ML111890017

Initial Exam 2011-301 Final Administrative JPMs

ML111890017
Person / Time
Site:	Oconee
Issue date:	07/06/2011
From:	NRC/RGN-II
To:	Duke Energy Corp
References
50-269/11-301, 50-270/11-301, 50-287/11-301
Download: ML111890017 (235)

Text

ADMIN-125 FS Page 1 of 10 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE ADM-1 25 CALCULATE SHUTDOWN MARGIN (MANUAL CALCULATION)

CANDIDATE EXAMINER

ADMIN-125 ES Page 2 of 10 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE Task:

ION)

CALCULATE SHUTDOWN MARGIN (MANUAL CALCULAT Alternate Path:

No Facility JPM #:

C RO-076 KIA Rating(s):

System: GENERIC K/A: 2.1.43 Rating: 4.1/4.3 Task Standard:

-3.5935).

Shutdown Margin agrees with attached example (-3.5122 to Preferred Evaluation Method:

Preferred Evaluation Location:

X Perform X Simulate Simulator In-Plant Classroom

References:

PT/i IA/i 103/15, Reactivity Balance Procedure Validation Time: 20 minutes Time Critical: NO Time Start:

Candidate:

NAME Time Finish:

Performance Rating: SAT UNSAT Performance Time:

Examiner:

NAME SIGNATURE DATE COMMENTS

ADMIN-125 FS Page 3 of 10 SIMULATOR OPERATOR INSTRUCTIONS None

ADMIN-125 ES Page 4 of 10 Tools/EguipmentlProcedures Needed:

• PT/I /A/1103/O1 5, Reactivity Balance Procedure, ation o Enclosure 13.1, Shutdown Boron Concentration/Shutdown Margin Calcul o Enclosures 13.7 through 13.21

• Calculator

• Straight edge ruler READ TO OPERATOR DIRECTION TO TRAINEE l

I will explain the initial conditions, and state the task to be performed. All contro room steps shall be performed for this JPM, including any required comm unicati ons. I will provide initiating cues and reports on other actions when directed by you. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

INITIAL/CURRENT CONDITIONS Unit 1 has been shutdown for 15 days for leak repair. The following conditions exist:

• Cycle burnup 100 EFPD

• RCS temperature = 60°F

• Control Rod Group I at 0% withdrawn

• Control Rod Group 8 at 35% withdrawn

• Assume 0% for Xenon and Samarium worth

• RCS Boron 1600 ppm

• Present power level is 25 cpm on Nl-2

• The RHOCALC program is not available INITIATING CUES Control Room supervisor directs you to perform the Original manual calculation of SDM using PT/I /A/1103/01 5, Reactivity Balance Procedure, Enclosure 13.1, Shutdown Boron Concentration/Shutdown Margin Calculation up to step 2.7.

This is NOT being performed for a Control Rod Trip Time test.

ADMIN-125 ES Page 5 of 10 STARTTIME:

STEP 1: Step 2.1 This enclosure must be performed twice the second is the separate verification. Circle whether this is the original or the verification: SAT STANDARD:

Student circles Original.

UNSAT COMMENTS:

STEP 2: Step 2.2 Enter the conditions for which this calculation is effective:

Core Burnup: EFPD RCS Temperature °F CRD Grpl Posn: %w/d CRD Grp8 Posn: %w/d NOTE: The Xe/Sm time interval is normally 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. However, any time SAT interval may be used. This time interval is only required if credit is to be taken for Xenon/Samarium.

Xenon/Samarium time interval valid from UNSAT date/time:___________________ to Date/time:______________

STANDARD:

Student enters the values for the required parameters from the INITIAL/CURRENT CONDITIONS.

Core Burnup: 100 EFPD RCS Temperature 60 °E CRD Grpl Posn: 0 %w/d CRD Grp8 Posn: 35 %w/d Student makes N/A for Xenon/Samarium date/time.

COMMENTS:

ADMIN-125 FS Page 6 of 10 STEP 3: Step 2.3 CRITICAL TASK Obtain reference Shutdown Boron Concentration for the effective Burnup and RCS Temp of this calculation (2.2) from one of the following:

Enclosure 13.10, Shutdown Boron Concentration vs. Burnup (Group 1 @

0% wd) if CRD Groups 1-7 are at 0%w/d SAT Enclosure 13.11, Shutdown Boron Concentration vs. Burnup (Group 1 @

50% wd) if CRD Grpl is at 50% and Grp2-7 are at 0%w/d STANDARD:

UNSAT Reference Shutdown Boron Concentration is obtained from the point of intersection of the current cycle burnup and the 60°F curve on Enclosure 13.10 (or table) and the value is recorded of Enclosure 13.1.

1358 PPM (+1-5)

COMMENTS:

STEP 4: Step 2.4 Adjust for non-reference conditions as follows:

STANDARD: SAT Student should determine from the INITIAL/CURRENT CONDITIONS.

that no adjustments are required. All of step 2.4 is NOT applicable.

COMMENTS: UNSAT STEP 5: Step 2.5 Determine required shutdown boron concentration as follows:

Step 2.5.1 Subtract 2.4.7 (IF 2.4.7 applicable) OR 2.4.6 (IF 2.4.7 NOT applicable) from 2.3 to obtain the required Boron concentration for 1%1kIk shutdown margin (assumes worst rod stuck out):

- =

step 2.3 steps 2.4.7 or 2.4.6 pos or zero SAT STANDARD:

Determine that required boron concentration is equal to reference shutdown boron concentration.

UNSAT 1358 (+/-5) ppmB - 0 ppmB = 1358 (+1-5) ppmB step 2.3 steps 2.4.7 or 2.4.6 pos or zero COMMENTS:

ADMIN-125 FS Page 7 of 10 STEP 6: Step 2.5.2 Obtain minimum RCS Boron Concentration for SSF operability from CRITICAL TASK Enclosure 13.20, Minimum RCS Boron Concentration to Maintain SSF Operability, using the Minimum Xenon from the effective time period:

Minimum RCS Boron for SSF operability =

STANDARD: SAT The student should determine that the Minimum RCS Boron for SSF operability is 1071 PPM (+1-10).

UNSAT COMMENTS:

STEP 7: Step 2.5.3 Determine the minimum RCS Boron Concentration by recording the CRITICAL TASK GREATER of step 2.5.1 and 2.5.2:

Minimum RCS Shutdown Boron Concentration =

SAT STANDARD:

The student should determine that the greater of the boron concentrations is same as step 2.5.1 value. (1358 ppmB +1-5)

UNSAT COMMENTS:

STEP 8: Step 2.6 IF desired, calculate actual shutdown margin as follows:

Step 2.6.1 Record actual RCS conditions:

RCS Boron Concentration: ppmB RCS Temperature°F STANDARD: SAT RCS Boron Concentration 1600 ppmB RCS Temperature 60 °F UNSAT COMMENTS:

_______ppmB _____

ADMIN-125 FS Page 8 of 10 STEP 9: Step 2.6.2 CRITICAL TASK the actual Boron Subtract the required Boron concentration in 2.5.1 from positiv e unless a 1% \k/k concentration in 2.6.1, the result should be shutdown margin has r been establi shed:

= SAT step 2.6.1 step 2.5.1 should be pos STANDARD: of 1600 and The student should subtract the (1405) from the actual UNSAT obtain a net result of (195) ppmB (positive).

