend
Issue date:	09/23/2004
From:	Gody A; Operations Branch IV
To:	Hinnenkamp P; Entergy Operations
References
	50-458/04-301 50-458/04-301
	Download: ML042990539 (147)
	v • d • e

The plant is operating in mode 1 at 100% of rated power. STP-053-3001 (Jet Pump Operability) has just been completed. Upon review of the STP the CRS has discovered that Jet Pump No. 7 is inoperable.

The CRS enters T.S. 3.4.3 Action A, requiring the plant to be in Hot Shutdown within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Which one of the following correctly describes the basis behind this required tech spec action?

A. A failed jet pump increases the probability of instability events at lower power levels during low flow conditions.

B. With a failed jet pump, neutron flux distribution across the core changes due to the change in core flow, thereby making the APRM indications unreliable.

C. A failed jet pump increases the blowdown area and reduces the capability of reflooding to two thirds (2/3) core height following a LOCA.

D. A failed jet pump causes the APRM Flow Biased scram and rod block setpoints to drift due to the increase or decrease in flow in the affected loop.

ANSWER: C Knowledge of bases in technical specifications for limiting conditions for operations and safety limits applicable to Loss of Forced Core Circulation..

OBJECTIVE REF HLO-405 OBJ-1 ORIGIN:

BANK LOD: 2 LOK: F HISTORY:

River Bend NRC Exam 2/2003 BANK QID:

833 QUESTION NO. 76 For Exam SRO K/A Statement:

TIER/GROUP:

1/1 TECHNICAL REFs TS Bases Page B 3.4-14 10 CFR 55 41.3 43.2 K/A SRO RO 295001 2.2.25 3.7 2.5

The plant was operating at rated power when a loss of offsite power occurred. Of the three Diesel Generators, only the HPCS Diesel Generator is operating.

Ten (10) minutes after the loss of power the following conditions exist:

- Post Accident Monitor recorders B21-R623A and B on P601 are indicating (1) RPV pressure is cycling between approximately 926 psig and 1064 psig (2) RPV level is 0 inches and slowly rising.

- SRV F051C is cycling open and closed.

- SRV F051D opened and remained open.

Which of the following abnormal and emergency procedures contain the appropriate action steps to mitigate the consequences of the conditions above?

A. AOP-0004, Loss of Offsite Power and EOP-0001, RPV Control.

B. AOP-0004, Loss of Offsite Power and EOP-0001A, RPV Control - ATWS.

C. AOP-0050, Station Blackout and EOP-0001, RPV Control.

D. AOP-0050, Station Blackout and EOP-0001A, RPV Control - ATWS.

ANSWER: D A - With only HPCS Generator operating, conditions are considered SBO and one SRV open and one cycling indicates power >5% (ATWS condition)

B - With only HPCS Generator operating, conditions are considered SBO.

C - One SRV open and one cycling indicates power >5% (ATWS condition)

Ability to determine/interpret reactor power, pressure, and level as they apply to Partial or Complete Loss of AC Power.

OBJECTIVE REF HLO-513 OBJ-3 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

217 QUESTION NO. 77 For Exam SRO K/A Statement:

TIER/GROUP:

1/1 TECHNICAL REFs AOP-0050, Step 1.1 & 2.1 SOP-0004, Step 1.2 EPSTG-0002, B-6-3 10 CFR 55 43.5 K/A SRO RO 295003 A2.02 4.3 4.2

The plant was operating at 100% power with RCIC inoperable, one day into a 14 day LCO. RCIC was expected to be repaired and returned to operable in three days.

A turbine trip and reactor scram occurs and NNS-SWG1A fails auto transfer leaving the bus de-energized. The Division III Diesel Generator started but had to be tripped and shutdown when a fire was discovered in the engine crankcase.

Four hours later it is estimated that it will take at least five days to return the Division III Diesel to service.

(Technical Specifications 3.8.1, 3.5.1 and 3.5.3 are included as EXAM HANDOUTS)

With the conditions above, what action, if any, is required by Technical Specifications?

A. No action is required as long as RCIC is returned to operable in three days.

B. Reduce steam dome pressure to less than or equal to 150 psig within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

C. Place the plant in Mode 3 within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months .

D. Immediately enter LCO 3.0.3.

ANSWER: B HPCS must be declared INOP then 3.5.3 Action B.2 is required.

A. In Mode 3, RCIC and HPCS still required to be operable and HPCS must be declared INOP C. Must be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

D. Not in 3.0.3 because action for both HPCS and RCIC INOP is provided in 3.5 Ability to determine /interpret the electrical distribution status as it applies to Turbine Trip.

OBJECTIVE REF STM-209 OBJ-H17 ORIGIN:

NEW LOD: 2 LOK: H HISTORY:

BANK QID:

200 QUESTION NO. 78 For Exam SRO K/A Statement:

TIER/GROUP:

TECHNICAL REFs TS 3.5.3 Action B.2 10 CFR 55 43.2 K/A SRO RO 295005 AA2.05 3.3 3.2

Following a refueling outage, a Xenon free reactor startup is in progress with RCS temperature at 130°F. The first five control rods have been fully withdrawn with no detectable change in SRM count rates. At this time, the operating CRD pump trips and the other CRD pump cannot be started. Several minutes later a RPV low water level scram at Level 3 occurs.

The ATC reports that none of the five withdrawn control rods inserted on the scram. All are still fully withdrawn. SRM count rates remain unchanged.

Which one of the following is the correct implementation of the EOPs for this situation?

A. No EOP entry is required, the reactor was never critical.

B. ONLY enter EOP-1, RPV Control, sufficient evidence exists that transitioning to EOP-1A, RPV Control - ATWS is unnecessary.

C. Enter EOP-1, RPV Control, transition to EOP-1A, RPV Control - ATWS, and remain in EOP-1A until Reactor Engineering concurs that the reactor was never critical.

D. Enter EOP-1, RPV Control, transition to EOP-1A, RPV Control - ATWS, and remain in EOP-1A until Reactor Engineering determines the reactor will remain shutdown.

ANSWER: D A - Level 3 is EOP entry condition B and C - RCS temperatures below minimum for critical could cause criticality unless RE determines otherwise.

Knowledge of the operational implications of reactivity control as it applies to scram.

OBJECTIVE REF HLO-513 OBJ-3 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

814 QUESTION NO. 79 For Exam SRO K/A Statement:

TIER/GROUP:

1/1 TECHNICAL REFs EOP-0001 EPSTG-0002, B-6-6 10 CFR 55 43.5 43.6 K/A SRO RO 295006 AK1.03 4

3.7

The plant was operating at 100% power when one of the operating Normal Service Water (NSW) pumps, SWP-P7A tripped. The standby NSW pump, SWP-P7B failed to start. SWP-P7C continued to operate, but service water pressure in both divisional safety related loops dropped to 76 psig momentarily. Then, ONLY Division 2 Standby Service Water initiated.

Which of the following Abnormal Operating Procedures should be entered for this condition?

A. AOP-0016, Loss of Standby Service Water ONLY.

B. AOP-0053, Initiation of Standby Service Water and AOP-0016, Loss of Standby Service Water.

C. AOP-0009, Loss of Normal Service Water and AOP-0016, Loss of Standby Service Water.

D. AOP-0009, Loss of Normal Service Water and AOP-0053, Initiation of Standby Service Water.

ANSWER: B A - AOP-0053 also with one NSW pump running.

B - Not AOP-0009 which is for TOTAL loss of NSW.

C - Not AOP-0009 which is for TOTAL loss of NSW.

Ability to operate/monitor backup systems as they apply to Partial or Complete Loss of Component Cooling Water.

OBJECTIVE REF STM-118 OBJ-H17 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

229 QUESTION NO. 80 For Exam SRO K/A Statement:

TIER/GROUP:

1/1 TECHNICAL REFs AOP-0016, Step 1.1 AOP-0053, Step 1.1 AOP-0009 10 CFR 55 45.3 K/A SRO RO 295018 A1.01 3.4 3.3

A plant startup to rated power is in progress. The plant is operating at 95% power and 95% of rated core flow when a failure of the air supply to the "A" Heater Drain Recirc controller results in a loss of feedwater heating and entry into AOP-0007.

The Reactor Engineer runs a Core Monitoring Case and reports that CMFLCPR is 1.002.

Tech Spec LCO 3.2.2 and the applicable COLR pages are included as EXAM HANDOUT MATERIAL.

Which one of the following describes the actions, if any, that are required for this condition?

A. No action is required.

B. Restore MCPR to within the limits within two (2) hours or reduce power to <23.8%

within the next four (4) hours.

C. Restore MCPR to within the limits within two (2) hours or reduce power to <23.8%

within the next two (2) hours.

D. Restore MCPR to within the limits and insert all insertable control rods within two (2) hours ANSWER: B REQUIRES TS 3.2.2 AND COLR PAGES 25 & 30 INCLUDED AS EXAM HANDOUTS A - Exceeded LCO when CMFLCPR is greater than 1.0 requiring action.

C - The four hours to reduce power is in addition to the two hours to restore to within limits.

D - Using COLR limiting value of MCPRp at 1.2 and CMFLCPR value of 1.002, measured MCPR is:

MCPR = MCPRp/CMFLCPR = 1.21/1.002 = 1.207 which does not violate SL.

Ability to recognize indications for system operating parameters which are entry-level conditions fo technical specifications.

OBJECTIVE REF STM-011 OBJ-11 ORIGIN:

MODIFIED LOD: 2 LOK: H HISTORY:

River Bend NRC Exam 10/2000 BANK QID:

815 QUESTION NO. 81 For Exam SRO K/A Statement:

TIER/GROUP:

1/1 TECHNICAL REFs COLR Pages 25 & 30 TS 3.2.2 10 CFR 55 43.2 K/A SRO RO 295019 2.1.33 4

3.4

The plant is performing the In-Service Pressure Test (Vessel Hydro) on the reactor following refueling operations. A miscommunication results in a significant rise in reactor pressure. The following RPV pressure indications were observed in the Main Control Room:

- Wide range Reactor Pressure C33-R605 on P680 went offscale high (>1200 psig).

- Post Accident recorders B21-R623A and B on P601 indicated RPV pressure had reached 1350 psig.

Which one of the following is a correct assessment of this condition regarding the RBS Technical Specifications and any required reporting?

A. The TS Safety Limit for reactor pressure was exceeded and the NRC Operations Center must be notified within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

B. The TS Safety Limit for reactor pressure was exceeded and the NRC Operations Center must be notified within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

C. Only the TS LCO for Reactor Steam Dome Pressure must be entered and NO reporting is required.

D. NO TS Safety Limits or LCOs were violated and NO reporting is required.

ANSWER: A B - Reporting time for Plant Manager and VP following SL violation.

