Text

2012-11 Final Written Handouts
	ML13051A382
Person / Time
Site:	River Bend
Issue date:	11/15/2012
From:	David Strickland; Operations Branch IV
To:	; Entergy Operations
	Laura Hurley
References
	50-458/12-011
	Download: ML13051A382 (60)
	v • d • e

During the exam review process for the written exam, there were two questions that required open references as documented in ES-401-9 form from the draft submittal. However, during the subsequent changes to the written exam for final approval, there were 8 questions that required an open reference on the written exam. These references are included in the references file uploaded to Adams with this note to file.

CONTINUOUS USE ATTACHMENT 1 PAGE 1 OF 2 RBS DUAL LOOP OPERATION POWER/FLOW MAPS RBS 3091 MWt DUAL LOOP OPERATION POWER/FLOW MAP w/DP = -2 Normal Feedwater Temperature 3600 SCRAM 3300 ROD-BLOCK 3000 2700 2400 2100 Restricted Region 1800 Exclusion Region Monitored CORE POWER (MWt) 1500 Region 1200 900 600 TLO/Normal TLO/Setup 300 0

0 10 20 30 40 50 60 70 80 90 100 CORE FLOW (Mlbm/hr)

AOP-0024 REV - 024 PAGE 12 OF 16

CONTINUOUS USE ATTACHMENT 1 PAGE 2 OF 2 RBS DUAL LOOP OPERATION POWER/FLOW MAPS RBS 3091 MWt DUAL LOOP OPERATION POWER/FLOW MAP Reduced Feedwater Temperature 3600 SCRAM 3300 ROD-BLOCK 3000 2700 2400 Restricted Region 2100 Monitored Exclusion Region 1800 Region CORE POWER (MWt) 1500 1200 900 600 TLO/Normal 300 TLO/Setup 0

0 10 20 30 40 50 60 70 80 90 100 CORE FLOW (Mlbm/hr)

(Used when below the - 50ºF Curve of AOP-0007, Loss of Feedwater Heating)

AOP-0024 REV - 024 PAGE 13 OF 16

CONTINUOUS USE ATTACHMENT 2 PAGE 1 OF 2 RBS SINGLE LOOP OPERATION POWER/FLOW MAPS RBS 3091 MWt SINGLE LOOP OPERATION POWER/FLOW MAP w/DP=-2 Normal Feedwater Temperature 3600 SCRAM 3300 ROD-BLOCK 3000 2700 2400 2100 Restricted Region 1800 Exclusion Region Monitored CORE POWER (MWt) 1500 Region 1200 900 600 SLO/Normal SLO/Setup 300 0

0 10 20 30 40 50 60 70 80 90 100 CORE FLOW (Mlbm/hr)

AOP-0024 REV - 024 PAGE 14 OF 16

CONTINUOUS USE ATTACHMENT 2 PAGE 2 OF 2 RBS SINGLE LOOP OPERATION POWER/FLOW MAPS RBS 3091 MWt SINGLE LOOP OPERATION POWER/FLOW MAP Reduced Feedwater Temperature 3600 SCRAM 3300 ROD-BLOCK 3000 2700 2400 Restricted 2100 Region Exclusion Region 1800 Monitored Region CORE POWER (MWt) 1500 1200 900 600 SLO/Normal 300 SLO/Setup 0

0 10 20 30 40 50 60 70 80 90 100 CORE FLOW (Mlbm/hr)

(Used when below the - 50ºF Curve of AOP-0007, Loss of Feedwater Heating)

AOP-0024 REV - 024 PAGE 15 OF 16

CONTINUOUS USE ATTACHMENT 2 PAGE 5 OF 6 REACTOR COOLDOWN DATA 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 AOP-0031 REV - 316 PAGE 30 OF 108

REFERENCE USE ATTACHMENT 9 PAGE 1 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F BEFORE FUEL SHUFFLE WITH RX WATER LEVEL AT 36 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 60 50 40 30 Before fuel shuffle TIME TO 200F (Mins) 20 Multiplier Temp 0.33 170 0.55 150 0.77 130 1.00 110 10 1.23 90 0