1600 ppmB - 1358 ppmB = 242 (+1-5) ppmB step 2.6.1 step 2.5.1 should be pos COMMENTS:

STEP 10: Step 2.6.3 CRITICAL TASK times the Calculate the actual shutdown margin by multiplying 2.6.2 ure 13.8, Differe ntial Boron Worth Differential Boron Worth from Enclos vs. Burnup and subtracting 1%tkIk  :

ppmB x - 1%lXkik=

( should be neg step 2.6.2 negative SAT End 13.8 STANDARD: 1%tkIk= -3.553 %k/k 242 (+1-5> ppmB x -0.01055 (+1- 0.00005) %k/k/ppmB) negative should be neg step 2.6.2 UNSAT End 13.8 is between Candidate determines SDM is greater than 1%tKIK and

-3.51 22 to -3.5935% AkIk.

COMMENTS:

END OF TASK STOP TIME:

ADMIN-125 FS Page 9 of 10 CRITICAL STEP EXPLANATIONS STEP # Explanation 3 Necessary to produce an accurate SDM 6 Necessary to produce an accurate SDM 7 Necessary to produce an accurate SDM 9 Necessary to produce an accurate SDM the requirements of 10 It is critical to calculate shutdown margin accurately to verify Technical Specifications are met.

CANDIDATE CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL/CURRENT CONDITIONS Unit 1 has been shutdown for 15 days for leak repair. The following conditions exist:

• Cycle burnup = 100 EFPD

• RCS temperature = 60°F

• Control Rod Group 1 at 0% withdrawn

• Control Rod Group 8 at 35% withdrawn

• Assume 0% for Xenon and Samarium worths

• RCS Boron 1600 ppm

• Present power level is 25 cpm on Nl-2

• The RHOCALC program is not available INITIATING CUES using Control Room supervisor directs you to perform the Original manual calculation of SDM PT/1/A11103/015, Reactivity Balance Procedure, Enclosure 13.1, Shutdown Boron Concentration/Shutdown Margin Calculation up to step 2.7.

This is NOT being performed for a Control Rod Trip Time test.

Duke Energy Procedure No.

Oconee Nuclear Station pT/l/A11103/o15 REACTIVITY BALANCE PROCEDURE (Unit 1) Revision No.

068 Electronic Reference No.

OXO02WBQ Continuous Use PERFORMANCE I UNCONTROLLED FOR PRINT (ISSUED) PDF Format

PT/i/A/i 103/015 Page 2 of 8 Reactivity Balance Procedure

1. Purpose 1.1 To calculate the Boron concentration necessary to provide greater than 1% AK/K shutdown margin.

1.2 To calculate the actual shutdown margin when the reactor is shutdown.

1.3 To evaluate the available shutdown margin during power operation (e.g., in the event of an inoperable rod.)

1.4 To provide the minimum RCS Boron concentration required to ensure greater than 1%

AK/K shutdown margin to perform the Control Rod Drive (CRD) patch verification (for initial startup following refueling).

1.5 To estimate the critical rod configuration or the critical Boron concentration prior to startup.

1.6 To provide a method for preventing inadvertent criticality using subcritical multiplication measurement.

1.7 To provide nominal APSR position.

1.8 To provide the Minimum RCS Boron Concentration to maintain SSF Operability

2. References 2.1 Technical Specifications: 1.1, Definitions Shutdown Margin 3.1.1, Shutdown Margin 3.1.4, Control Rod Group Alignment Limits 3.1.5, Safety Rod Position Limits 3.2.1, Regulating Rod Position Limits 3.3.9, Source Range Neutron Flux 3.9.1, Boron Concentration 2.2 Selected Licensee Commitments: 16.13.4, Reactivity Anomaly 2.3 Unit 1 - Physics Test Manual (PTM), ONEI-0400-55 2.4 Unit 1 - Core Operating Limits Report (COLR), ONEI-0400-50

PT/i/A/I 103/015 Page 3 of 8 2.5 Nuclear Systems Directive 304, Reactivity Management 2.6 Work Process Manual, Section 2.5, Testing

3. Time Required Two people - 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for most enclosures

4. Prerequisite Tests None

5. Test Equipment Personal computer (for computerized calculations)

6. Limits and Precautions 6.1 The results of this procedure are used to make important operational decisions, therefore this procedure affects core reactivity. (R.M.)

6.2 Appropriate corrections have been made per this procedure, or actual plant conditions must be the same as the reference conditions stated on the appropriate enclosure(s).

(R.M.)

6.3 Separate verification is required for each calculation performed. For hand calculations, this requires that two people separately complete the appropriate enclosures for the desired calculation to verify the results are in agreement. For computerized calculations, this requires that two people separately run the computer code(s) or verify the input.

(R.M.)

6.4 IF the power history information from the last equilibrium Xe/Sm condition is NOT input into the code, significant error may result. (R.M.)

6.5 Per Technical Specification 3.1.5 all safety rods (groups 1-4) must be fully withdrawn prior to MODE 2 entry (Keff> 0.99, SDM < 1% AKJK). (R.M.)

7. Required Unit Status None

8. Prerequisite System Conditions None

PT/i/A/i 103/0 15 Page4of8

9. Test Method 9.1 Shutdown Boron Concentration:

centration!Shutdown Margin Calculated in Enclosure 13.1, Shutdown Boron Con Calculation.

Calculation, or 13.2, Computerized Shutdown Margin 1.0% AKIK shutdown margin The shutdown Boron concentration provides a greater than with the worst case stuck rod assumed to be out.

ined based on the cycle bumup, rod A reference shutdown Boron concentration is obta of Xenon, Samarium, and the positions and RCS temperature. The reactivity worths their equivalent Boron inoperable rod penalty (if applicable) are converted into Xenon worth occurring in a concentrations. (Credit is taken only for the minimum The Shutdown Boron specified time interval, which should not exceed 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />.

to uncertanities in the Xenon concentration is valid iy during that time interval. Due unless the RCS is below models, 0.8 times the Xenon and Samarium worth are used worths are used. Xenon and 450°F, in which case 0.5 times the Xenon and Samarium ervatism.) These Boron Samarium worths may be assumed to be zero for cons concentration to provide the concentrations are then applied to the reference Boron shutdown margin (i.e., the required Boron concentration for a greater than 1.0% MKIK shutdown Boron concentration).

9.2 Shutdown Margin Calculation while Shutdown:

ationlShutdown Margin Calculated in Enclosure 13.1, Shutdown Boron Concentr in Calculation.

Calculation or 13.2, Computerized Shutdown Marg the reactor is shutdown. The The shutdown margin is the amount of reactivity by which with a known inoperable rod, an worst case stuck rod is assumed to be out. If operating penalty need not be applied additional penalty is applied to account for that rod. This d to be fully inserted by when the reactor is shutdown if that rod can be confirme tion must first be found per step redundant indications. The shutdown Boron concentra d from this concentration and the 9.1. The actual Boron concentration is then subtracte d from this value to obtain the result converted to % z\KiK. 1.0% z\KIK is then subtracte for SSF RC Makeup System shutdown margin, expressed in % z\KIK. A separate check requires the stuck rod penalty.

operability is performed, which takes credit for Xenon and Boron Concentration to Maintain This limit is shown in Enclosure 13.20, Minimum RCS SSF Operability.