C - Pressure exceeded 1075 psig, but LCO is only applicable in Modes 1 and 2.

D - SL violation with dome pressure on PAM recorders >1325 psig.

Knowledge of which events related to system operations/status that should be reported to outside agencies as it applies to High Reactor Pressure.

OBJECTIVE REF HLO-219 OBJ-1 ORIGIN:

MODIFIED LOD: 2 LOK: F HISTORY:

River Bend NRC Exam 2/1999 BANK QID:

931 QUESTION NO. 82 For Exam SRO K/A Statement:

TIER/GROUP:

1/1 TECHNICAL REFs RBS TS Page 2.0-1 10 CFR 55 43.2 K/A SRO RO 295025 2.4.30 3.6

With the plant operating at 100% power, the following sequence of events and actions have occurred at the times specified.

- 1020 Large Break LOCA in the Drywell and the reactor scrammed.

- 1030 EOP-0004, RPV Flooding was entered due to high Drywell temperature and RPV pressure at 5 psig

- 1031 6 SRVs were opened and remain open

- 1036 Injection sources for RPV Flooding raised RPV pressure above 42 psig and Drywell temperatures were lowering.

Assuming RPV pressure is maintained above 42 psig until the Minimum Core Flooding Interval is achieved, what are the times for the Minimum Core Flooding Interval (MCFI) and the Maximum Core Uncovery Time Limit (MCUTL)?

(EOP Figure 3 and Table 1 included as EXAM HANDOUTS.)

MCFI MCTUL A. 46 min. 2.8 min.

B. 46 min. 3.4 min.

C. 64 min. 3.4 min.

D. 64 min. 4.5 min.

ANSWER: C REQUIRES EOP FIGURE 3 AND TABLE 1 A - Incorrect MCFI (for 7 SRVs open) and MCUTL was determined using MCFI instead of time after Shutdown B - Incorrect MCFI, (for 7 SRVs open)

D - Correct MCFI but miscalulated time after shutdown making MCUTL too high.

Ability to perform specific system and integrated plant procedures during different modes of plant operation as applicable to High Drywell Temperature.

OBJECTIVE REF HLO-512 OBJ-7 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

932 QUESTION NO. 83 For Exam SRO K/A Statement:

TIER/GROUP:

1/1 TECHNICAL REFs EOP-0004, RF-10 & RF-12 10 CFR 55 43.5 K/A SRO RO 295028 2.1.23 4

The CRVICS logic for a full MSIV closure and Inboard Balance of Plant isolation was inadvertently actuated with the plant at 100% power. All isolation valves and dampers closed as expected and an automatic reactor scram occurred from the MSIV closure.

Fifteen minutes later, Suppression Pool level has lowered to 18.5 feet and Containment pressure has risen to 5 psig.

Which of the following would be the reason for the containment pressure and any required actions? (EOP Figure 4, Pressure Suppression Pressure included as EXAM HANDOUT.)

A. Loss of containment cooling requiring normal containment venting B. Loss of containment cooling requiring emergency containment venting C. Excessive Post-LOCA drywell bypass leakage requiring emergency containment venting D. Excessive Post-LOCA Drywell bypass leakage requiring Emergency Depressurization ANSWER: D ED required due to being in unsafe region of PSP curve.

A - Pressure too high for just loss of containment cooling and prohibits normal containment venting B - Pressure too high for just loss of containment cooling and emergency venting not required (C)

C - Emergency containment venting is not required until pressure is approaching 30 psig.

Knowledge of the reasons for Drywell/containment pressure response as they apply to Inadvertent Containment Isolation.

OBJECTIVE REF HLO-514 OBJ-6 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

933 QUESTION NO. 84 For Exam SRO K/A Statement:

TIER/GROUP:

1/2 TECHNICAL REFs EOP-0002, CP-4 & Fig. 4 10 CFR 55 41.9 43.5 K/A SRO RO 295020 AK3.02 3.5

Given the following conditions

- RCIC tripped and Isolation Valves E51-F063, E51-F064 failed to close.

- RCIC Equipment Room Area Radiation: 1.2 E+04 mr/hr

- RCIC Equipment Room Area Temperature: 207°F Which of the following is the bases for initiating a Reactor Scram with the above conditions?

EOP-0003 included as EXAM HANDOUT.

A. The scram will begin to reduce the energy that the RPV will discharge to the RCIC room to that of decay heat.

B. Emergency Depressurization is required.

C. Failure of Secondary Containment due to high temperatures must be assumed and the scram will stop the radioactive release.

D. A scram will immediately significantly reduce the driving head and flow through the break in the RCIC room.

ANSWER: A REQUIRES EOP-0003 AS EXAM HANDOUT MATERIAL B - Correct for EOP-3 SC-21 C - Secondary Containment is not assumed to have failed at this point.

D - Correct for EOP-3 SC-21, The Scram in itself will not significantly decrease driving head until RPV pressure is lowered.

Knowledge of the reasons for reactor SCRAM as they apply to High Secondary Containment Area Temperature.

OBJECTIVE REF HLO-515 OBJ-4 ORIGIN:

NEW LOD: 3 LOK: F HISTORY:

BANK QID:

934 QUESTION NO. 85 For Exam SRO K/A Statement:

TIER/GROUP:

1/2 TECHNICAL REFs EPSTG-0002, Page B-9-13 10 CFR 55 43.5 K/A SRO RO 295032 EK3.02 3.8

During plant operation at rated power, the ANNULUS PRESSURE HIGH alarm on P863 is received. The following parameter values exist:

- Outside air temperature is 81°F

- Annulus air temperature is 85°F

- Annulus pressure on LMS-TR127 reads -2.9 inches water column

- Auxiliary building pressure on HVR-PDI247 reads -0.25 inches water column The ARP for ANNULUS PRESSURE HIGH, applicable pages of STP-000-0001 and Technical Specifications are included as EXAM HANDOUT MATERIAL.

Given the conditions above determine if Annulus pressure is within Technical Specification limits and if EOP-0003 entry is required.

A. NEITHER EOP-0003 NOR TS LCO entry is required.

B. EOP-0003 entry IS NOT required, TS LCO entry IS required.

C. EOP-0003 entry IS required, TS LCO entry IS NOT required.

D. BOTH EOP-0003 and TS LCO entry ARE required.

ANSWER: A REQUIRES ARP-P863-72A-A01, STP-000-001, PAGES 16 & 33, AND TS 3.4.6.1 AS EXAM HANDOUT MATERIALS Based on the corrected value being in acceptable side of STP-000-0001, Page 33 curve.

B - While Annulus pressure value of -2.9" WC is less than LCO limit of 3.0 inches vacuum, when corrected to 3.15 it is acceptable. Correction to make annulus pressure relative to atmospheric.

C - EOP-0003 matches TS in that it is Annulus pressure relative to atmospheric D - See B & C Ability to determine/interpret secondary containment pressure as it applies to Secondary Containment High Differential Pressure.

OBJECTIVE REF STM-403 OBJ-H10 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

950 QUESTION NO. 86 For Exam SRO K/A Statement:

TIER/GROUP:

1/2 TECHNICAL REFs ARP-P863-72A-A01 STP-000-0001, Pages 16 & 33 TS 3.6.4.1 EOP-0003, Entry Conditions 10 CFR 55 43.5 K/A SRO RO 295035 EA2.01 3.9

Complete the following statement, regarding the Containment Hydrogen Deflagration Overpressure Limit (HDOL) curve in the EOPs.

As containment pressure rises,...

A. the maximum allowed hydrogen concentration lowers due to the reduced capability of the Hydrogen Recombiners at higher containment pressure.

B. the maximum allowed hydrogen concentration lowers because the deflagration pressure of hydrogen lowers.

C. the maximum allowed hydrogen concentration rises because it takes a higher concentration of hydrogen to burn at higher pressures.

D. the maximum allowed hydrogen concentration lowers to ensure that a hydrogen deflagration at the limit combined with current pressure will not exceed containtment overpressure failure limits.

ANSWER: D Ability to determine/interpret combustible limits for wetwell as they apply to High Primary Containment Hydrogen Concentrations.

OBJECTIVE REF HLO-514 OBJ-8 ORIGIN:

BANK LOD: 2 LOK: H HISTORY:

River Bend NRC Exam 10/2000 BANK QID:

674 QUESTION NO. 87 For Exam SRO K/A Statement:

TIER/GROUP:

1/2 TECHNICAL REFs EPSTG-0002, App. A EOP-1 Figure 5 10 CFR 55 43.5 K/A SRO RO 500000 EA2.04 3.3 3.3

RHR A has just been placed in Shutdown Cooling Mode following a plant shutdown for a refuel outage.

During the outage, which one of the following changes in the status of Shutdown Cooling REQUIRES Duty Manager notification?

A. Adjusting the cooldown rate of the operating shutdown cooling loop by closing the RHR Heat Exchanger Bypass Valve.

B. Shifting shutdown cooling from RHR A to RHR B loops in order to conduct scheduled outage maintenance on Division 1 equipment.

C. Placing RHR B in service for shutdown cooling due to a trip of the RHR A pump.

D. Removing RHR A from shutdown cooling in preparation for a reactor startup after the refueling outage.

ANSWER: C AOP entry (AOP-0051 for Loss of Decay Heat Removal) requires Duty Manager Notification A - Normal system adjustment for shutdown cooling ops.

B - Planned evolution during an outage.

D - Planned evolution in preparation for mode change.

Knowledge of Shutdown Cooling system status criteria which require the notification of plant personnel.

OBJECTIVE REF HLO-206 OBJ-ORIGIN:

NEW LOD: 2 LOK: F HISTORY:

BANK QID:

936 QUESTION NO. 88 For Exam SRO K/A Statement:

TIER/GROUP:

2/1 TECHNICAL REFs OSP-0046, Page 8 10 CFR 55 43.5 K/A SRO RO 205000 2.1.14 3.3

The plant is operating at 85% power. The Manual Scram Pushbutton Surveillance is being performed. After arming and depressing the last Manual Scram Pushbutton for DIV 4, the half scram is reset. However, a failure of the K14D relay contacts to reclose when re-energized results in the B RPS DIV 4 SCRAM SOV VALVES OPEN light above the DIV 4 Manual Scram Pushbutton on P680 remaining out. All other RPS scram solenoid valve white lights on P680 are lit.

If a loss of RPS Bus A occurs at this time, which one of the following is the expected response and appropriate action to be taken?

A. None of the control rods will scram. Transfer RPS Bus A to Alternate power per AOP-0010, Loss of RPS Bus.

B. Approximately 1/4 of the control rods will scram. Manually scram the reactor and enter AOP-0001 and AOP-0010.

C. Approximately 1/4 of the control rods will scram. Transfer RPS Bus A to Alternate power per AOP-0010, Loss of RPS Bus.