0 5 10 15 20 25 30 TIME AFTER SHUTDOWN (HOURS)

OSP-0037 REV - 027 PAGE 27 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 2 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT 36 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 13 12 11 10 9

8 7

TAF (HRS) 6 Before Fuel Shuffle 5

4 Mulitiplier Temp 0.86 170 0.90 150 3

0.95 130 1.00 110 2

1.05 90 1

0 0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 28 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 3 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT 36 INCHES 140 130 120 110 100 90 80 70 60 Before Fuel Shuffle 50 HEAT UP RATE (DEGREES/HR) 40 30 20 10 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 29 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 4 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F BEFORE FUEL SHUFFLE WITH RX WATER LEVEL AT 85 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 4

3 2

Before Fuel Shuffle TIME TO 200F (HRS)

Multiplier Temp 1 0.33 170 0.55 150 0.77 130 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 30 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 5 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT 85 INCHES 120 110 100 90 80 70 60 Before Fuel Shuffle 50 40 HEAT UP RATE (DEGREES/HR) 30 20 10 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 31 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 6 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT 85 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 18 17 16 15 14 13 12 11 10 9

8 Before Fuel Shuffle TAF (HRS) 7 6 Mulitiplier Temp 5 0.86 170 0.90 150 4 0.95 130 3 1.00 110 1.05 90 2

1 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 32 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 7 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F CURVE BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT MAIN STEAM LINES AND RX WATER TEMPERATURE AT 110 DEGREES 4

3 2 Before Fuel Shuffle TIME TO 200F (HRS)

Multiplier Temp 0.33 170 1

0.55 150 0.77 130 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 33 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 8 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE BEFORE FUEL SHUFFLE FOR RX WATER AT THE MAIN STEAM LINES 120 110 100 90 80 70 60 50 Before Fuel Shuffle 40 HEAT UP RATE (DEGREES PER HOUR) 30 20 10 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 34 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 9 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT MAIN STEAM LINES AND RX WATER TEMPERATURE AT 110 DEGREES 20 15 Before Fuel Shuffle 10 TAF (HRS)

Multiplier Temp 0.86 170 0.91 150 5 0.95 130 1.00 110 1.05 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 35 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 10 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F CURVE BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT FLANGE AND RX WATER TEMPERATURE AT 110 DEGREES 5

4 3

Before Fuel Shuffle 2

TIME TO 200F (HRS)

Multiplier Temp 0.33 170 0.55 150 1 0.77 130 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 36 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 11 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT FLANGE 100 90 80 70 60 50 40 Before Fuel Shuffle HEAT UP RATE (DEGREES/HR) 30 20 10 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 37 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 12 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL BEFORE FUEL SHUFFLE FOR RX WATER LEVEL AT FLANGE AND RX WATER TEMPERATURE AT 110 DEGREES 30 25 20 Before fuel Shuffle 15 TAF (HRS)

Multiplier Temp 10 0.88 170 0.92 150 0.96 130 1.00 110 5 1.04 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 38 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 13 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F CURVE BEFORE FUEL SHUFFLE FOR FLOODED CONDITIONS AND RX WATER TEMPERATURE AT 110 DEGREES 25 20 15 Before Fuel Shuffle 10 TIME TO 200F (HRS)

Multiplier Temp 0.33 170 0.55 150 5 0.77 130 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 39 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 14 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE BEFORE FUEL SHUFFLE FOR FLOODED CONDITIONS 20 15 10 Before Fuel Shuffle HEAT UP RATE (DEGREES/HR) 5 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 40 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 15 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL BEFORE FUEL SHUFFLE FOR FLOODED CONDITIONS AND RX WATER TEMPERATURE AT 110 DEGREES 300 250 200 Before Fuel Shuffle 150 TAF (HRS)

Multiplier Temp 100 0.92 170 0.95 150 0.97 130 1.00 110 50 1.02 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 41 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 16 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200F AFTER FUEL SHUFFLE WITH RX WATER LEVEL AT 36 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 5