PT/i/A/i 103/0 15 Page 5 of 8 of Shutdown may be used with Following a shutdown, Control Rod Position at the time 1% z\KIK shutdown margin the Rod Position Limit curves (in COLR) to verify at least Temperature stays? 532°F and for the first 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> following shutdown (provided RCS wns with an inoperable rod, boron does not decrease). This may be necessary for shutdo ure 13.1, Shutdown Boron since the more conservative calculation method (in Enclos Compu terized Shutdown Margin ConcentrationlShutdown Margin Calculation, and 13.2, immediately after shutdown.

Calculation) may not show 1% zKIK shutdown margin 1% KJK shutdown margin using Boration should begin immediately to be able to show the calculation method.

9.3 Shutdown Margin at Power:

at Power.

Verified in Enclosure 13.18, Shutdown Margin Calculation verified to be?: 1% AKIK by While at power, the available shutdown margin may be in the Acceptable Region using the Rod Position Limits curves (in COLR). Operation ing a reactor trip will be? 1%

of these curves ensures that the shutdown margin follow and 4 RCP operation, and zXKIK with the worst stuck rod out. There are curves for 3 ered inoperable for the curves for 0 and 1 inoperable rod. A dropped rod is consid purposes of providing shutdown margin while at power.

9.4 Estimated Critical Rod Position:

l Rod Position Calculation.

Calculated in Enclosure 13.4, Computerized Estimated Critica burnup. The reactivity worths The core excess reactivity is obtained based on the cycle RCS temperature not at 53 2°F) associated with Boron, Xenon, temperature correction (if core excess reactivity. The groups and Samarium are then obtained and summed with the rod worth when summed with all 5-7 positions are then determined for which the inserted upper and lower rod position the above, yields a total core reactivity of 0.0% AKJK. The ns are recorded.

limits are then determined and the actual critical rod positio 9.5 Estimated Critical Boron Concentration:

l Boron Calculation.

Calculated in Enclosure 13.5, Computerized Estimated Critica

. The reactivity worth The core excess reactivity is obtained based on the cycle bumup ature not at 532°F),

associated with Xenon, temperature correction (if RCS temper with the core excess Samarium and the desired critical rod positions are summed for which its reactivity worth, reactivity. The Boron concentration is then determined ity of 0.0% AK/K.

when summed with all the above, yields a total core reactiv

PT/i/A/l 103/0 15 Page 6 of 8 9.6 Subcritical Multiplication Measurement:

Performed in 13.6, Computerized Subcritical Multiplication (1/M) Measurement.

With Group 1 at 50% wd, an initial source range (SR) count rate (C ) is recorded. During 0

control rod withdrawals, new counts (C) are recorded and used to calculate 1/M, or C /C.

0 As criticality is approached, C/C0 will approach infinity, and l/M will approach zero.

Plotting 1/M versus rod worth provides a rough indication of what rod position will yield a critical condition, and acts as an indication of premature criticality, or criticality more than 0.75% AK/K below the Estimated Critical Position calculated in step 9.4.

10. Data Required 10.1 For Xenon Worth: Core EFPD and power history to time of last equilibrium xenon.

10.2 For Shutdown Boron Concentration/Shutdown Margin Calculation: Power History, Boron Concentration, RCS temperature, Core EFPD, Group 8 position, any inoperable rod penalty.

10.3 For Estimated Critical Rod Configuration: Boron Concentration, RCS temperature, Core EFPD, Group 8 Position, and power history.

10.4 For Estimated Critical Boron Configuration: RCS temperature, Core EFPD, desired critical rod configuration and power history.

10.5 For Subcritical Multiplication Measurement: ECP Control Rod position, time safety groups must be thuly withdrawn, Unit, Cycle, Beginning of Cycle (Yes/No), EFPD, Graph Notify Lines (Yes/No), Xenon Free (Yes/No), and source range (SR) count rate.

11. Acceptance Criteria 11.1 Separate verifications for Shutdown Boron shall agree within 10 ppmB. The more conservative Shutdown Boron Concentration calculation shall be used to ensure at least a 1.0% AK/K shutdown margin.

11.2 Separate verifications for Estimated Critical Boron shall agree within 10 ppm.

11.3 Separate verifications for Estimated Critical Positions shall agree within 5% wd.

11.4 Acceptance criteria for 1/M approach to critical: Criticality is achieved within 0.75% Ak/k of the predicted critical rod position concentration.

11.5 Review criteria for 1/M approach to critical: Criticality achieved within 0.35%Ak!k of the predicted critical rod position for startups considered Xenon free, 0.5% AkJk review criteria for non-Xenon free startups.

PT/i/All 103/0 15 Page 7 of 8

12. Procedure Complete, or refer to, the appropriate enclosure(s):

Shutdown Margin Calculation while shutdown:

tdown Margin Calculation, Enclosure 13.1, Shutdown Boron ConcentrationlShu or ulation Enclosure 13.2 Computerized Shutdown Margin Calc Estimated Critical Rod Position:

Position Calculation Enclosure 13.4, Computerized Estimated Critical Rod Estimated Critical Boron Concentration:

Calculation Enclosure 13.5, Computerized Estimated Critical Boron Computerized Subcritical Multiplication (1/M) Measurement ation (1/M) Measurement Enclosure 13.6, Computerized Subcritical Multiplic Refueling Outage Boron Concentrations:

ations Enclosure 13.13, Refueling Outage Boron Concentr Required Control Rod Group 8 Position:

gned Cycle Length Enclosure 13.14, Required Group 8 Position and Desi Designed Cycle Length Information:

gned Cycle Length Enclosure 13.14, Required Group 8 Position and Desi Required Shutdown Margin:

Enclosure 13.16, Shutdown Margin Requirements Shutdown Margin Calculation at power:

Enclosure 13.18, Shutdown Margin Calculation at Power RCS Boron Concentration for SSF Operability:

Maintain SSF Operability Enclosure 13.20, Minimum RCS Boron Concentration to RCMU Letdown Flow Degraded:

RCS Boron Concentration for SSF Operability with SSF Maintain SSF Operability with Enclosure 13.21, Minimum RCS Boron Concentration to Bypass Open SSF RCMU Letdown Flow Degraded 50% & SSF RCMU

PT/i/A/I 103/0 15 Page 8 of 8 NOTE: Only the appropriate completed enclosures need be attached to the procedure cover sheet to be submitted for procedure completion.