D. All of the control rods will scram. Manually scram the reactor and enter AOP-0001 and AOP-0010.

ANSWER: B Manual Scram to close SDV vent and drain valves and prevent fuel damage.

A - 1/4 of the control rods will scram due to both scram pilot valve solenoids being de-energized.

C - SDV vent and drain valves may be open with 1/4 of control rods scrammed.

D - Only 1/4 of the control rods will scram.

Ability to predict the impacts of the failure of individual relays to reposition on RPS; and use procedures to correct, control, or mitigate.

OBJECTIVE REF STM-508 OBJ-H8 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

937 QUESTION NO. 89 For Exam SRO K/A Statement:

TIER/GROUP:

2/1 TECHNICAL REFs STM-508, Figures 7 & 16 STM-508, Page 22 10 CFR 55 43.5 43.6 K/A SRO RO 212000 A2.21 3.9

The plant is operating at 100% power with no LCOs. With the Division III Battery Charger tagged out for maintenance, the Backup Battery Charger, BYS-CHGR1D, is connected to the Div III 125 VDC switchgear, E22-PNLS001.

Based on the above conditions, Technical Specification LCO 3.8.4 entry...

(Technical Specification 3.8.4 is included as EXAM HANDOUT material.)

A. IS REQUIRED because the Backup Charger IS NOT capable of maintaining the Div. III battery parameters within surveillance requirements.

B. IS REQUIRED because the Backup Charger IS NOT a safety related charger.

C. IS NOT REQUIRED as long as the Backup Charger CAN maintain the Div. III battery parameters within surveillance requirements.

D. IS NOT REQUIRED because the Backup Charger IS a safety related charger.

ANSWER: B A - Can maintain parameters but is not safety related and cannot be used to meet 3.8.4.

C - Must enter even with surveillance reqirements met.

D - Must enter because it is NOT safety related.

Ability to explain and apply D. C. Electrical Distribution system limits and precautions.

OBJECTIVE REF STM-305 OBJ-H7 ORIGIN:

NEW LOD: 3 LOK: H HISTORY:

BANK QID:

946 QUESTION NO. 90 For Exam SRO K/A Statement:

TIER/GROUP:

2/1 TECHNICAL REFs TS 3.8.4 SOP-0049, P&L 2.5 10 CFR 55 43.2 K/A SRO RO 263000 2.1.32 3.8

The plant is operating at 100% power with Standby Service Water Pump, SWP-P2A, inoperable since 0800 this morning. At 1200 while being load tested in parallel with offsite power, the Division III (HPCS) Diesel Generator tripped due to a failure of the governor. The governor failure caused the an exessive load on the generator and subsequent output breaker trip.

Assuming all efforts to repair SWP-P2A and the Division III Diesel governor are unsuccessful, when must the plant be in MODE 3?

(Technical Specifications 3.7.1 and 3.8.1 are included as EXAM HANDOUTS)

A. 30 days + 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from 0800 this morning.

B. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from 1200 today.

C. 17 days + 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from 1200 today.

D. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months from 1200 today.

ANSWER: D A -

B -

C -

Ability to predict the impacts of operating unloaded, lightly loaded, and highly loaded on the EDGs; and use procedures to correct, control, or mitigate.

OBJECTIVE REF STM-309S OBJ-H7 ORIGIN:

NEW LOD: 2 LOK: H HISTORY:

BANK QID:

232 QUESTION NO. 91 For Exam SRO K/A Statement:

TIER/GROUP:

2/1 TECHNICAL REFs AOP-0003 AOP-0001 ADM-0022 10 CFR 55 CFR K/A SRO RO 264000 A2.03 3.4

Given the following initial conditions for the Inclined Fuel Transfer (IFTS) System:

- IFTS Tube is full

- Upper upender inclined

- Carriage at upper terminal

- Lower upender inclined

- System powered up and neither bridge in the IFTS area SELECT the correct statement regarding IFTS operation.

A. The transfer tube can be drained.

B. The refueling bridge can enter the IFTS area.

C. The fuel handling bridge can enter the IFTS area in the Fuel Building.

D. The winch can be lowered using the "lower" pushbutton on the upper control panel.

ANSWER: D Ability to monitor automatic operations of Fuel Handling Equipment including interlock operation.

OBJECTIVE REF STM-055 OBJ-H4 ORIGIN:

MODIFIED LOD: 3 LOK: H HISTORY:

River Bend NRC Exam 2/2003 BANK QID:

882 QUESTION NO. 92 For Exam SRO K/A Statement:

TIER/GROUP:

2/2 TECHNICAL REFs STM-055, Pages 12 & 37 10 CFR 55 41.4 41.6 43.7 K/A SRO RO 234000 A3.02 3.7 3.1

During a refueling outage, an irradiated fuel bundle is being moved from the Reactor to the Dryer Storage Pool.

The fuel bundle's lifting bail fails and the bundle falls into the reactor vessel between the vessel wall and the shroud (downcomer area) on the Northeast side of the Reactor Vessel. It appears that bundle integrity is maintained as NO BUBBLES are rising to the surface of the Reactor Cavity.

Personnel working in which one of the following locations would run the highest risk of overexposure due to hig radiation levels?

A. The Drywell.

B. The Refuel floor.

C. The Containment.

D. The Steam Tunnel.

ANSWER: A Only shielded by RPV wall.

B - Shielded by depth of water in RPV and Refuel Cavity C - Shielded by Drywell wall.

D - Shielded by RPV water based on location of bundle and Drywell wall.

Knowledge of the effect a loss or malfunction of the Reactor Vessel Internals will have on plant radiation levels.

OBJECTIVE REF HLO-535 OBJ-5 ORIGIN:

MODIFIED LOD: 2 LOK: H HISTORY:

FitzPatrick NRC 7/2003 (INPO 25621)

BANK QID:

940 QUESTION NO. 93 For Exam SRO K/A Statement:

TIER/GROUP:

2/2 TECHNICAL REFs AOP-0027, Page 4 10 CFR 55 43.4 43.6 43.7 K/A SRO RO 290002 K3.04 3.2

During an Emergency, the CRS determines that the only action appropriate to maintain the plant in a safe condition will NOT be in compliance with the station's operating license.

Whose permission, at a MINIMUM, is required to take that action and when must the NRC be notified?

A. Licensed Senior Reactor Operator (SRO); notify the NRC within one (1) hour B. General Manager-Operations; notify the NRC within four (4) hours C. Licensed Senior Reactor Operator (SRO); notify the NRC within four (4) hours D. Site Duty Manager; notify the NRC within four (4) hours ANSWER: A Knowledge of conduct of operations requirements.

OBJECTIVE REF HLO-206 OBJ-6 ORIGIN:

BANK LOD: 2 LOK: F HISTORY:

River Bend Audit Exam 1/2003 BANK QID:

1063 QUESTION NO. 94 For Exam SRO K/A Statement:

TIER/GROUP:

3 TECHNICAL REFs LI-108 REAP, RAF 1.5 10 CFR 55 43.3 43.1 K/A SRO RO 2.1.1 3.8 3.7

In implementing AOP-0031, Shutdown From Outside The Main Control Room, after evacuation of the Control Room the Operations Shift Manager is required to report to the...

A. Div I Remote Shutdown Panel to assist the CRS in directing plant operations.

B. Div II Remote Shutdown Panel to provide oversite and support for the CRS.

C. Operations Support Center to coordinate support required by the CRS.

D. Technical Support Center to implement the EIPs as Emergency Director.

ANSWER: D A - May report here initially but not required B - CRS will be at Div I RSP not Div II and OSM is required to report to TSC.

C - Building Operators report to OSC and a designated OSC Manager coordinates support.

Knowledge of operator responsibilities during all modes of plant operation.

OBJECTIVE REF HLO-537 OBJ-1 ORIGIN:

MODIFIED LOD: 2 LOK: F HISTORY:

River Bend NRC Exam 1/1997 BANK QID:

624 QUESTION NO. 95 For Exam SRO K/A Statement:

TIER/GROUP:

3 TECHNICAL REFs AOP-0031, Page 5 10 CFR 55 43.5 41.10 K/A SRO RO 2.1.2 4

3

A proposed plant modification must always have prior approval from the NRC if...

A. it requires a 50.59 evaluation.

B. it involves a system described in the RBS USAR.

C. it involves a system included in the RBS Technical Specifications.

D. it results in a design basis limit for Primary Containment being altered.

ANSWER: D A - This evaluation will determine if NRC approval is required B - Must have a 50.59 evaluation but not necessarily NRC approval C - Must have a 50.59 evaluation but not necessarily NRC approval Knowledge of the process for making changes in the facility as described in the SAR.

OBJECTIVE REF HLO-200 OBJ-2 ORIGIN:

NEW LOD: 3 LOK: F HISTORY:

BANK QID:

876 QUESTION NO. 96 For Exam SRO K/A Statement:

TIER/GROUP:

3 TECHNICAL REFs 10CFR50.59 LI-101 10 CFR 55 43.3 K/A SRO RO 2.2.5 2.7 1.6

During Startup while in Mode 2, Leakage Computer report contains the following:

- 0.37 gpm Unidentified Leakage

- 3.34 gpm Identified Leakage.

Which one of the following subsequent changes in leakage requires entry into the Technical Specification LCO for Reactor Coolant System Leakage?

Technical Specification 3.4.5 is included as EXAM HANDOUT MATERIAL.

A. Additional 2.1 gpm leakage into the Containment Building Floor Drain Sump in the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. A leak from the E12-F0041B RHR Injection check valve bonnet seal inside the Drywell C. Additional leakage of 26.66 gpm leakage into the Containment Building Equipment Drain Sump averaged over 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months D. Additional 4.66 gpm leak into the Pedestal Floor Drain ANSWER: D REQUIRES TS 3.4.5 INCLUDED IN EXAM HANDOUT MATERIAL.

A - Tech Spec 3.4.5.d only required in Mode 1 B - Bonnet Seal Leakage is exempt from Pressure Boundary Leakage C - Required to be averaged over 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Knowledge of limiting conditions for operations and safety limits.

OBJECTIVE REF STM-207 OBJ-H8 ORIGIN:

NEW LOD: 2 LOK: H HISTORY:

BANK QID:

926 QUESTION NO. 97 For Exam SRO K/A Statement:

TIER/GROUP:

3 TECHNICAL REFs TS LCO 3.4.5 10 CFR 55 41.3 41.5 K/A SRO RO 2.2.22 4.1 3.4

The plant is operating at 100% power.

The Control Room Supervisor has a tagout that requires independent verification.

The Operations Shift Manager should NOT grant a waiver for independent verification if the valves to be tagged are located...