4 3

After Fuel Shuffle 2

TIME TO 200F (HRS)

Multiplier Temp 0.33 170 0.55 150 0.77 130 1.00 110 1

1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 42 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 17 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE AFTER FUEL SHUFFLE WITH RX WATER LEVEL AT 36 INCHES 70 60 50 40 30 After Fuel Shuffle HEAT UP RATE (DEGREES/HR) 20 10 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 43 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 18 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL AFTER FUEL SHUFFLE FOR RX WATER LEVEL AT 36 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 20 18 16 14 12 10 TAF (HRS) 8 After Fuel Shuffle 6

Mulitiplier Temp 0.86 170 4 0.90 150 0.95 130 1.00 110 2

1.05 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 44 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 19 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200F AFTER FUEL SHUFFLE WITH RX WATER LEVEL AT 85 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 5

4 3 After Fuel Shuffle 2

TIME TO 200F (HRS)

Multiplier Temp 0.33 170 0.55 150 1 0.77 130 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 45 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 20 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE AFTER FUEL SHUFFLE WITH RX WATER LEVEL AT 85 INCHES 60 50 40 30 After Fuel Shuffle 20 HEAT UP RATE (DEGREES/HR) 10 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 46 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 21 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL AFTER FUEL SHUFFLE FOR RX WATER LEVEL AT 85 INCHES AND RX WATER TEMPERATURE AT 110 DEGREES 25 20 15 TAF (HRS)

After Fuel Shuffle 10 Mulitiplier Temp 0.86 170 5 0.90 150 0.95 130 1.00 110 1.05 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 47 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 22 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F AFTER FUEL SHUFFLE FOR RX WATER LEVEL AT THE MAIN STEAM LINES AND RX WATER TEMPERATURE AT 110 DEGREES 5

4 3

After Fuel Shuffle 2

TIME TO 200F (HRS)

Multiplier Temp 0.33 170 0.55 150 1 0.77 130 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 48 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 23 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE FOR RX WATER AT THE MAIN STEAM LINES AFTER FUEL SHUFFLE 60 50 40 After Fuel Shuffle 30 20 HEAT UP RATE (DEGREES/HR) 10 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 49 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 24 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL AFTER FUEL SHUFFLE AT MAIN STEAM LINES AND RX WATER TEMPERATURE AT 110 DEGREES 30 25 20 After Fuel Shuffle 15 TAF (HRS) 10 Mulitiplier Temp 0.86 170 0.91 150 0.95 130 5

1.00 110 1.05 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 50 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 25 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F AFTER FUEL SHUFFLE FOR RX WATER LEVEL AT THE FLANGE AND RX WATER TEMPERATURE AT 110 DEGREES 6

5 4

3 After Fuel Shuffle TIME TO 200F (HRS) 2 Multiplier Temp 0.33 170 0.55 150 0.77 130 1 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 51 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 26 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE FOR WATER LEVEL AT FLANGE AFTER FUEL SHUFFLE 45 40 35 30 25 After Fuel Shuffle 20 15 HEAT UP RATE (DEGREES/HR) 10 5

0 0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 52 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 27 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL AFTER FUEL SHUFFLE FOR RX WATER LEVEL AT FLANGE AND RX WATER TEMPERATURE AT 110 DEGREES 40 35 30 25 After Fuel Shuffle 20 TAF (HRS) 15 Multiplier Temp 0.88 170 10 0.92 150 0.96 130 1.00 110 1.04 90 5

0 0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 53 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 28 OF 32 THERMAL HYDRAULIC CURVES TIME TO 200 F AFTER FUEL SHUFFLE FOR FLOODED CONDITIONS AND RX WATER TEMPERATURE AT 110 DEGREES 35 30 25 20 After Fuel Shuffle TIME TO 200F (HRS) 15 Multiplier Temp 10 0.33 170 0.55 150 0.77 130 5 1.00 110 1.23 90 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 54 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 29 OF 32 THERMAL HYDRAULIC CURVES HEAT UP RATE FOR FLOODED CONDITIONS AFTER FUEL SHUFFLE 8