13. Enclosures 13.1 Shutdown Boron ConcentrationlShutdown Margin Calculation 13.2 Computerized Shutdown Margin Calculation 13.3 Computerized Shutdown Margin Calculation Documentation 13.4 Computerized Estimated Critical Rod Position Calculation 13.5 Computerized Estimated Critical Boron Calculation 13.6 Computerized Subcritical Multiplication (1/M) Measurement 13.7 Core Excess Reactivity vs. Burnup 13.8 Differential Boron Worth vs. Burnup 13.9 Temperature Coefficient vs. RCS Boron Concentration 13.10 Shutdown Boron Concentration vs. Bumup (Group 1 @ 0% wd) 13.11 Shutdown Boron Concentration vs. Burnup (Group 1 @ 50% wd) 13.12 Inoperable Rod Penalty for Individual Inoperable Rod 13.13 Refueling Outage Boron Concentrations 13.14 Required Group 8 Position and Designed Cycle Length 13.15 Power Defect vs. Reactor Power 13.16 Shutdown Margin Requirements 13.17 Control Rod Group Worths for Control Rod Drop Time Testing 13.18 Shutdown Margin Calculation at Power 13.19 Group 7 Control Rod Worth 13.20 Minimum RCS Boron Concentration to Maintain SSF Operability 13.21 Minimum RCS Boron Concentration to Maintain SSF Operability with SSF RCMU Letdown Flow Degraded 50% & SSF RCMU Bypass Open

Enclosure 13.1 PT/1/A11103/015 Shutdown Boron Concentration/Shutdown Page 1 of 5 Margin Calculation Calculation Performed By:________________ Date: Time:_______________

NOTE: This enclosure assumes the SDM computer code is unavailable.

1. Purpose The purpose of this enclosure is to manually calculate a shutdown margin.

2. Procedure 2.1 This enclosure must be performed twice the second is the separate verification. Circle whether this is the original or the verification:

Original May be performed by anyone trained on this procedure Separate Verification Must be Licensed Operator or a Qualified Reactor Engineer (N/A steps 2.10-2.13 for Separate Verification.)

2.2 Enter the conditions for which this calculation is effective:

Core Bumup: EFPD RCS Temperature °F CRD Grpl Posn: %w/d CRD Grp8 Posn: %w/d NOTE: The Xe/Sm time interval is normally 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. However, any time interval may be used.

This time interval is only required if credit is to be taken for XenonlSamarium.

XenonlSamarium time interval valid from date/time:________________________ to date/time:________________________

2.3 Obtain reference Shutdown Boron Concentration for the effective Bumup and RCS Temp of this calculation (2.2) from one of the following:

Enclosure 13.10, Shutdown Boron Concentration vs. Burnup (Group I @ 0% wd) if CRD Groups 1-7 are at 0%w/d Enclosure 13.11, Shutdown Boron Concentration vs. Burnup (Group 1 @ 50% wd) if CRD Grpl is at 50% and Grp2-7 are at 0%w/d C__

Lsitive J

Enclosure 13.1 PT/i/A/i 103/0 15 Shutdown Boron Concentration/Shutdown Page 2 of 5 Margin Calculation 2.4 Adjust for non-reference conditions as follows:

2.4.1 IF available, independently obtain Xenon + Samarium worth from the OAC or PT. Use the minimum Xenon + Samarium worth which occurs at or between the time interval specified in 2.2 above.

• IF desired zero may be used for conservatism.

• IF the RCS temperature is at or above 450°, multiply by 0.8.

• IF the RCS temperature is less than 450°F multiply by 0.5:

negative x

0.8orO.5 Enegative %k/k Xe+Sm Wrth 2.4.2 IF credit is taken for Xenon worth in 2.4.1, initial and attach the Xenon computer printout AND actual power history (from OAC log, TMS, P1, etc.)

to this enclosure.

2.4.3 IF shutdown with a stuck rod (see step 9.2) obtain Inoperable Rod Penalty from Enclosure 13.12, Inoperable Rod Penalty for Individual Inoperable Rod:

Inoperable Rod Group#: Rod#: r positive 2.4.4 IF this calculation is for CRDTTT, obtain the Control Rod Worth for the highest worth group to be tested for the applicable conditions from Enclosure 13.17, Control Rod Group Worths for Control Rod Drop Time Testing:

Rod Group#:_________ I positive 2.4.5 2.4.6 Sum 2.4.1 + 2.4.3 + 2.4.4 =______

[ neg or pos Obtain boron concentration adjustment by dividing 2.4.5 by Differential I

Boron Worth from Enclosure 13.8, Differential Boron Worth vs.

/ %zkJkIppmB neg or pos negative step 2.4.5 End 13.8

Enclosure 13.1 PT/1/A,1103/015 Shutdown Boron Concentration/Shutdown Page 3 of 5 Margin Calculation 2.4.7 IF Group 8 is NOT 30 -40 %wd, AND bumup < APSR pull window (or No APSR pull this cycle) noted in Enclosure 13.14, Required Group 8 Position and Designed Cycle Length, subtract 50 ppmB from 2.4.6:

neg or pos

- 50 ppmB = Ineg or posppmB 2.5 Detennine required shutdown boron concentration as follows:

CAUTION: IF steps 2.4.6 OR 2.4.7 are negative values, THEN a negative number will be subtracted.

2.5.1 Subtract 2.4.7 (Ij 2.4.7 applicable) OR 2.4.6 (jj 2.4.7 NOT applicable) from 2.3 to obtain the required Boron concentration for 1 %Aklk shutdown margin (assumes worst rod stuck out):

=

step 2.3 steps 2.4.7 or 2.4.6 pos or zero 2.5.2 Obtain minimum RCS Boron Concentration for SSF operability from Enclosure 13.20, Minimum RCS Boron Concentration to Maintain SSF Operability, using the Minimum Xenon from the effective time period:

Minimum RCS Boron for SSF operability = PPmB]

2.5.3 Determine the minimum RCS Boron Concentration by recording the GREATERofstep2.5.1 and 2.5.2:

Minimum RCS Shutdown Boron Concentration

[ ppmB 2.6 IF desired, calculate actual shutdown margin as follows:

2.6.1 Record actual RCS conditions:

RCS Boron Concentration: ppmB RCS Temperature °F 2.6.2 Subtract the required Boron concentration in 2.5.1 from the actual Boron concentration in 2.6.1, the result should be positive unless a 1%Ak/k shutdown margin has NOT been established:

=

step 2.6.1 step 2.5.1 1.should be pos

Enclosure 13.1 PT/1/A/11o3/o15 Shutdown Boron Concentration/Shutdown Page 4 of 5 Margin Calculation 2.6.3 Calculate the actual shutdown margin by multiplying 2.6.2 times the Differential Boron Worth from Enclosure 13.8, Differential Boron Worth vs.

Burnup and subtracting 1%zk/k:

x - 1%Ak/kT step 2.6.2 negative should be neg End 13.8 2.7 Verify Separate Verification agrees within 10 ppmB of the Original on Step 2.5.3.

(R.M.)

2.8 IF this calculation is being used to verify shutdown margin for present reactor conditions, perform the following:

2.8.1 Verify that the shutdown margin (Step 2.6.3) is greater than 1%

M(JK (i.e.

1 more negative than -1.O%AKJK) (R.M.)

OR 2.8.2 Perform the following:

A. Notify Control Room SRO immediately.

B. IF within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> of shut down, verify Shutdown Margin using COLR curve (verification method in step 9.2). (R.M.)

C. Initiate boration to establish adequate Shutdown Margin. (R.M.)

ops AND 2.8.3 Ensure the present boron concentration is greater than the boron concentration in2.5.3.