A. in a locked high radiation area.

B. near the Main Turbine Control Valves.

C. inside the Containment in a contaminated area.

D. in the RWCU Pump Room.

ANSWER: C Knowledge of 10CFR20 and related facility radiation control procedures.

OBJECTIVE REF HLO-201 OBJ-12 ORIGIN:

MODIFIED LOD: 2 LOK: F HISTORY:

River Bend NRC Exam 2/2003 BANK QID:

632 QUESTION NO. 98 For Exam SRO K/A Statement:

TIER/GROUP:

3 TECHNICAL REFs ADM-0076, Page 15 10 CFR 55 43.4 41.10 K/A SRO RO 2.3.1 3

2.6

Given the following conditions:

- The Main Control Room has been evacuated due to a fire.

- All AOP-0031 immediate operator actions are complete, however the shutdown status of the reactor could not be determined prior to evacuation.

- Control of the plant has been established at the Remote Shutdown Panel.

- Indications of an ATWS exist 12 minutes after evacuating the control room Which one of the following describes the correct action to be taken by the CRS?

A. Carry out the actions of AOP-0031 (Shutdown From Outside the Main Control Room) ONLY.

B. Enter EOP-0001, then execute EOP-0001A, RPV Control - ATWS and continue to carry out the actions of AOP-0031.

C. Execute EOP-0001, RPV Control and continue to carry out the actions of AOP-0031.

D. Execute EOP-0001A, RPV Control and exit AOP-0031.

ANSWER: B A - EOPs take priority over AOPs C - Must transition to execute EOP-0001A with ATWS conditions present D - Must enter EOP-0001A through EOP-0001 and should not exit AOP-0031.

Knowledge of the organization of the operating procedures network for normal, abnormal, and emergency evolutions.

OBJECTIVE REF HLO-537 OBJ-1 ORIGIN:

MODIFIED LOD: 2 LOK: H HISTORY:

River Bend NRC Exam 10/2000 BANK QID:

675 QUESTION NO. 99 For Exam SRO K/A Statement:

TIER/GROUP:

3 TECHNICAL REFs EPSTG-0002, B-4-7 10 CFR 55 43.5 K/A SRO RO 2.4.5 3.6 2.9

The reactor is shutdown with no injection subsystems or alternate injection subsystems running.

Given the following RPV level and pressure conditions, in which case is Emergency Depressurization REQUIRED? (EOP-0004, Sheets 1 and 2 included as EXAM HANDOUTS)

A. Level is -180 inches and slowly lowering, Pressure is 400 psig and slowly rising.

B. Level is -190 inches and slowly lowering, Pressure is 200 psig and slowly lowering.

C. Level is -190 inches and slowly lowering, Pressure is 300 psig and slowly rising.

D. Level is -200 inches and slowly lowering, Pressure is 450 psig and stable.

ANSWER: C Rising pressure in Steam Cooling requires transition to Emergency Depressurization (STC-4 & 5)

A - Adequate core cooling exists with level above the MSCRWL (-186") regardless of trends. With no injection Emergency Depressurization is NOT REQUIRED B - Same as D.

D - Expected condtions for steam cooling, Emergency Depressurization NOT REQUIRED till -202.

Knowledge of the parameters and logic used to assess the status of safety functions including (2)

Core cooling and heat removal OBJECTIVE REF HLO-512 OBJ-7 ORIGIN:

MODIFIED LOD: 3 LOK: H HISTORY:

River Bend NRC Exam 2/2003 BANK QID:

370 QUESTION NO. 100 For Exam SRO K/A Statement:

TIER/GROUP:

3 TECHNICAL REFs EOP-0004, STC-4 and 5 EPSTG-0002, Page 12-8 10 CFR 55 43.5 K/A SRO RO 2.4.21 4.3 4.6

HANDOUT MATERIALS for the September 17, 2004 River Bend NRC SRO Written Exam

For SRO Question 3

For SRO Question 6

CONTINUOUS USE ATTACHMENT 2 PAGE 1 OF 6 REACTOR COOLDOWN DATA AOP-0031 REV - 19 PAGE 40 OF 118 START TIME PLUS ACTUAL TIME RPV PRESSURE RPV TEMPERATURE FROM STEAM TABLES RPV TEMPERATURE FROM PYROMETER (RPV COOLANT LESS THAN 212°F)

HRS MIN 0

15 30 45 60 1

15 30 45 60 2

15 30 45 60 3

15 30 45 60 4

15 30 45 60 5

15 30 45 60

CONTINUOUS USE ATTACHMENT 2 PAGE 2 OF 6 REACTOR COOLDOWN DATA AOP-0031 REV - 19 PAGE 41 OF 118 START TIME PLUS ACTUAL TIME RPV PRESSURE RPV TEMPERATURE FROM STEAM TABLES RPV TEMPERATURE FROM PYROMETER (RPV COOLANT LESS THAN 212°F)

HRS MIN 6

15 30 45 60 7

15 30 45 60 8

15 30 45 60 9

15 30 45 60 10 15 30 45 60 11 15 30 45 60

CONTINUOUS USE ATTACHMENT 2 PAGE 3 OF 6 REACTOR COOLDOWN DATA AOP-0031 REV - 19 PAGE 42 OF 118 START TIME PLUS ACTUAL TIME RPV PRESSURE RPV TEMPERATURE FROM STEAM TABLES RPV TEMPERATURE FROM PYROMETER (RPV COOLANT LESS THAN 212°F)

HRS MIN 12 15 30 45 60 13 15 30 45 60 14 15 30 45 60 15 15 30 45 60 16 15 30 45 60 17 15 30 45 60

CONTINUOUS USE ATTACHMENT 2 PAGE 4 OF 6 REACTOR COOLDOWN DATA AOP-0031 REV - 19 PAGE 43 OF 118 START TIME PLUS ACTUAL TIME RPV PRESSURE RPV TEMPERATURE FROM STEAM TABLES RPV TEMPERATURE FROM PYROMETER (RPV COOLANT LESS THAN 212°F)

HRS MIN 18 15 30 45 60 19 15 30 45 60 20 15 30 45 60 21 15 30 45 60 22 15 30 45 60 23 15 30 45 60

CONTINUOUS USE ATTACHMENT 2 PAGE 5 OF 6 REACTOR COOLDOWN DATA AOP-0031 REV - 19 PAGE 44 OF 118 STEAM TABLE RPV Pressure (psig)

Sat. Steam Temperature (°F) 1100 557 1050 552 1000 546 950 540 900 533 850 527 800 520 750 513 700 505 650 497 600 489 550 479 500 470 450 459 400 448 350 435 300 421 250 406 200 388 150 366 100 338 50 298

CONTINUOUS USE ATTACHMENT 2 PAGE 6 OF 6 REACTOR COOLDOWN DATA AOP-0031 REV - 19 PAGE 45 OF 118 Remarks:

Performed By: /

Signature KCN Initials Date/Time

/

Signature KCN Initials Date/Time

/

Signature KCN Initials Date/Time Reviewed By:

OSM/CRS KCN Date/Time

For SRO Question 7

For SRO Question 36

A 60 s 10 s

-100 s D

60 s 10 s

-100 s C

60 s 10 s

-100 s B

60 s 10 s

-100 s Core Midplane Core Bottom Core Bottom Core Midplane Core Midplane Core Midplane Core Bottom Core Bottom DRAWING FOR QUESTION 36

For SRO Question 75

ARP-680-04 REV 20 PAGE 11 OF 87 ALARM NO. 2158 RECIRC LOOP A LOW T H13-P680/04A/A05 INITIATING DEVICES SETPOINTS

1. K702A Relay

1.

Less than 8.6°F difference between Reactor Steam Dome temperature and Recirc Pump A suction temperature.

AUTOMATIC ACTIONS

1. IF Recirc Pump B AND Recirc Pump A are 95% speed, THEN Recirc Pump A trips to OFF after a 15 minute time delay.

2. IF Recirc Pump B is <95% speed AND Recirc Pump A is 95% speed, THEN Recirc Pump A downshifts to 25% speed (Slow Speed) after a 15 minute time delay.

OPERATOR ACTIONS

1. Verify Automatic Actions.

2. Perform the following:

Monitor Recirc Pump vibration levels.

IF Recirc Pump vibration levels are excessive, THEN downshift the Recirc Pump to 25% speed AND Go To AOP-0024, Thermal Hydraulic Stability Controls.

NOTE Video Service Screen 46 can be used to validate the low T condition.

Validate the low T condition.

3. IF the Recirc Pump trips, THEN Refer To GOP-0004, Single Loop Operation.

4. IF Recirc Pump downshifts to 25% speed, THEN Go To AOP-0024, Thermal Hydraulic Stability Controls.

5. IF the low T condition is not valid, THEN place key operated switch B33-S125A, STEAM DOME/PUMP SUCTION T INTERLOCK BYPASS, in BYPASS.

LONG TERM ACTIONS

1. IF B33-S125A was placed in BYPASS, THEN continuously monitor the following which may indicate possible Jet Pump or Recirc Pump cavitation:

a.

Power to Flow Map,

b. Recirc Pump vibration, and

c.

Jet Pump Performance.

2. IF the low T condition is valid, THEN initiate a Condition Report to track the cumulative time for pump cavitation (maximum = 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months ).

ARP-680-04 REV 20 PAGE 12 OF 87 ALARM NO. 2158 RECIRC LOOP A LOW T H13-P680/04A/A05 POSSIBLE CAUSES

1. Reactor pressure decrease.

2. Instrument malfunction (steam dome pressure temperature conversion, recirc pump suction temperature).

REFERENCES

1. GE-NE-B3300280-01 (CR95-1216)

2. MR 96-0004

For SRO Question 78

ECCS Operating 3.5.1 RIVER BEND 3.5-1 Amendment No. 81 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS -Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of seven safety/relief valves shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3, except ADS valves are not required to be OPERABLE with reactor steam dome pressure 100 psig.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One low pressure ECCS injection/spray subsystem inoperable.

A.1 Restore low pressure ECCS injection/spray subsystem to OPERABLE status.

7 days B.

High Pressure Core Spray (HPCS) System inoperable.

B.1 Verify by administrative means RCIC System is OPERABLE when RCIC is required to be OPERABLE.

AND B.2 Restore HPCS System to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days (continued)

ECCS Operating 3.5.1 RIVER BEND 3.5-2 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Two ECCS injection subsystems inoperable.

OR One ECCS injection and one ECCS spray subsystem inoperable.

C.1 Restore one ECCS injection/spray subsystem to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months D.

Required Action and associated Completion Time of Condition A, B, or C not met.

D.1 Be in MODE 3.

AND D.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours E.

One ADS valve inoperable.

E.1 Restore ADS valve to OPERABLE status.

14 days F.

One ADS valve inoperable.