7 6

5 After Fuel Shuffle 4

3 HEAT UP RATE (DEGREES/ HR) 2 1

0 0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 55 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 30 OF 32 THERMAL HYDRAULIC CURVES TIME TO TOP OF ACTIVE FUEL AFTER FUEL SHUFFLE FOR FLOODED CONDITIONS AND RX WATER TEMPERATURE AT 110 DEGREES 400 350 300 250 After Fuel Shuffle 200 TAF (HRS) 150 Multiplier Temp 0.92 170 0.95 150 100 0.97 130 1.00 110 1.02 90 50 0

0 5 10 15 20 25 30 35 40 TIME AFTER SHUTDOWN (DAYS)

OSP-0037 REV - 027 PAGE 56 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 31 OF 32 THERMAL HYDRAULIC CURVES BEFORE FUEL SHUFFLE Days After Decay Heat Up Heat Up Heat Heat Time To Time To Time To Time To Time To Time To Time To Time To Shutdown Heat Rate Rate Up Up Mode Mode Mode Mode Top of Top of Top of Top of Flooded Flange Rate Rate Change Change Change Change Active Active Active Active MSL 85 in. Flooded Flange MSL 85 in. Fuel Fuel Fuel Fuel 85 Flooded Flange MSL in.

Days MBtu/hr (F/HR) (F/HR) (F/HR) (F/HR) hrs hrs hrs hrs hrs hrs hrs hrs 1 67.4 16.19 87.59 109.54 110.61 5.56 1.03 .82 .81 60.78 6.79 4.34 4.24 2 55.1 13.24 71.61 89.55 90.43 6.8 1.26 1.01 1.00 74.35 8.30 5.30 5.19 3 48.3 11.6 62.77 78.5 79.27 7.76 1.43 1.15 1.14 84.81 9.47 6.05 5.92 4 43.7 10.5 56.79 71.02 71.72 8.57 1.58 1.27 1.25 93.74 10.47 6.69 6.54 5 40.2 9.66 52.24 65.33 65.98 9.32 1.72 1.38 1.36 101.9 11.38 7.27 7.11 6 37.8 9.08 49.12 61.43 62.04 9.91 1.83 1.47 1.45 108.37 12.1 7.73 7.56 7 35.4 8.5 46.01 57.53 58.1 10.58 1.96 1.56 1.55 115.72 12.92 8.26 8.07 8 33.7 8.1 43.8 54.77 55.31 11.12 2.05 1.64 1.63 121.56 13.58 8.67 8.48 10 30.7 7.37 39.9 49.89 50.38 12.2 2.26 1.8 1.79 133.44 14.9 9.52 9.31 20 23.2 5.57 30.15 37.7 38.08 16.15 2.99 2.39 2.36 176.57 19.72 12.6 12.32 40 17.2 4.13 22.35 27.95 28.23 21.78 4.03 3.22 3.19 238.17 26.6 16.99 16.62 OSP-0037 REV - 027 PAGE 57 OF 62

REFERENCE USE ATTACHMENT 9 PAGE 32 OF 32 THERMAL HYDRAULIC CURVES AFTER FUEL SHUFFLE Time To Time To Time To Time To Time To Time To Time To Time To Heat Up Heat Up Heat Up Heat Up Top of Top of Top of Top of Days After Decay Mode Mode Mode Mode Rate Rate Rate Rate Active Active Active Active Shutdown Heat Change Change Change Change Flooded Flange MSL 85 in. Fuel Fuel Fuel Fuel Flooded Flange MSL 85 in.

Flooded Flange MSL 85 in.