2.9 IF this calculation is being used to project shutdown margin for future conditions, inform the Control Room SRO that the required boron concentration to ensure a greater than 1 %zXKIK shutdown margin for the above reference conditions must be greater than the concentration in Step 2.5.3. (R.M.)

2.10 Discuss the results of the shutdown margin calculation with the Control Room SRO.

(N/A this step on separate verification calculation).

Control Room SRO 2.11 Attach the results of the shutdown margin calculations to a procedure cover sheet and turn the package over to the Control Room SRO. (N/A this step on the separate verification calculation.)

Enclosure 13.1 PT/i/A/i 103/015 Shutdown Boron Concentration/Shutdown Page 5 of 5 Margin Calculation 2.12 IF desired, place a copy of the shutdown margin in the Current Unit Shutdown Margins folder located in the Reactor Engineering procedure cabinet. (N/A this step on the separate verification calculation.)

NOTE: The Reactor Engineering mail code is ONO3CV.

2.13 WHEN the shutdown margin calculation is no longer required, return this procedure, including all applicable enclosures and attachments, to Reactor Engineering for procedure completion and review. (N/A this step on the separate verification calculation.)

Enclosure 13.2 PT/i/A/l 1 03/015 Computerized Shutdown Margin Calculation Page 1 of 2

1. Purpose Caic.

The purpose of this enclosure is to calculate a shutdown margin using a Rho

2. Procedure Calculation Performed by:_____________________

ation. Circle 2.1 This enclosure must be performed twice the second is the separate verific whether this is the original or the verification:

Original May be performed by anyone trained on this procedure Separate Verification Must be a Licensed Operator or a Qualified Reactor Engineer (N/A steps 2.7-2.10 for Separate Verification) ion is CAUTION: 1. IF the power history information from the last equilibrium Xe/Sm condit NOT input into the code, significant error may result.

to

2. IF Xenon credit is required the EFPD input into the code SHALL correspond the beginning of the power history, NOT the EFPD at the effect ive time of calculation.

wn

3. The RhoCalc code uses the EFPD that is input to the code to lookup the shutdo boron concentration. Therefore, the EFPD used for shutdown margin when taking credit for Xenon may be less than the current burnup.

2.2 IF credit for Xenon is taken:

2.2.1 Obtain the power history back to the last time of Xenon Equilibrium to perform the Xenon calculation from a source such as PT server, OAC Log, RO Log, etc.

2.2.2 Attach actual power history (from OAC log, TMS, P1 Server, etc.) to this enclosure.

2.3 Open RhoCalc.

ation NOTE: IF a printer is not available, Enclosure 13.3, Computerized Shutdown Margin Calcul Documentation, may be used to document this calcula tion.

2.4 Input appropriate data for the shutdown margin calculation, select Calculate SDM and print.

2.5 Verify that the final required RCS boron concentrations on Separate Verifications agree within 10 ppmB.

Enclosure 13.2 PT/1/A/1103/015 Computerized Shutdown Margin Calculation Page 2 of 2 2.6 IF calculation is being used to verify shutdown margin for present conditions, perform one of the following:

2.6.1 Verify that the shutdown margin is more negative than -1.00 %Ak/k. (R.M.)

OR 2.6.2 Perform the Following:

A. Notify Control Room SRO immediately.

B. IF within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> of shut down, verify Shutdown Margin using COLR curve (verification method in step 9.2). (R.M.)

C. Initiate boration to establish adequate SDM (R.M.)

ops 2.7 Discuss the results of the shutdown margin calculation with the Control Room SRO.

(N/A this step on separate verification calculation).

Room SRO 2.8 Attach results of shutdown margin calculation to the procedure and turn the package over to the Control Room SRO. (N/A this step on separate verification calculation).

2.9 IF desired, place a copy of the shutdown margin in the Current Unit Shutdown Margins folder located in the Reactor Engineering procedure cabinet. (N/A this step on the separate verification calculation.)

NOTE: The Reactor Engineering mail code is ONO3CV.

2.10 WHEN the shutdown margin calculation is no longer required, return this procedure, including all applicable enclosures and attachments, to Reactor Engineering for procedure completion and review. (N/A this step on the separate verification calculation.)

Enclosure 13.3 PT/1/A!11o3/o15 Computerized Shutdown Margin Calculation Page 1 of 1 Documentation

1. Purpose The purpose of this enclosure is to document the shutdown margin calculated in Enclosure 13.2, Computerized Shutdown Margin Calculation, when a printer is not available.

2. Procedure 2.1 After performing steps 2.1 through 2.4 of Enclosure 13.2, Computerized Shutdown Margin Calculation, copy the following information off of the computer screen:

Performed By: Date/Time Calculation is Effective For:

Burnup EFPD RCS Temperature deg F Group 8  % wd Present Boron Concentration ppmB Xe/Sm Credit Calculation Good From: Date/Time To: Date/Time DBW  % delta-k!k/ppmB Reference Shutdown Boron Concentration Xe+Sm Worth  % delta-k/k Rod Penalty  % delta-k/k Grp 8 Position Penalty Adjustment______ ppmB Rod Group Rod Number Xe/SmJRod-Grp Out/Group 8 Boron Adjustment ppmB Boron Concentration Required for 1 %Aic/k Shutdown ppmB Minimum RCS Boron Concentration required for SSF Operability ppmB Minimum RCS Boron Concentration ppmB Shutdown Margin at Present Conditions  % delta-k/k RCS Temperature Group 1 at 0%wd Group 1 at 50%wd 60 200 300 400 449 450 500 532 Independent Verification:

Enclosure 13.4 PT/1/A/11o3/015 Computerized Estimated Critical Rod Position Page 1 of 4 Calculation

1. Purpose The purpose of this enclosure is to calculate an estimated critical rod position to be used during unit start up.

2. Procedure Calculation Performed by:_____________________

2.1 This enclosure must be performed twice the second is the separate verification. Circle whether this is the original or the verification:

Original Must be performed by a Licensed Operator (N/A next bullet step)

Separate Verification Must be performed by a Qualified Reactor Engineer (N/A steps 2.9-2.14 for Separate Verification)

NOTE: The only acceptance criterion is that measured RCS % design flow is greater than that required. RPS flows can be expected to deviate from baseline.

2.2 IF returning from a forced outage, perform an RCS flow check using POWCALC.XLS AND attach results to this enclosure.

CAUTION: IF the power history information from the last equilibrium Xe/Sm condition is NOT input into the code, significant error may result.

NOTE: IF conducting an initial cycle startup the power history is 0% F. P.

2.3 IF returning from a forced shutdown:

2.3.1 Obtain the power history back to the last time of Xenon Equilibrium to perform the Xenon calculation from a source such as PT server, OAC Log, RO Log, etc.

2.3.2 Attach actual power history (from OAC log, TMS, PT Server, etc.) to this enclosure.

2.4 Open RhoCalc.

Enclosure 13.4 PT/i/All 103/015 Computerized Estimated Critical Rod Position Page 2 of 4 Calculation NOTE: 1. EFPD input into the code shall correspond to the beginning of the power history, NOT the EFPD at the effective time of calculation.

2. When choosing the input Boron concentration during transient Xenon conditions sufficient time must be factored in to allow for changes to be made to the RCS and PZR Boron concentration, samples to be taken, the time required to pull Groups 1 4-to 100% wd, and any other time constraints noted by the 0CC.