AND One low pressure ECCS injection/spray subsystem inoperable.

F.1 Restore ADS valve to OPERABLE status.

OR F.2 Restore low pressure ECCS injection/spray subsystem to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 72 hours G.

Two or more ADS valves inoperable.

OR G.1 Be in MODE 3.

AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

ECCS Operating 3.5.1 RIVER BEND 3.5-3 Amendment No. 81 ACTIONS CONDTION REQUIRED ACTION COMPLETION TIME G.

(continued)

Required Action and associated Completion Time of Condition E or F not met.

G.2 Reduce reactor steam dome pressure to 100 psig.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H.

HPCS and Low Pressure Core Spray (LPCS)

Systems inoperable.

OR Three or more ECCS injection/spray subsystems inoperable.

OR HPCS System and one or more ADS valves inoperable.

OR Two or more ECCS injection/spray subsystems and one or more ADS valves inoperable.

H.1 Enter LCO 3.0.3.

Immediately

ECCS Operating 3.5.1 RIVER BEND 3.5-4 Amendment No. 81 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve.

31 days SR 3.5.1.2

NOTE----------------------------------

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut in permissive pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

Verify each ECCS injection/spray subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

31 days SR 3.5.1.3 Verify ADS accumulator supply pressure is 131 psig.

31 days SR 3.5.1.4 Verify each ECCS pump develops the specified flow rate with the specified pump differential pressure.

PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPCS 5010 gpm 282 psid LPCI 5050 gpm 102 psid HPCS 5010 gpm 415 psid In accordance with the Inservice Testing Program (continued)

ECCS Operating 3.5.1 RIVER BEND 3.5-5 Amendment No. 81, 130 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.5

NOTE--------------------------------

Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal.

18 months SR 3.5.1.6

NOTE------------------------------

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated automatic initiation signal.

18 months SR 3.5.1.7

NOTE-------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify each ADS valve relief mode actuator strokes when manually actuated.

In accordance with the Inservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid SR 3.5.1.8

NOTE------------------------------

ECCS actuation instrumentation is excluded.

Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits.

18 months

RCIC System 3.5.3 RIVER BEND 3.5-10 Amendment No. 81 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY:

MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

RCIC System inoperable.

A.1 Verify by administrative means High Pressure Core Spray System is OPERABLE.

AND A.2 Restore RCIC System to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days B.

Required Action and associated Completion Time not met.

B.1 Be in MODE 3.

AND B.2 Reduce reactor steam dome pressure to 150 psig.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours

RCIC System 3.5.3 RIVER BEND 3.5-11 Amendment No. 81, 114 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System piping is filled with water from the pump discharge valve to the injection valve.

31 days SR 3.5.3.2 Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

31 days SR 3.5.3.3

NOTE----------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure 1075 psig and 920 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure.

92 days SR 3.5.3.4

NOTE----------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure 165 psig and 150 psig, the RCIC pump can develop a flow rate 600 gpm against a system head corresponding to reactor pressure.

18 months (continued)

RCIC System 3.5.3 RIVER BEND 3.5-12 Amendment No. 81 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.5

NOTE---------------------------------

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation signal.

18 months

AC SourcesOperating 3.8.1 RIVER BEND 3.8-1 Amendment No. 81 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC SourcesOperating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a.

Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electric Power Distribution System; and

b.

Three diesel generators (DGs).

APPLICABILITY:

MODES 1, 2, and 3.

NOTE------------------------------------------------

Division III AC electrical power sources are not required to be OPERABLE when High Pressure Core Spray System and Standby Service Water System pump 2C are inoperable.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One required offsite circuit inoperable.

A.1 Perform SR 3.8.1.1 for OPERABLE required offsite circuit.

AND 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-2 Amendment No. 81, 125 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.2 Restore required offsite circuit to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery of two divisions with no offsite power AND 17 days from discovery of failure to meet LCO B.

One required DG inoperable.

B.1 Perform SR 3.8.1.1 for OPERABLE required offsite circuit(s).

AND B.2 Declare required feature(s), supported by the inoperable DG, inoperable when the redundant required feature(s) are inoperable.

AND 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition B concurrent with inoperability of redundant required feature(s)

(continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-3 Amendment No. 81, 125 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B.

(continued)

B.3.1 Determine OPERABLE DG(s) are not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for OPERABLE DG(s).

AND B.4 Restore required DG to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from discovery of an inoperable Division III DG AND 14 days AND 17 days from discovery of failure to meet LCO C.

Two required offsite circuits inoperable.

C.1 Declare required feature(s) inoperable when the redundant required feature(s) are inoperable.

AND C.2 Restore one required offsite circuit to OPERABLE status.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from discovery of Condition C concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-4 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

One required offsite circuit inoperable.

AND One required DG inoperable.

NOTE-------------------

Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution SystemsOperating," when any division is de-energized as a result of Condition D.

D.1 Restore required offsite circuit to OPERABLE status.

OR D.2 Restore required DG to OPERABLE status.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 12 hours E.

Two required DGs inoperable.

E.1 Restore one required DG to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OR 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months if Division III DG is inoperable F.

Required Action and Associated Completion Time of Condition A, B, C, D, or E not met.

F.1 Be in MODE 3.

AND F.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours G.

Three or more required AC sources inoperable.

G.1 Enter LCO 3.0.3.

Immediately

AC SourcesOperating 3.8.1 RIVER BEND 3.8-5 Amendment No. 81, 90, 121 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each required offsite circuit.

7 days SR 3.8.1.2

NOTES---------------------------------

1.

Performance of SR 3.8.1.7 satisfies this SR.

2.

All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

3.

A modified DG start involving gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each DG starts from standby conditions and achieves:

a.

For DG 1A and DG 1B, steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

b.

For DG 1C:

1.

Maximum of 5400 V, and 66.75 Hz, and

2.

Steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

31 days (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-6 Amendment No. 81, 90, 121 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3

NOTES-------------------------------

1.

DG loadings may include gradual loading as recommended by the manufacturer.

2.

Momentary transients outside the load range do not invalidate this test.

3.

This Surveillance shall be conducted on only one DG at a time.

4.

This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.7 Verify each DG operates for 60 minutes at a load 3000 kW and 3100 kW for DG 1A and DG 1B, and 2500 kW and 2600 kW for DG 1C.

31 days SR 3.8.1.4 Verify each day tank contains 316.3 gal of fuel oil.

31 days SR 3.8.1.5 Check for and remove accumulated water from each day tank.

31 days SR 3.8.1.6 Verify the fuel oil transfer system operates to automatically transfer fuel oil from the storage tank to the day tank.

31 days (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-7 Amendment No. 81, 121 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7

NOTE--------------------------------------

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby conditions and achieves:

a.

For DG 1A and DG 1B, steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz, in 10 seconds.

b.

For DG 1C:

1. Maximum of 5400 V, and 66.75 Hz, and

2. Steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz, in 13 seconds.

184 days SR 3.8.1.8

NOTE---------------------------------

This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify manual transfer of unit power supply from the normal offsite circuit to required alternate offsite circuit.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-8 Amendment No. 81 121 133, 137 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9

NOTE--------------------------------

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

If performed with DG synchronized with offsite power, it shall be performed at a power factor 0.9 Verify each DG rejects a load greater than or equal to its associated single largest post accident load and following load rejection, the engine speed is maintained less than nominal plus 75% of the difference between nominal speed and the overspeed trip setpoint or 15% above nominal, whichever is lower.

18 months SR 3.8.1.10

NOTE-------------------------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor 0.9 does not trip and voltage is maintained 4784 V for DG 1A and DG 1B and 5400 V for DG 1C during and following a load rejection of a load 3030 kW and 3130 kW for DGs 1A and 1B and 2500 kW and 2600 kW for DG 1C.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-9 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

NOTES--------------------------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses for Divisions I and II; and

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C,

2.

energizes auto-connected shutdown loads,

3.

maintains steady state voltage 3740 V and 4580 V,

4.

maintains steady state frequency 58.8 Hz and 61.2 Hz, and

5.

supplies permanently connected and auto-connected shutdown loads for 5 minutes.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-10 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12

NOTES-----------------------------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1 or 2. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and:

a.

For DG 1C during the auto-start maintains voltage 5400 V and frequency 66.75 Hz;

b.

In 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C after auto-start and during tests, achieves voltage 3740 V and 4580 V;

c.

In 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C after auto-start and during tests, achieves frequency 58.8 Hz and 61.2 Hz; and

d.

Operates for 5 minutes.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-11 Amendment No. 81 94 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13

NOTE---------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG's automatic trips are bypassed on an actual or simulated ECCS initiation signal except:

a.

Engine overspeed; and

b.

Generator differential current.

18 months SR 3.8.1.14

NOTES---------------------------

1.

Momentary transients outside the load and power factor ranges do not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor 0.9, operates for 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a.

For DG 1A and DG 1B loaded 3030 kW and 3130 kW; and

b.

For DG 1C:

1.

For 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2750 kW and 2850 kW, and

2.

For the remaining hours of the test loaded 2500 kW and 2600 kW.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-12 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15

NOTES-------------------------------

1.

This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months loaded 3000 kW and 3100 kW for DG 1A and DG 1B, and 2500 kW and 2600 for DG 1C, or operating temperatures have stabilized, which ever is longer.

Momentary transients outside of the load range do not invalidate this test.

2.

All DG starts may be preceded by an engine prelube period.

Verify each DG starts and achieves, in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C, voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

18 months SR 3.8.1.16

NOTE---------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

a.

Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-13 Amendment No. 81 95 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.17

NOTE--------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:

a.

Returning DG to ready-to-load operation; and

b.

Automatically energizing the emergency loads from offsite power.

18 months SR 3.8.1.18

NOTE--------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.

Verify sequence time is within +/- 10% of design for each load sequencer timer.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-14 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19

NOTES-----------------------------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses for Divisions I and II; and

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C,

2.

energizes auto-connected emergency

loads,

3.

achieves steady state voltage 3740 V and 4580 V,

4.

achieves steady state frequency 58.8 Hz and 61.2 Hz, and

5.

supplies permanently connected and auto-connected emergency loads for 5 minutes.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-15 Amendment No. 81, 121 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20

NOTE--------------------------------

All DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from standby condition, each DG achieves, in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C, voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

10 years

For SRO Question 81

MCPR 3.2.2 RIVER BEND 3.2-2 Amendment No. 81, 114 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY:

THERMAL POWER 23.8% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Any MCPR not within limits.

A.1 Restore MCPR(s) to within limits.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months B.

Required Action and associated Completion Time not met.

B.1 Reduce THERMAL POWER to < 23.8% RTP.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the limits specified in the COLR.

Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 23.8% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter

Page 25 of 71 RBS CYCLE 12 COLR Revision 1 FIGURE 10. OPERATING LIMIT MCPR (MCPRF) VERSUS CORE FLOW FOR NON-KAN ATRIUM-10 FOR RECIRCULATION SYSTEM IN LOOP AUTO CONTROL, ALL EXPOSURES 1.41 1.14 1.08 1.00 1.10 1.20 1.30 1.40 1.50 1.60 0

10 20 30 40 50 60 70 80 90 100 110 120 Core Flow, % rated MCPRf Limit

Page 30 of 71 RBS CYCLE 12 COLR Revision 1 FIGURE 15. OPERATING LIMIT MCPR (MCPRP) VERSUS CORE POWER FOR NON-KAN ATRIUM-10, EXPOSURE RANGE BOC TO BOC + 5200 MWD/MTU 1.20 1.28 1.43 1.53 2.01 2.16 1.85 2.12 1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 2.0 2.1 2.2 2.3 0

10 20 30 40 50 60 70 80 90 100 110 Power, % rated MCPRp Limit

> 50% Flow

<= 50% Flow

For SRO Question 83

MCUTL MAXIMUM CORE UNCOVERY TIME LIMIT FIGURE 3 6000 TIME AFTER SHUTDOWN (MIN) 10 0

100 1000 UNCOVERY MAXIMUM (MIN)

LIMIT TIME CORE UNSAFE 10 5

15 SAFE

42 PSIG 94 MIN 64 MIN 46 MIN 5

6 OR MORE TIME RPV PRESSURE HAS REMAINED OPEN SRVS NUMBER OF MINIMUM CORE FLOODING INTERVAL - MCFI 7

TABLE 1 ABOVE

For SRO Question 84

PRESSURE SUPPRESSION PRESSURE FIGURE 4 SP LEVEL (FT)

SAFE 1

0 15 14 4

3 2

17 16 18 (PSIG)

PRESS CTMT 6

5 20 19 21 22 UNSAFE PSP

For SRO Question 85

For SRO Question 86

CONTINUOUS USE DATA SHEET 1 PAGE 10 OF 15 DAILY OPERATING LOGS STP-000-0001 REV - 45 PAGE 16 OF 34 Step Instrument Night Limits Day No.

Panel Numbers Panel Numbers 92 Corrected Annulus pressure LMS-TR127 HVR-PDI247 OR HVR-PDI273 P863

+

=

Ann Pressure Aux Bldg Corrected LMS-TR127 Pressure Annulus HVR-PDI247 Pressure OR HVR-PDI273 Corrected Annulus Pressure less than

- 3.40 INWG or in the ACCEPTABLE zone of Attachment 4 93 Fuel Bldg HVF-FLT2 A P863 Yes / No /

NA B P863 Yes / No / NA One operating if moving recently irradiated fuel in Fuel Bldg.

A P863 Yes / No / NA B P863 Yes / No / NA 94 Stby Cooling Tower (SBCT)

Temp (see*)

P869

__________°F

< 88°F.

IF SBCT temperature 60°F, THEN see** below.

IF Wide Range Avg. Temp is 70° to 85°F, THEN record Narrow Range Avg. Temp.

IF Wide Range Avg. Temp is < 70°F or > 85°F, THEN record Wide Range Avg. Temp.

- IF Standby Cooling Tower Basin Temp is 60°F, THEN notify OSM/CRS to take actions to restore SWP-PVY32A, B, C, and D if Gagged Open prior to the temperature in the Standby Cooling Tower Basin reaching 55°F to maintain HVK operability.

IF Tamaris is not available to monitor Standby Cooling Tower Temperature, THEN perform the following:

1. Install the appropriate M&TE at the local thermocouple wires in the South and West quadrants.

2. Get two temperature readings in each quadrant, one with the thermocouple at existing depth the second by pulling the thermocouple above EL. 94 MSL (approximately two to three feet from top)

3. Record the average temperature.

4. Disconnect the M&TE installed in Step #1.

+

=

TOTAL =

1 2 3 4

TOTAL 4 AVG P841 P842 P841 P842 95 SBCT level SWP-ESX 167 164 Verify Standby Cooling Tower (SBCT) level 78% (11110) 96 PVLCS Press LSV-ESX9 A

B T.S. 101 psig Range 106.5 and 132 psig Cont/Ann P HVR-ESZ60 A

B 97 HVR-ESX60 C

E D

F Within 2.0 inches RHR C Pump Rm RHS-ES50 A

B 122°F A

B RPCCW Area RHS-ES54 A

B 122°F A

B RHR Equip Rm Cube (East)

RHS-ES55 A

B 122°F A

B 98 RHR Equip Rm Cube (West)

RHS-ES56 A

B 122°F A

B 99 Cont Press CMS-ES45 A P819 B P820

- 0.3 to + 0.3 psig A P819 B P820

CONTINUOUS USE ATTACHMENT 4 PAGE 1 OF 1 DP INDICATION LIMIT TO MAINTAIN NEGATIVE PRESSURE IN ANNULUS STP-000-0001 REV - 45 PAGE 33 OF 34 dP Indication Limit to Maintain Negative Pressure in Annulus (Annulus assumed at < 110F) 0 10 20 30 40 50 60 70 80 90

-3.350

-3.300

-3.250

-3.200

-3.150

-3.100 Correction Annulus Pressure Outside Temperature (F)

Acceptable Unacceptable

Secondary Containment-Operating 3.6.4.1 RIVER BEND 3.6-46 Amendment No. 81, 113 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary ContainmentOperating LCO 3.6.4.1 The shield building and auxiliary building shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Secondary containment inoperable.

A.1 Restore secondary containment to OPERABLE status.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months B.

Required Action and associated Completion Time not met.

B.1 Be in MODE 3.

AND B.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify shield building annulus and auxiliary building vacuum is 3.0 and 0.0 inch of vacuum water gauge, respectively.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

Secondary Containment-Operating 3.6.4.1 RIVER BEND 3.6-47 Amendment No. 81 95 113, 132 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.4.1.2 Verify all secondary containment equipment hatches are closed and sealed and loop seals filled.

31 days SR 3.6.4.1.3 Verify each secondary containment access door is closed, except when the access opening is being used for entry and exit.

31 days SR 3.6.4.1.4 Verify each standby gas treatment (SGT) subsystem will draw down the shield building annulus and auxiliary building to 0.5 and 0.25 inch of vacuum water gauge in 18.5 and 34.5 seconds, respectively.

18 months on a STAGGERED TEST BASIS SR 3.6.4.1.5 Deleted Not Applicable SR 3.6.4.1.6 Verify each SGT subsystem can maintain 0.5 and 0.25 inch of vacuum water gauge in the shield building annulus and auxiliary building, respectively, for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

18 months on a STAGGERED TEST BASIS SR 3.6.4.1.7 Deleted Not Applicable

For SRO Question 90

DC SourcesOperating 3.8.4 RIVER BEND 3.8-24 Amendment No. 81 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC SourcesOperating LCO 3.8.4 The Division I, Division II, and Division III DC electrical power subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Division I or II DC electrical power subsystem inoperable.

A.1 Restore Division I and II DC electrical power subsystems to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months B.

Division III DC electrical power subsystem inoperable.

B.1 Declare High Pressure Core Spray System and Standby Service Water System pump 2C inoperable.

Immediately C.

Required Action and associated Completion Time not met.

C.1 Be in MODE 3.

AND C.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours

DC SourcesOperating 3.8.4 RIVER BEND 3.8-25 Amendment No. 81 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is 130.2 V on float charge.

7 days SR 3.8.4.2 Verify no visible corrosion at battery terminals and connectors.

OR Verify battery connection resistance is 1.5 E-4 ohm for inter-cell connections, 1.5 E-4 ohm for inter-rack connections, 1.5 E-4 ohm for inter-tier connections, and 1.5 E-4 ohm for terminal connections.

92 days SR 3.8.4.3 Verify battery cells, cell plates, and racks show no visual indication of physical damage or abnormal deterioration.

18 months SR 3.8.4.4 Remove visible corrosion, and verify battery cell to cell and terminal connections are coated with anti-corrosion material.

18 months SR 3.8.4.5 Verify battery connection resistance is 1.5 E-4 ohm for inter-cell connections, 1.5 E-4 ohm for inter-rack connections, 1.5 E-4 ohm for inter-tier connections, and 1.5 E-4 ohm for terminal connections.

18 months (continued)

DC SourcesOperating 3.8.4 RIVER BEND 3.8-26 Amendment No. 81 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.6 Verify each battery charger supplies 300 amps for chargers 1A and 1B and 50 amps for charger 1C at 130.2 V for 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

18 months SR 3.8.4.7

NOTES-------------------------------

1.

SR 3.8.4.8 may be performed in lieu of SR 3.8.4.7 once per 60 months.

2.

This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

18 months (continued)

DC SourcesOperating 3.8.4 RIVER BEND 3.8-27 Amendment No. 81 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.8

NOTE------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test.

60 months AND

NOTE-------

Only applicable when battery shows degradation or has reached 85% of expected life.

18 months

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-50 Revision No. 3-2 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.4 DC SourcesOperating BASES BACKGROUND The station DC electrical power system provides the AC emergency power system with control power. It also provides both motive and control power to selected safety related equipment. As required by 10 CFR 50, Appendix A, GDC 17 (Ref. 1), the DC electrical power system is designed to have sufficient independence, redundancy, and testability to perform its safety functions, assuming a single failure. The DC electrical power system also conforms to the requirements of Regulatory Guide 1.6 (Ref. 2) and IEEE-308 (Ref. 3).

The 125 VDC electrical power system consists of three independent Class 1E DC electrical power subsystems, Divisions I, II, and III. Each subsystem consists of a battery, associated battery charger(s), and all the associated control equipment and interconnecting cabling.

During normal operation, the DC loads are powered from the battery chargers with the batteries floating on the system. In case of loss of normal power to the battery charger, the DC loads are automatically powered from the Engineered Safety Feature (ESF) batteries.

Each of the Division I and II electrical power subsystems provides the control power for its associated Class 1E AC power load group, 4.16 kV switchgear, and 480 V load centers. Also, these DC subsystems provide DC electrical power to the inverters, which in turn power the AC vital buses. The Division III DC electrical power subsystem provides DC motive and control power as required for the High Pressure Core Spray (HPCS) System diesel generator (DG) set control and protection.

The DC power distribution system is described in more detail in Bases for LCO 3.8.9, "Distribution SystemsOperating," and LCO 3.8.10, "Distribution SystemsShutdown."

Each Division I and II battery has adequate storage capacity to carry the required load continuously for at least 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months as discussed in the USAR, Section 8.3.2 (Ref. 4).

(continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-51 Revision No. 5-5 BASES BACKGROUND The Division III battery has adequate storage to carry the required load (continued) continuously for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months (Ref. 4).

Each DC battery subsystem is separately housed in a ventilated room apart from its charger and distribution centers. Each subsystem is located in an area separated physically and electrically from the other subsystems to ensure that a single failure in one subsystem does not cause a failure in a redundant subsystem. There is no sharing between redundant Class 1E subsystems such as batteries, battery chargers, or distribution panels.

The batteries for a DC electrical power subsystem are sized to produce required capacity at 80% of nameplate rating while maintaining system voltage.

Each battery charger of Division I and II DC electrical power subsystems has ample power output capacity for the steady state operation of connected loads required during normal operation, while at the same time maintaining its battery bank fully charged. Each battery charger has sufficient capacity to restore the battery bank from the design minimum charge to its fully charged state within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months while supplying normal steady state loads (Ref. 4).

The battery charger of Division III DC electrical power subsystem has sufficient capacity to restore the battery bank from the design minimum charge to its fully charged state in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months while supplying normal steady state loads (Ref. 4).

APPLICABLE The initial conditions of Design Basis Accident (DBA) and transient SAFETY ANALYSES analyses in the USAR, Chapter 6 (Ref. 5) and Chapter 15 (Ref. 6),

assume that ESF systems are OPERABLE. The DC electrical power system provides normal and emergency DC electrical power for the DGs, emergency auxiliaries, and control and switching during all MODES of operation.

The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and is based upon meeting the design basis of the unit. This includes maintaining DC sources OPERABLE during accident conditions in the event of:

(continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-52 Revision No. 0 BASES APPLICABLE

a.

An assumed loss of all offsite AC power or of all onsite AC power; SAFETY ANALYSES and (continued)

b.

A worst case single failure.

The DC sources satisfy Criterion 3 of the NRC Policy Statement.

LCO The DC electrical power subsystems, each subsystem consisting of one battery, one battery charger, and the corresponding control equipment and interconnecting cabling supplying power to the associated bus within the divisions, are required to be OPERABLE to ensure the availability of the required power to shut down the reactor and maintain it in a safe condition after an anticipated operational occurrence (AOO) or a postulated DBA. Loss of any DC electrical power subsystem does not prevent the minimum safety function from being performed (Ref. 4).

APPLICABILITY The DC electrical power sources are required to be OPERABLE in MODES 1, 2, and 3 to ensure safe unit operation and to ensure that:

a.

Acceptable fuel design limits and reactor coolant pressure boundary limits are not exceeded as a result of AOOs or abnormal transients; and

b.

Adequate core cooling is provided, and containment integrity and other vital functions are maintained in the event of a postulated DBA.

The DC electrical power requirements for MODES 4 and 5 are addressed in the Bases for LCO 3.8.5, "DC SourcesShutdown."

ACTIONS A.1 Condition A represents one division with a loss of ability to completely respond to an event, and a potential loss of ability to remain energized during normal operation. It is, therefore, imperative that the operator's attention focus on stabilizing the unit, minimizing the potential for complete (continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-53 Revision No. 0 BASES ACTIONS A.1 (continued) loss of DC power to the affected division. The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limit is consistent with the allowed time for an inoperable DC distribution system division.

If one of the required Division I or II DC electrical power subsystems is inoperable (e.g., inoperable battery, inoperable battery charger, or inoperable battery charger and associated inoperable battery), the remaining DC electrical power subsystems have the capacity to support a safe shutdown and to mitigate an accident condition. Since a subsequent worst case single failure could, however, result in the loss of minimum necessary DC electrical subsystems, continued power operation should not exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Completion Time is based on Regulatory Guide 1.93 (Ref. 7) and reflects a reasonable time to assess unit status as a function of the inoperable DC electrical power subsystem and, if the DC electrical power subsystem is not restored to OPERABLE status, to prepare to effect an orderly and safe unit shutdown.

B.1 With the Division III DC electrical power subsystem inoperable, the HPCS and Standby Service Water System pump 2C may be incapable of performing their intended functions and must be immediately declared inoperable. This declaration also requires entry into applicable Conditions and Required Actions of LCO 3.5.1, "ECCS Operating," and LCO 3.7.1, "Standby Service Water (SSW) System and Ultimate Heat Sink (UHS)."

C.1 and C.2 If the DC electrical power subsystem cannot be restored to OPERABLE status within the associated Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant (continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-54 Revision No. 1 BASES ACTIONS C.1 and C.2 (continued) conditions from full power conditions in an orderly manner and without challenging plant systems. The Completion Time to bring the unit to MODE 4 is consistent with the time required in Regulatory Guide 1.93 (Ref. 7).

SURVEILLANCE SR 3.8.4.1 REQUIREMENTS Verifying battery terminal voltage while on float charge helps to ensure the effectiveness of the charging system and the ability of the batteries to perform their intended function. Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery (or battery cell) and maintain the battery (or battery cell) in a fully charged state. The voltage requirements are based on the nominal design voltage of the battery and are consistent with the initial voltages assumed in the battery sizing calculations. The 7 day Frequency is consistent with manufacturer's recommendations and IEEE-450 (Ref. 8).

SR 3.8.4.2 Visual inspection to detect corrosion of the battery cells and connections, or measurement of the resistance of each inter-cell, inter-rack, inter-tier, and terminal connection, provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance. Only those terminals and connectors which have visible corrosion must be measured for connection resistance.

The Surveillance Frequency for these inspections, which can detect conditions that can cause power losses due to resistance heating, is 92 days. This Frequency is considered acceptable based on operating experience related to detecting corrosion trends.

SR 3.8.4.3 Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.

(continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-55 Revision No. 0 BASES SURVEILLANCE SR 3.8.4.3 (continued)

REQUIREMENTS The 18 month Frequency of the Surveillance is based on engineering judgement, taking into consideration the desired unit conditions to perform the Surveillance. Operating experience has shown that these components usually pass the SR when performed at the 18 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.8.4.4 and SR 3.8.4.5 Visual inspection and resistance measurements of inter-cell, inter-rack, inter-tier, and terminal connections provides an indication of physical damage or abnormal deterioration that could indicate degraded battery condition. The anti-corrosion material is used to ensure good electrical connections and to reduce terminal deterioration. The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection.

The removal of visible corrosion is a preventive maintenance SR. The presence of visible corrosion does not necessarily represent a failure of this SR, provided visible corrosion is removed during performance of this Surveillance.

The 18 month Frequency of the Surveillance is based on engineering judgement, taking into consideration the desired unit conditions to perform the Surveillance. Operating experience has shown that these components usually pass the SR when performed at the 18 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.8.4.6 Battery charger capability requirements are based on the design capacity of the chargers (Ref. 4). According to Regulatory Guide 1.32 (Ref. 9), the battery charger supply is required to be based on the largest combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to (continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-56 Revision No. 103 BASES SURVEILLANCE SR 3.8.4.6 (continued)

REQUIREMENTS the fully charged state, irrespective of the status of the unit during these demand occurrences. The minimum required amperes and duration ensure that these requirements can be satisfied. Momentary transients that are not attributable to charger performance do not invalidate this test.

The Surveillance Frequency is acceptable, given the unit conditions required to perform the test and the other administrative controls existing to ensure adequate charger performance during these 18 month intervals.

In addition, this Frequency is intended to be consistent with expected fuel cycle lengths.

SR 3.8.4.7 A battery service test is a special test of the battery's capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length correspond to the design duty cycle requirements as specified in Reference 4.

The Surveillance Frequency of 18 months is consistent with the recommendations of Regulatory Guide 1.32 (Ref. 9) and Regulatory Guide 1.129 (Ref. 10), which state that the battery service test should be performed during refueling operations or at some other outage, with intervals between tests not to exceed 18 months.

This SR is modified by two Notes. Note 1 allows the once per 60 months performance of SR 3.8.4.8 in lieu of SR 3.8.4.7. This substitution is acceptable because the battery performance test (SR 3.8.4.8) represents a more severe test of battery capacity than the battery service test (SR 3.8.4.7). Because both the battery service test and the battery performance test involve battery capacity determination, complete battery replacement invalidates the previous performance of these surveillance requirements. In addition to requiring the re-performance of both of these surveillance tests prior to declaring the battery OPERABLE, complete battery replacement also resets the 60 month time period used for substitution of the service test by the performance test. For this reason, substitution is acceptable for performance testing conducted within the first two years of service of a new battery as required by Reference 8.

The reason for Note 2 is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge safety systems. Credit may be taken for unplanned events that satisfy the Surveillance. Examples of unplanned events may include:

1)

Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and (continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-57 Revision No. 4-6 BASES SURVEILLANCE SR 3.8.4.7 (continued)

REQUIREMENTS

2)

Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.

SR 3.8.4.8 A battery performance test is a test of constant current capacity of a battery, normally done in the as found condition, after having been in service, to detect any change in the capacity determined by the acceptance test. The test is intended to determine overall battery degradation due to age and usage.

The acceptance criteria for this Surveillance is consistent with IEEE-450 (Ref. 8) and IEEE-485 (Ref. 11). These references recommend that the battery be replaced if its capacity is below 80% of the manufacturer's rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements.

The Surveillance Frequency for this test is normally 60 months. If the battery shows degradation, or if the battery has reached 85% of its expected life the Surveillance Frequency is reduced to 18 months.

Degradation is indicated, according to IEEE-450 (Ref. 8), when the battery capacity drops by more than 10% of rated capacity from its average on previous tests, or when it is 10% below the manufacturer's rating. These Frequencies are based on the recommendations in IEEE-450 (Ref. 8).

This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge safety systems. Credit may be taken for unplanned events that satisfy the Surveillance. Examples of unplanned events may include:

(continued)

DC Sources Operating B 3.8.4 RIVER BEND B 3.8-58 Revision No. 4-6 BASES SURVEILLANCE SR 3.8.4.8 (continued)

REQUIREMENTS

1)

Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

2)

Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.

REFERENCES

1.

10 CFR 50, Appendix A, GDC 17.

2.

Regulatory Guide 1.6, March 10, 1971.

3.

IEEE Standard 308, 1978.

4.

USAR, Section 8.3.2.

5.

USAR, Chapter 6.

6.

USAR, Chapter 15.

7.

Regulatory Guide 1.93, December 1974.

8.

IEEE Standard 450, 1975.

9.

Regulatory Guide 1.32, February 1977.

10.

Regulatory Guide 1.129, December 1974.

11.

IEEE Standard 485.

For SRO Question 91

SSW System and UHS 3.7.1 RIVER BEND 3.7-1 Amendment No. 81 3.7 PLANT SYSTEMS 3.7.1 Standby Service Water (SSW) System and Ultimate Heat Sink (UHS)

LCO 3.7.1 Two SSW subsystems and the UHS shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One division with one UHS cooling tower fan cell inoperable.