Days MBtu/hr (F/hr) (F/hr) (F/hr) (hrs) (hrs) (hrs) (hrs) (hrs) (hrs) (hrs) (hrs) (hrs) 4 31.09 7.47 40.41 50.53 51.03 12.05 2.23 1.78 1.76 131.74 14.71 9.40 9.19 5 28.60 6.87 37.17 46.49 46.94 13.10 2.42 1.94 1.92 143.21 16.00 10.22 9.99 6 26.90 6.46 34.95 43.71 44.14 13.93 2.57 2.06 2.04 152.31 17.01 10.87 10.63 7 25.19 6.05 32.73 40.94 41.34 14.87 2.75 2.20 2.18 162.63 18.16 11.60 11.35 8 23.98 5.76 31.16 38.97 39.35 15.63 2.89 2.31 2.29 170.84 19.08 12.19 11.92 10 21.84 5.25 28.39 35.50 35.85 17.15 3.17 2.54 2.51 187.53 20.95 13.38 13.08 20 16.51 3.97 21.45 26.83 27.09 22.70 4.20 3.35 3.32 248.15 27.72 17.70 17.31 40 12.24 2.94 15.90 19.89 20.09 30.61 5.66 4.52 4.48 334.72 37.38 23.88 23.35 OSP-0037 REV - 027 PAGE 58 OF 62

SRM Instrumentation 3.3.1.2 3.3 INSTRUMENTATION 3.3.1.2 Source Range Monitor (SRM) Instrumentation LCO 3.3.1.2 The SRM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.2-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required SRMs 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SRMs inoperable in to OPERABLE status.

MODE 2 with intermediate range monitors (IRMs) on Range 2 or below.

B. Three required SRMs B.1 Suspend control rod Immediately inoperable in MODE 2 with withdrawal.

IRMs on Range 2 or below.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met.

D. One or more required D.1 Fully insert all insertable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SRMs inoperable in control rods.

MODE 3 or 4.

AND (continued)

RIVER BEND 3.3-10 Amendment No. 81

SRM Instrumentation 3.3.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Place reactor mode switch 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in the shutdown position.

E. One or more required E.1 Suspend CORE Immediately SRMs inoperable in ALTERATIONS except for MODE 5. control rod insertion.

AND E.2 Initiate action to fully Immediately insert all insertable control rods in core cells containing one or more fuel assemblies.

RIVER BEND 3.3-11 Amendment No. 81, 161

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.

SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.2.2 ---------------------------NOTES-----------------------------

1. Only required to be met during CORE ALTERATIONS.

2. One SRM may be used to satisfy more than one of the following.

Verify an OPERABLE SRM detector is located in: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

a. The fueled region;

b. The core quadrant where CORE ALTERATIONS are being performed when the associated SRM is included in the fueled region; and

c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.

SR 3.3.1.2.3 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

RIVER BEND 3.3-12 Amendment No. 81

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.4 ----------------------------NOTE------------------------------

Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Verify count rate is: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months during CORE

a. t 3.0 cps, or ALTERATIONS

b. t 0.7 cps with a signal to noise ratio t 2:1. AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.1.2.5 ---------------------------NOTE-------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.1.2.6 ------------------------NOTES--------------------------------

1. Neutron detectors are excluded.

2. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL CALIBRATION. 24 months RIVER BEND 3.3-13 Amendment No. 81, 168

SRM Instrumentation 3.3.1.2 Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS REQUIREMENTS

1. Source Range Monitor 2(a) 3 SR 3.3.1.2.1 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 3,4 2 SR 3.3.1.2.3 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 5 2(b),(c) SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 (a) With IRMs on Range 2 or below.

(b) Only one SRM channel is required to be OPERABLE during spiral offload or reload when the fueled region includes only that SRM detector.

(c) Special movable detectors may be used in place of SRMs if connected to normal SRM circuits.

RIVER BEND 3.3-14 Amendment No. 81

Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters LCO 3.6.3.2 Two divisions of primary containment and drywell hydrogen igniters shall be OPERABLE, each with > 90% of the associated igniter assemblies OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One primary containment A.1 Restore primary 30 days and drywell hydrogen containment and drywell igniter division inoperable. hydrogen igniter division to OPERABLE status.

B. Two primary containment B.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and drywell hydrogen means that the igniter divisions inoperable. hydrogen control function is maintained.