3. The ECP time shall run sufficiently into the future to determine if MODE 2 entry could occur with Group 5 <0%. This time of occurrence is required in step 2.8

4. Estimated conditions (i.e. RCS BoronlTemperature) at the time of criticality may be used.

2.5 Input appropriate data for the estimated critical rod position calculation, select Calculate ECP, and print.

2.6 Circle the appropriate response:

Were estimated conditions used for the ECP? Yes/No 2.7 Verify Separate Verifications agree on the ECP within 5%wd for all future time steps that have an ECP prediction.

Enclosure 13.4 PT/i/A/i 103/015 Computerized Estimated Critical Rod Position Page 3 of 4 Calculation CAUTION: 1. All safety Rods (Groups 1-4) must be fully withdrawn prior to the time that Rod Posn Mode 2 Entry (T.S. 3.1.5) column reaches Group 5<0%. T. S. 3.1.5 prohibits entering Mode 2 (Keff> 0.99, SDM <1% dKIK) on the Safeties.

Groups I 4 can NOT be fully withdrawn prior to the Rod Posn @ Mode 2 Entry (T.S. 3.1.5) column indicating 5 <0%, any in-progress approach to critical must be aborted AND the RCS borated sufficiently to meet T.S. 3.1.5 requirements.

2. IF the RCS is sufficiently borated to account for Xe decay to Xe free conditions, Step 2.8.2 may be N/Aed because the T.S. 3.1.5 limit will NOT be reached AND Mode 2 (Keff> 0.99, SDM <1% dKIK) will NOT be entered on the Safeties.

2.8 Complete one of the following steps:

2.8.1 Verify that the RCS is sufficiently borated to account for Xe decay such that entry into T.S. 3.1.5 will NOT occur.

OR 2.8.2 Document the time/date of the time step immediately prior to the first occurrence ofS <0% in the Rod Posn @ Mode 2 Entry (T.S. 3.1.5) column of the ECP printout.

Time at which the safety rods must be fully withdrawn:

hours on 2.9 Discuss the results of ECP with the Control Room SRO. (N/A this step on separate verification calculation).

Room SRO 2.10 Attach results of ECP to the procedure and turn the package over to the Control Room SRO. (N/A this step on separate verification calculation).

2.11 Fill in the actual critical rod configuration and notification limit check on the computer printout. (N/A this step on separate verification calculation).

NOTE: The notification lines of 1/M.xls spreadsheet are the review and acceptance criteria of 11.4 and 11.5. IF these criteria are NOT met see the WPM section 2.5, Testing, Approach to Critical Rod Position.

2.12 Verify actual critical conditions are within i/M.xls notification lines. (N/A this step on separate verification calculation.)

Enclosure 13.4 PT/i/A/i 103/0 15 Computerized Estimated Critical Rod Position Page 4 of 4 Calculation NOTE: The Reactor Engineering mail code is ONO3CV.

2.13 Forward the completed ECP, including all applicable enclosures and attachments, to Reactor Engineering. (N/A this step on the separate verification calculation.)

NOTE: The GO Nuclear Design Group requires the Procedure Completion Approved blank to be signed off prior to transmittal.

2.14 Transmit copy of completed ECP to GO Nuclear Design. (N/A this step on separate verification calculation.)

Enclosure 13.5 PT/i/A/i 103/015 Computerized Estimated Critical Boron Page 1 of 2 Calculation

1. Purpose The purpose of this enclosure is to calculate an estimated critical boron concentration to be used during unit start up.

2. Procedure Calculation Performed by:_____________________

2.1 This enclosure must be perfonned twice the second is the separate verification. Circle whether this is the original or the verification:

Original Must be performed by a Licensed Operator Separate Verification Must be performed by a Qualified Reactor Engineer (N/A steps 2.8-2.10 for Separate Verification)

CAUTION: j the power history information from the last equilibrium Xe/Sm condition is NOT input into the code, significant error may result.

NOTE: jj conducting an initial cycle startup the power history is 0% F. P.

2.2 jj returning from a forced shutdown:

2.2.1 Obtain the power history back to the last time of Xenon Equilibrium to perform the Xenon calculation from a source such as P1 server, OAC Log, RO Log, etc.

2.2.2 Attach actual power history (from OAC log, TMS, P1 Server, etc.) to this enclosure.

2.3 Open RhoCaic.

Enclosure 13.5 PT/1/A/11o3/o15 Computerized Estimated Critical Boron Page 2 of 2 Calculation NOTE: 1. The target ECP is normally -Group 6 at 50% for reactor startups other than the initial cycle startup. This can be adjusted to plant conditions at the discretion of the SRO.

IF deviating from this position significantly, model the power increase using PT/0/A/l 103/020, Power Maneuvering Predictions, to ensure no problems will be encountered.

2. EFPD input into the code shall correspond to the beginning of the power history, NOT the EFPD at the effective time of calculation.

2.4 Input appropriate data for the estimated critical boron calculation, select Calculate ECB, and print.

NOTE: Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation, does NOT have to be used to calculate the ECP in step 2.5.

2.5 Run Rhocalc to calculate an ECP using the boron concentration found in the ECB above.

NOTE: When choosing the input Boron concentration for the ECP during transient Xenon conditions sufficient time must be factored in to allow for changes to be made to the RCS and PZR Boron concentration, samples to be taken, the time required to pull Groups 1 4 -

to 100% wd, and any other time constraints noted by the 0CC.

2.6 Ensure that all Safety rod groups can be fully withdrawn one hour prior to the time that 5 <0% shows in the Rod Posn MODE 2 Entry column of the ECP printout for the anticipated time of criticality.

2.7 Verify Separate Verifications agree on the ECB within 10 ppmB for all future time steps.

2.8 Discuss the results of ECB with the Control Room SRO. (N/A this step on separate verification calculation).

Room SRO 2.9 Attach results of ECB to the procedure and turn the package over to the Control Room SRO. (N/A this step on separate verification calculation).

NOTE: The Reactor Engineering mail code is ONO3CV.

2.10 WHEN the ECB is no longer required, return this procedure, including all applicable enclosures and attachments, to Reactor Engineering. (N/A this step on the separate verification calculation.)

Enclosure 13.6 PT/1/A/11o3/o15 Computerized Subcritical Multiplication (l/M)

Page 1 of 4 Measurement

1. Purpose s by spreadsheet during unit start The purpose of this enclosure is to perform 1/M measurement Power Physics Procedure, controls up other than the initial cycle startup. PT/0/A/071 1/00 1, Zero the initial cycle startup.

2. Procedure Engineer. The Double NOTE:

• This procedure is performed by a Qualified Reactor Operator.

Verification performed in step 2.7.6 shall be by a Licensed ced at this time.

• Step 2.4 may be performed at any time and should be referen

_____ Time:_______________

Calculation Performed By:________________ Date:______

ing premature CAUTION: The l/M plot should only be used as an operator aid for predict rod position or as a criticality and should NOT be relied upon for predicting critical substitution for Control Room indications.

ns:

NOTE: A control copy of 1M.xls is located in the following locatio sheet\l_M.XLS

• \\ONSFSOO\SYSCODES\Computer Support\l _M Spread

• Reactor Engineering Fireproof Cabinet

• SDQA 10135-ONS 2.1 Open spreadsheet i_M.xls.

cells are yellow).