A.1 Restore cooling tower fan cell to OPERABLE status.

30 days B.

Both divisions with one UHS cooling tower fan cell inoperable.

B.1 Restore one cooling tower fan cell to OPERABLE status.

7 days C.

One division with both UHS cooling tower fan cells inoperable.

C.1 Declare associated SSW subsystem inoperable.

Immediately D.

UHS basin inoperable.

D.1 Restore UHS basin to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months E.

One SSW subsystem with one pump inoperable.

E.1 Restore pump to OPERABLE status.

30 days (continued)

SSW System and UHS 3.7.1 RIVER BEND 3.7-2 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F.

Two SSW subsystems with one pump inoperable.

F.1 Restore one pump to OPERABLE status.

7 days G.

One SSW subsystem inoperable for reasons other than Condition E or F.

NOTES-----------------

1.

Enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources -

Operating," for diesel generator made inoperable by SSW.

2.

Enter applicable Conditions and Required Actions of LCO 3.4.9, "Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown," for RHR shutdown cooling subsystem made inoperable by SSW.

G.1 Restore SSW subsystem to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)

SSW System and UHS 3.7.1 RIVER BEND 3.7-3 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H.

Required Action and associated Completion Time of Condition A, B, D, E, F, or G not met.

OR Both SSW subsystems inoperable for reasons other than Condition F.

OR Three or four UHS cooling tower fan cells inoperable.

H.1 Be in MODE 3.

AND H.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level of UHS cooling tower basin is 78%.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.7.1.2 Verify the average water temperature of UHS is 88°F.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.7.1.3 Operate each cooling tower fan cell for 15 minutes.

31 days (continued)

SSW System and UHS 3.7.1 RIVER BEND 3.7-4 Amendment No. 81 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.1.4 Verify each required SSW subsystem manual, power operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.

31 days SR 3.7.1.5 Verify each SSW subsystem actuates on an actual or simulated initiation signal.

18 months

AC SourcesOperating 3.8.1 RIVER BEND 3.8-1 Amendment No. 81 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC SourcesOperating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a.

Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electric Power Distribution System; and

b.

Three diesel generators (DGs).

APPLICABILITY:

MODES 1, 2, and 3.

NOTE------------------------------------------------

Division III AC electrical power sources are not required to be OPERABLE when High Pressure Core Spray System and Standby Service Water System pump 2C are inoperable.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One required offsite circuit inoperable.

A.1 Perform SR 3.8.1.1 for OPERABLE required offsite circuit.

AND 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-2 Amendment No. 81, 125 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.2 Restore required offsite circuit to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery of two divisions with no offsite power AND 17 days from discovery of failure to meet LCO B.

One required DG inoperable.

B.1 Perform SR 3.8.1.1 for OPERABLE required offsite circuit(s).

AND B.2 Declare required feature(s), supported by the inoperable DG, inoperable when the redundant required feature(s) are inoperable.

AND 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition B concurrent with inoperability of redundant required feature(s)

(continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-3 Amendment No. 81, 125 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B.

(continued)

B.3.1 Determine OPERABLE DG(s) are not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for OPERABLE DG(s).

AND B.4 Restore required DG to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from discovery of an inoperable Division III DG AND 14 days AND 17 days from discovery of failure to meet LCO C.

Two required offsite circuits inoperable.

C.1 Declare required feature(s) inoperable when the redundant required feature(s) are inoperable.

AND C.2 Restore one required offsite circuit to OPERABLE status.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from discovery of Condition C concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-4 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

One required offsite circuit inoperable.

AND One required DG inoperable.

NOTE-------------------

Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution SystemsOperating," when any division is de-energized as a result of Condition D.

D.1 Restore required offsite circuit to OPERABLE status.

OR D.2 Restore required DG to OPERABLE status.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 12 hours E.

Two required DGs inoperable.

E.1 Restore one required DG to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OR 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months if Division III DG is inoperable F.

Required Action and Associated Completion Time of Condition A, B, C, D, or E not met.

F.1 Be in MODE 3.

AND F.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours G.

Three or more required AC sources inoperable.

G.1 Enter LCO 3.0.3.

Immediately

AC SourcesOperating 3.8.1 RIVER BEND 3.8-5 Amendment No. 81, 90, 121 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each required offsite circuit.

7 days SR 3.8.1.2

NOTES---------------------------------

1.

Performance of SR 3.8.1.7 satisfies this SR.

2.

All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

3.

A modified DG start involving gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each DG starts from standby conditions and achieves:

a.

For DG 1A and DG 1B, steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

b.

For DG 1C:

1.

Maximum of 5400 V, and 66.75 Hz, and

2.

Steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

31 days (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-6 Amendment No. 81, 90, 121 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3

NOTES-------------------------------

1.

DG loadings may include gradual loading as recommended by the manufacturer.

2.

Momentary transients outside the load range do not invalidate this test.

3.

This Surveillance shall be conducted on only one DG at a time.

4.

This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.7 Verify each DG operates for 60 minutes at a load 3000 kW and 3100 kW for DG 1A and DG 1B, and 2500 kW and 2600 kW for DG 1C.

31 days SR 3.8.1.4 Verify each day tank contains 316.3 gal of fuel oil.

31 days SR 3.8.1.5 Check for and remove accumulated water from each day tank.

31 days SR 3.8.1.6 Verify the fuel oil transfer system operates to automatically transfer fuel oil from the storage tank to the day tank.

31 days (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-7 Amendment No. 81, 121 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7

NOTE--------------------------------------

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby conditions and achieves:

a.

For DG 1A and DG 1B, steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz, in 10 seconds.

b.

For DG 1C:

1. Maximum of 5400 V, and 66.75 Hz, and

2. Steady state voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz, in 13 seconds.

184 days SR 3.8.1.8

NOTE---------------------------------

This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify manual transfer of unit power supply from the normal offsite circuit to required alternate offsite circuit.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-8 Amendment No. 81 121 133, 137 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9

NOTE--------------------------------

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

If performed with DG synchronized with offsite power, it shall be performed at a power factor 0.9 Verify each DG rejects a load greater than or equal to its associated single largest post accident load and following load rejection, the engine speed is maintained less than nominal plus 75% of the difference between nominal speed and the overspeed trip setpoint or 15% above nominal, whichever is lower.

18 months SR 3.8.1.10

NOTE-------------------------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor 0.9 does not trip and voltage is maintained 4784 V for DG 1A and DG 1B and 5400 V for DG 1C during and following a load rejection of a load 3030 kW and 3130 kW for DGs 1A and 1B and 2500 kW and 2600 kW for DG 1C.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-9 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11

NOTES--------------------------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses for Divisions I and II; and

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C,

2.

energizes auto-connected shutdown loads,

3.

maintains steady state voltage 3740 V and 4580 V,

4.

maintains steady state frequency 58.8 Hz and 61.2 Hz, and

5.

supplies permanently connected and auto-connected shutdown loads for 5 minutes.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-10 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12

NOTES-----------------------------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1 or 2. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and:

a.

For DG 1C during the auto-start maintains voltage 5400 V and frequency 66.75 Hz;

b.

In 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C after auto-start and during tests, achieves voltage 3740 V and 4580 V;

c.

In 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C after auto-start and during tests, achieves frequency 58.8 Hz and 61.2 Hz; and

d.

Operates for 5 minutes.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-11 Amendment No. 81 94 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13

NOTE---------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG's automatic trips are bypassed on an actual or simulated ECCS initiation signal except:

a.

Engine overspeed; and

b.

Generator differential current.

18 months SR 3.8.1.14

NOTES---------------------------

1.

Momentary transients outside the load and power factor ranges do not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor 0.9, operates for 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a.

For DG 1A and DG 1B loaded 3030 kW and 3130 kW; and

b.

For DG 1C:

1.

For 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2750 kW and 2850 kW, and

2.

For the remaining hours of the test loaded 2500 kW and 2600 kW.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-12 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15

NOTES-------------------------------

1.

This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months loaded 3000 kW and 3100 kW for DG 1A and DG 1B, and 2500 kW and 2600 for DG 1C, or operating temperatures have stabilized, which ever is longer.

Momentary transients outside of the load range do not invalidate this test.

2.

All DG starts may be preceded by an engine prelube period.

Verify each DG starts and achieves, in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C, voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

18 months SR 3.8.1.16

NOTE---------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG:

a.

Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-13 Amendment No. 81 95 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.17

NOTE--------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:

a.

Returning DG to ready-to-load operation; and

b.

Automatically energizing the emergency loads from offsite power.

18 months SR 3.8.1.18

NOTE--------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.

Verify sequence time is within +/- 10% of design for each load sequencer timer.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-14 Amendment No. 81 121, 133 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.19

NOTES-----------------------------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses for Divisions I and II; and

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C,

2.

energizes auto-connected emergency

loads,

3.

achieves steady state voltage 3740 V and 4580 V,

4.

achieves steady state frequency 58.8 Hz and 61.2 Hz, and

5.

supplies permanently connected and auto-connected emergency loads for 5 minutes.

18 months (continued)

AC SourcesOperating 3.8.1 RIVER BEND 3.8-15 Amendment No. 81, 121 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20

NOTE--------------------------------

All DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from standby condition, each DG achieves, in 10 seconds for DG 1A and DG 1B and 13 seconds for DG 1C, voltage 3740 V and 4580 V and frequency 58.8 Hz and 61.2 Hz.

10 years

For SRO Question 97

RCS Operational LEAKAGE 3.4.5 RIVER BEND 3.4-12 Amendment No. 81 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Operational LEAKAGE LCO 3.4.5 RCS operational LEAKAGE shall be limited to:

a.

No pressure boundary LEAKAGE;

b.

5 gpm unidentified LEAKAGE;

c.

30 gpm total LEAKAGE averaged over the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period; and

d.

2 gpm increase in unidentified LEAKAGE within the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period in MODE 1.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Unidentified LEAKAGE not within limit.

OR Total LEAKAGE not within limit.

A.1 Reduce LEAKAGE to within limits.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months B.

Unidentified LEAKAGE increase not within limit.

B.1 Verify source of unidentified LEAKAGE increase is not service sensitive type 304, type 316 austenitic stainless steel, or other intergranular stress corrosion cracking susceptible material.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (continued)

RCS Operational LEAKAGE 3.4.5 RIVER BEND 3.4-13 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Required Action and associated Completion Time of Condition A or B not met.

OR Pressure boundary LEAKAGE exists.

C.1 Be in MODE 3.

AND C.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified LEAKAGE, total LEAKAGE, and unidentified LEAKAGE increase are within limits.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

For SRO Question 100

ML042990539

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