AND B.2 Restore one primary 7 days containment and drywell hydrogen igniter division to OPERABLE status.

(continued)

RIVER BEND 3.6-41 Amendment No. 81, 156

Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Energize each primary containment and drywell 184 days hydrogen igniter division and perform current versus voltage measurements to verify required igniters in service.

SR 3.6.3.2.2 -----------------------NOTE----------------------------------

Not required to be performed until 92 days after discovery of four or more igniters in the division inoperable.

Energize each primary containment and drywell 92 days hydrogen igniter division and perform current versus voltage measurements to verify required igniters in service.

SR 3.6.3.2.3 Verify each required igniter in inaccessible areas 24 months develops sufficient current draw for a t 1700qF surface temperature.

(continued)

RIVER BEND 3.6-42 Amendment No. 81, 168

Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.6.3.2.4 Verify each required igniter in accessible areas 24 months develops a surface temperature of t 1700qF.

RIVER BEND 3.6-43 Amendment No. 81, 168

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 B 3.6 CONTAINMENT SYSTEMS B 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters BASES BACKGROUND The primary containment and drywell hydrogen igniters are a part of the combustible gas control required by 10 CFR 50.44 (Ref. 1) and GDC 41, "Containment Atmosphere Cleanup" (Ref. 2), to reduce the hydrogen concentration in the primary containment following a degraded core accident. The hydrogen igniters ensure the combustion of hydrogen in a manner such that containment overpressure failure is prevented as a result of a postulated degraded core accident.

10 CFR 50.44 (Ref. 1) requires boiling water reactor units with Mark III containments to install suitable hydrogen control systems. The hydrogen igniters are installed to accommodate an amount of hydrogen equivalent to that generated from the reaction of 75% of the fuel cladding with water.

This requirement was placed on reactor units with Mark III containments because they were not designed for inerting and because of their low design pressure. Calculations indicate that if hydrogen equivalent to that generated from the reaction of 75% of the fuel cladding with water were to collect in primary containment, the resulting hydrogen concentration would be far above the lower flammability limit such that, without the hydrogen igniters, if the hydrogen were ignited from a random ignition source, the resulting hydrogen burn would seriously challenge the primary containment.

The hydrogen igniters are based on the concept of controlled ignition using thermal igniters designed to be capable of functioning in a post accident environment, seismically supported and capable of actuation from the control room. Igniters are distributed throughout the drywell and primary containment in which hydrogen could be released or to which it could flow in significant quantities. The hydrogen igniters are arranged in two independent divisions such that each containment region has two igniters, one from each division, controlled and powered redundantly so that ignition would occur in each region even if one division failed to energize.

(continued)

RIVER BEND B 3.6-72 Revision No. 0

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 BASES BACKGROUND When the hydrogen igniters are energized they heat up to a surface (continued) temperature t 1700qF. At this temperature, they ignite the hydrogen gas that is present in the airspace in the vicinity of the igniter. The hydrogen igniters depend on the dispersed location of the igniters so that local pockets of hydrogen at increased concentrations would burn before reaching a hydrogen concentration significantly higher than the lower flammability limit.

APPLICABLE The hydrogen igniters cause hydrogen in containment to burn in a SAFETY ANALYSES controlled manner as it accumulates following a degraded core accident (Ref. 3). Burning occurs at the lower flammability concentration, where the resulting temperatures and pressures are relatively benign. Without the system, hydrogen could build up to higher concentrations that could result in a violent reaction if ignited by a random ignition source after such a buildup.

The hydrogen igniters are not included for mitigation of a Design Basis Accident (DBA) because an amount of hydrogen equivalent to that generated from the reaction of 75% of the fuel cladding with water is far in excess of the hydrogen calculated for the limiting DBA loss of coolant accident (LOCA). The hydrogen concentration resulting from a DBA can be maintained less than the flammability limit using the hydrogen recombiners. However, the hydrogen igniters have been shown by probabilistic risk analysis to be a significant contributor to limiting the severity of accident sequences that are commonly found to dominate risk for units with Mark III containment.