2.2 Perform the following Steps on the NI-i TAB (user input 2.2.1 Enter appropriate Unit number 2.2.2 Enter appropriate Cycle number 2.2.3 Enter NO in the Begin of Cycle? field.

2.2.4 Enter current cycle EFPD into the EFPD field.

this procedure at the users NOTE: Notify Lines can be selected or deselected at any time during discretion.

2.2.5 IF desired, enter YES for Graph Notify Lines? field.

Enclosure 13.6 PT/1/A/11o3/o15 Computerized Subcritical Multiplication (1/M) Page 2 of 4 Measurement NOTE: 1. Xenon free is defined as < 0.i%KIK of Xenon present in the core. This number can be obtained from the OAC, Rho Caic, etc.

2. The review criteria for a Xenon free startup is +/- 0.35%t\KJK. The review criteria for a startup with xenon is +/- 0.5%z\KIK.

2.2.6 Select whether startup will be Xenon free (YES) or (NO).

2.2.7 Enter the RhoCaic produced Rod Group and Rod Position at the time of desired criticality, from the ECP generated in Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation.

2.2.8 Enter the time Safety Groups must be fully withdrawn from the ECP generated in Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation.

NOTE: 1. Regardless of NI-i operability, the date and times at rod position hold points must be recorded on TAB NI-i.

2. All operable NIs should be used when performing this enclosure.

2.3 Determine the operable NIs with Operations.

2.4 Perform one of the following:

2.4.1 IF Step 2.6 of Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation was answered Yes, verify current conditions match those assumed in the ECP within +/- 5 ppmB and +/- 10 RCS Temperature.

OR 2.4.2 Perform Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation again using the current conditions as inputs.

2.5 In the appropriate tabs of the spreadsheet, record initial count rates Ci, C2 and C3 with CR Group 1 at 50 +/- 2%wd, CR Group 8 at 35+/- 5%wd.

NOTE: TS SR 3.2.1.3 requires verification of SDM within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> prior to achieving criticality.

2.6 Prior to withdrawing Group 1 from 50 to 100% withdrawn, verify SDM at the current RCS conditions.

Enclosure 13.6 PT/i/A/i 103/015 Computerized Subcritical Multiplication (1IM) Page 3 of 4 Measurement NOTE: 1. The same NI(s) selected for Co must be used consistently for the entire withdrawal sequence 1/M measurement.

2. After each pull, wait until count rate stabilizes before taking next set of counts. For example, it may only be necessary to wait thirty seconds after each pull on the safety groups. As the reactor gets closer to criticality, it may be necessary to wait several minutes after each pull before count rate stabilizes.

3. NOT all hold points may be used. The hold points in step 2.7.6 that are NOT used may be N/Aed.

4. By signing off hold points in step 2.7.6 the procedure user is documenting that steps 2.7.1 2.7.5 have been completed for each hold point or have been evaluated and determined not to be required for that hold point.

2.7 Have Ops withdraw CR Groups to their upper limits, stopping with each applicable group at the positions listed below. At each position; (R.M.)

2.7.1 ji required, update the TRhocalc generated ECP portion of the 1/M.XLS spreadsheet. This assures that the correct predicted conditions are used in the 1/M.xls spreadsheet.

2.7.2 Wait approximately one minute, and then enter NI count rates into the appropriate tab of the spreadsheet.

NOTE: The evaluation as required in 2.7.3 may include further rod withdrawal to add positive reactivity equal to or less than one-half of the amounts remaining to provide the predicted criticality.

2.7.3 IF the Extrapolated Estimated Critical Rod Position indicates critical conditions prior to the lower limit of criticality lower notify limit of criticality, STOP further rod withdrawals and evaluate. (R.M.)

NOTE: Criticality must be achieved within 0.75% AKJK of the ECP per Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation).

2.7.4 When any 1/M data point is plotted greater than the lower limit of criticality, the 1 /M measurement may be stopped.

2.7.5 IF criticality cannot be achieved within 0.75% tXKJK of the ECP, notify the Operations Shift Manager, insert control rods to Group 1 at 50%w/d, request an immediate RCS Boron sample, AND notify Reactor Engineering. (R.M.)

Enclosure 13.6 PT/i/A/i 103/0 15 Computerized Subcritical Multiplication (1IM) Page 4 of 4 Measurement 2.7.6 Calculate 1/M.

Additional data points may be taken if desired.

CR Groups Rod Positions (within +/- 2%wd) 1 50 (Co) wd OPS QRE 1 100%wd OPS QRE 2 100%wd OPS QRE 3 100%wd OPS QRE 4 100%wd OPS QRE 5 50%wd OPS QRE 5 75%wd 0P5 QRE 6 25%wd OPS QRE 6 50%wd OPS QRE 6 75%wd OPS QRE 7 25%wd OPS QRE 7 50%wd OPS QRE 7 75%wd OPS QRE 7 100%wd OPS QRE 2.8 Ensure actual critical conditions are recorded on the ECP printout.

2.9 Print and attach the 1/M spreadsheet.

Core Excess Reactivity (%cielta-klk)

C-fl (0 0 - C-.)

0 I

0 0,

0 0

0 0

00 a,

0 0

0 C-.)

0 0

o F.)

-, 0 CD 0 .

.. c m

a,

.T 0

C-.) -

0 0

C.) Ui C.)

CD 0

C) a, -2 0 a, C.)

a, C-.)

o 0 C

a. 0 CD 0 GD a,

- CD Z

0 0

-1 0) 0 C-)

C-fl a,

0 a.

C))

0 0

C-fl a) -.1 a, CD F.) C-.) C))

Enclosure 13.8 PT/i/A/l 103/015 Differential Boron Worth vs. Burnup Page 1 of 2 01C26

-0.013 60F fl N I] El]

nterpoia e to Actua Temperature I

-0.012 300F E

0.

C.r .i 400F G) -

0 50F

-C 0

C 0

32F a) 60F

-0.009

-0.008

-0.007 -

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 Core Burnup (EFPD)

Enclosure 13.8 PT/i/A/l 103/015 Differential Boron Worth vs. Burnup Page 2 of 2 01C26 values are used to generate the graph NOTE: The data in the Table below is taken from the Unit 1 Cycle 26 PTM, table 30. These on page 1 of2.