The hydrogen igniters are considered to be risk significant in accordance with the NRC Policy Statement.

LCO Two divisions of primary containment and drywell hydrogen igniters must be OPERABLE, each with more than 90% of the igniters OPERABLE (i.e., no more than 5 inoperable).

This ensures operation of at least one igniter division, with adequate coverage of the primary containment and (continued)

RIVER BEND B 3.6-73 Revision No. 0

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 BASES LCO drywell, in the event of a worst case single active failure. This will ensure (continued) that the hydrogen concentration remains near 4.0 v/o.

APPLICABILITY In MODES 1 and 2, the hydrogen igniter is required to control hydrogen concentration to near the flammability limit of 4.0 v/o following a degraded core event that would generate hydrogen in amounts equivalent to a metal water reaction of 75% of the core cladding. The control of hydrogen concentration prevents overpressurization of the primary containment. The event that could generate hydrogen in quantities sufficiently high enough to exceed the flammability limit is limited to MODES 1 and 2.

In MODE 3, both the hydrogen production rate and the total hydrogen produced after a degraded core accident would be less than that calculated for the DBA LOCA. Also, because of the limited time in this MODE, the probability of an accident requiring the hydrogen igniter is low.

Therefore, the hydrogen igniter is not required in MODE 3.

In MODES 4 and 5, the probability and consequences of a degraded core accident are reduced due to the pressure and temperature limitations.

Therefore, the hydrogen igniters are not required to be OPERABLE in MODES 4 and 5 to control hydrogen.

ACTIONS A.1 With one hydrogen igniter division inoperable, the inoperable division must be restored to OPERABLE status within 30 days. In this Condition, the remaining OPERABLE hydrogen igniter division is adequate to perform the hydrogen burn function. However, the overall reliability is reduced because a single failure in the OPERABLE subsystem could result in reduced hydrogen control capability. The 30 day Completion Time is based on the low probability of the occurrence of a degraded core event that would generate hydrogen in amounts equivalent to a metal water reaction of 75% of the core cladding, the amount of time available after the event for operator action to prevent hydrogen accumulation from exceeding the flammability limit, and the low probability of failure of the OPERABLE hydrogen igniter division.

(continued)

RIVER BEND B 3.6-74 Revision No. 0

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 BASES ACTION B.1 and B.2 With two primary containment and drywell igniter divisions inoperable, the ability to perform the hydrogen control function via alternate capabilities must be verified by administrative means within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The alternate hydrogen control capabilities are provided by at least one hydrogen recombiner and one hydrogen mixing subsystem. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time allows a reasonable period of time to verify that a loss of hydrogen control function does not exist. The verification may be performed as an administrative check by examining logs or other information to determine the availability of the alternate hydrogen control capabilities. It does not mean to perform the Surveillances needed to demonstrate OPERABILITY of the alternate hydrogen control capabilities. If the ability to perform the hydrogen control function is maintained, continued operation is permitted with two igniter divisions inoperable for up to 7 days. Seven days is a reasonable time to allow two igniter divisions to be inoperable because the hydrogen control function is maintained and because of the low probability of the occurrence of a LOCA that would generate hydrogen in the amounts capable of exceeding the flammability limit.

C.1 If any Required Action and required Completion Time cannot be met, the plant 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 . The allowed Completion Time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is reasonable, based on (continued)

RIVER BEND B 3.6-75 Revision No. 133

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 BASES ACTIONS C.1 (continued) operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.6.3.2.1 and SR 3.6.3.2.2 REQUIREMENTS These SRs verify that there are no physical problems that could affect the igniter operation. Since the igniters are mechanically passive, they are not subject to mechanical failure. The only credible failures are loss of power or burnout. The verification that each required igniter is energized is performed by circuit current versus voltage measurement of each circuit.

The Frequency of 184 days has been shown to be acceptable through operating experience because of the low failure occurrence, and provides assurance that hydrogen burn capability exists between the more rigorous 24 month Surveillances. Operating experience has shown these components usually pass the Surveillance when performed at a 184 day Frequency. Additionally, these surveillances must be performed every 92 days if four or more igniters in any division are inoperable. The 92 day Frequency was chosen, recognizing that the failure occurrence is higher than normal. Thus, decreasing the Frequency from 184 days to 92 days is a prudent measure, since only two more inoperable igniters (for a total of six) will result in an inoperable igniter division. SR 3.6.3.2.2 is modified by a Note that indicates that the Surveillance is not required to be performed until 92 days after four or more igniters in the division are discovered to be inoperable.

SR 3.6.3.2.3 and SR 3.6.3.2.4 These functional tests are performed every 24 months to verify system OPERABILITY. The current draw to develop a surface temperature of t 1700qF is verified for igniters in inaccessible areas. Inaccessible areas are defined as areas that have high radiation levels during the entire refueling outage period. These areas are the heat exchanger, filter demineralizer, backwash, and holding pump rooms of the RWCU system.

Additionally, the surface temperature of each accessible igniter is verified to be t 1700qF to demonstrate (continued)

RIVER BEND B 3.6-76 Revision No. 143

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 BASES SURVEILLANCE SR 3.6.3.2.3 and SR 3.6.3.2.4 (continued)

REQUIREMENTS that a temperature sufficient for ignition is achieved. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

REFERENCES 1. 10 CFR 50.44.

2. 10 CFR 50, Appendix A, GDC 41.

3. USAR, Section 6.2.5.

RIVER BEND B 3.6-77 Revision No. 143

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

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

Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with fuel A.1 Restore fuel oil level to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months oil level < 45,495 gal and within limits.

t 38,996 gal.

B. One or more DGs with B.1 Restore lube oil 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months lube oil inventory: inventory to within limits.

1. For DG 1A or 1B,

< 367 gal and t 350 gal; and

2. For DG 1C, < 295 gal and t 265 gal.

C. One or more DGs with C.1 Restore fuel oil total 7 days stored fuel oil total particulates to within particulates not within limit. limit.

(continued)

RIVER BEND 3.8-21 Amendment No. 81

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with new D.1 Restore stored fuel oil 30 days fuel oil properties not within properties to within limits. limits.

E. Required Actions and E.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs with diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, or D.

RIVER BEND 3.8-22 Amendment No. 81

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains 31 days t 45,495 gal of fuel.

SR 3.8.3.2 Verify lube oil inventory is: 31 days

a. t 367 gal for DGs 1A and 1B; and

b. t 295 gal for DG 1C.

SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil In accordance are tested in accordance with, and maintained within with the Diesel the limits of, the Diesel Fuel Oil Testing Program. Fuel Oil Testing Program SR 3.8.3.4 Verify each required DG air start receiver pressure is 31 days

a. t 160 psig for DGs 1A and 1B; and

b. t 200 psig for DG 1C.

SR 3.8.3.5 Check for and remove accumulated water from each 31 days fuel oil storage tank.

SR 3.8.3.6 Deleted RIVER BEND 3.8-23 Amendment No. 81 91, 160

Primary Containment Unit Coolers 3.6.1.7 3.6 CONTAINMENT SYSTEMS 3.6.1.7 Primary Containment Unit Coolers LCO 3.6.1.7 Two primary containment unit coolers shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required primary A.1 Restore required 7 days containment unit cooler primary containment inoperable. unit cooler to OPERABLE status.

B. Two required primary B.1 Restore one required 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months containment unit coolers primary containment inoperable. unit cooler to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months RIVER BEND 3.6-25 Amendment No. 81

Primary Containment Unit Coolers 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 Verify each required primary containment unit 31 days cooler pressure relief and backdraft damper in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.6.1.7.2 Verify each required primary containment unit 92 days cooler develops a flow rate of t 50,000 cfm on recirculation flow through the unit cooler.

SR 3.6.1.7.3 Verify each required primary containment unit 24 months cooler actuates throughout its emergency operating sequence on an actual or simulated automatic initiation signal.

RIVER BEND 3.6-26 Amendment No. 81, 168

ML13051A382

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