TEMPERATURE 400 450 532 560 EFPD 60 300

-0.00881 -0.00848 -0.00776 -0.00748 0 -0.01027 -0.00938

-0.00898 -0.00863 -0.00792 -0.00762 100 -0.01055 -0.00957

-0.00975 -0.00937 -0.00859 -0.00828 300 -0.01153 -0.01040

-0.01053 -0.01006 -0.00923 -0.00891 435 -0.01245 -0.01124

-0.01090 -0.01041 -0.00962 -0.00928 500 -0.01301 -0.01172

Enclosure 13.9 PT/1/A/1103/015 Temperature Coefficient vs. RCS Boron Concentration Page 1 of 1 532 F HZP Grp 7 @ 0% wd 01C26 0.000 0

-0.001 -0.001

-0.002 -0.002

-0.003 -0.003

-0.004 -0.004

-0.005 -0.005 c_

0 0 06 -0.006 a) a)

-0.007 -0.007 S

? -0.008 -0.008

.g -o.ooo -0.009

-0.010 -0.01

-0.011

-0.012 -0.012 C)

-0.013 -0.013 5 -0.014 -0.014 JM.015 -0.015

-0.016 -0.016

-0.017 -0.017

-0.018 -0.018

-0.019 -0.019

-0.020 -0.02

-0.021 -0.021

-0.022 -0.022 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 RCS Boron Concentration (ppmb)

Enclosure 13.10 PT/i/All 103/015 Shutdown Boron Concentration vs. Burnup (Group 1 @ 0% wd) Page 1 of 2 Groups 1-7 @ 0% wd Grp 8 @35 wd (NOT wd after 435 EFPD) 01C26 1500 1400 1300 Assumes Worst Stuck Rod 0 1200 1100 1000 E

a a 900 C

0 800 C

0 700 0

C) 600 0

60F 500 t at tAt T t 300F 400 400 F 300 450 F 200 100 532F 0 560F 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 Core Burnup (EFPD)

Enclosure 13.10 PT/1/A11103/015 Shutdown Boron Concentration vs. Burnup (Group 1 @ 0% wd) Page 2 of 2 Groups 1-7 @ 0% wd Grp 8 @35% wd (NOT @3% wd after 435 EFPD) 01C26 NOTE: The data in the Table below is taken from the Unit 1 Cycle 26 PTM, table 5. These values are used to generate the graph on page 1 of 2.

TEMPERATURE EFPD 60 300 400 450 532 560 Gp8at35 0 1502 1468 1428 1395 1303 1251 Gp8at35 100 1358 1315 1265 1224 1106 1045 Gp8at35 300 985 913 834 774 611 528 Gp8at35 435 685 590 494 424 233 137 Gp 8 NOT at 35 435 690 601 509 442 260 167 Gp 8 NOT at 35 490 566 468 370 298 105 9 Gp 8 NOT at 35 500 544 445 346 273 79 -19

Enclosure 13.11 PT/1/A!1103/015 Shutdown Boron Concentration vs. Burnup (Group 1 @ 50% wd) Page 1 of 2 Grps 2-7 @ 0% wd Grp 8 @35% wd (NOT @35% wd after 435 EFPD)

O1C26 1600 1500 1400 1300 N Ass esWorstst kR dOu 1200 1100 E 1000 a.

a.

c 900 0

m 800 0

U 700 600 t tA Te 60F 500 300 F 400 400 F 300 450 F 200 532 F 100 560 F 0

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 480 460 500 Core Burnup (EFPD)

Enclosure 13.11 PT/l/A11103/015 Shutdown Boron Concentration vs. Burnup (Group 1 Page 2 of 2

@ 50% wd)

Grps 2-7 @ 0% wd Grp 8 @5% wd (NOT wd after 435 EFPD) 01C26 NOTE: The data in the Table below is taken from the Unit I Cycle 26 PTM, table 7. These values are used to generate the graph on page 1 of2.

TEMPERATURE EFPD 60 300 400 450 532 560 Gp8at35 0 1563 1552 1531 1511 1447 1409 Gp8at35 100 1410 1396 1366 1339 1249 1202 Gp8at35 300 1010 969 913 868 734 666 Gp8at35 435 693 627 551 496 333 251 Gp 8 NOT at 35 435 695 627 551 496 333 251 Gp 8 NOT at 35 490 569 483 402 340 172 87 Gp 8 NOT at 35 500 547 459 375 312 143 57

Enclosure 13.12 PT/1/A/11o3/o15 Inoperable Rod Penalty for Individual Page 1 of 1 Inoperable Rod 01C26 Rod Rod Eighth Core Penalty Group No. Location (% MKJK) 1 1,2,3,4,5,6,7,8 K-il 0.35 2 1,2,3,4,5,6,7,8 M-13 1.72 3 2,4,6,8 K-09 0.05 3 1,3,5,7 H-10 0.05 4 1 H-08 0.01 4 2,3,4,5,6,7,8,9 L-14 0.70 5 2,5,8,11 M-ii 1.21 5 1,3,4,6,7,9,10,12 K-13 0.81 6 2,4,6,8 L-10 0.32 6 1,3,5,7 H-14 0.25 7 2,4,6,8 N-12 1.72 7 1,3,5,7 H-12 0.50

EncJosure 13.13 PT/1/A/1103/015 Refueling Outage Boron Concentrations Page 1 of 1 01C26 NOTE: This boron concentration will provide a shutdown margin of greater than 1% zKJK with the most reactive bank withdrawn and the worst case stuck rod out with cycle burnup at 0 EFPD. RCS temperature is between 60°F 532°F. All other banks are assumed to be fully inserted. It is also conservative for performing CRDTTT at 0 EFPD.

CRD Patch Verification and CR1) Trip Time Testing:

> 1698 ppniB if Group 8 is 30-40% wd

> 1748 ppmB if Group 8 is NOT 30-40% wd (between 60°F 532°F)

ZPPT All-Rods-Out Boron Concentration 1771 ppmB (at 532 °F)

NOTE: This boron concentration will provide a shutdown margin of greater than 1% zMKIK with all control rods withdrawn and no credit taken for Xenon for temperatures 33°F or greater.

Refueling Boron Concentration:

> 2220 ppmB (33°F or above)

Enclosure 13.14 PT/i/A/11o3/o15 Required Group 8 Position and Designed Page 1 of 1 Cycle Length 01C26 REQUIRED GROUP 8 POSITION:

CAUTION: 1. For reactor shutdown, use Group 8 position listed below unless otherwise directed by OP/i/All 102/010.

2. IF a reactor trip occurs during Group 8 withdrawal to 100%, Group 8 will be repositioned to 30 40 %wd.

3. The term APSR pull utilized below is defined as the planned course of action to pull group 8 from 30 40% to 100% withdrawn beginning at:

435 EFPD Prior to APSR pull During APSR pull After APSR pull Required Group 8 Required Group 8 Required Group8 Condition Position (% wd) Position (% wd) Position (%wd)*

Approach to Criticality 30 40

- 30 40

- 100 Steady State Operation 30 -40 35 - 100 100 Reactor Shutdown 30-40 30-40 100 Group 8 may be inserted to 35% wd for increased shutdown margin.

DESIGNED CYCLE LENGTH:

The Oconee Unit 1 Cycle 26 designed cycle length is 480 500 EFPD.

Enclosure 13.15 PT/i/All 103/0 15 Power Defect vs. Reactor Power Page 1 of 1 Group 8 @35% wd (NOT @3% wd after 435 EFPD)

HFP EQXE EQSM O1C26

-3

-2.5

-2 U

-1.5 U

U 0

0.

1

-0.5 0

0 10 20 30 40 50 60 70 80 90 100 Power Level (%FP)

Enclosure 13.16 PT/1/A/1103/o15 Shutdown Margin Requirements Page 1 of 1 01C26 The Shutdown Margin (SDM) shall be greater than 1% k!k. (Ref. TS 3.1.1 and COLR)

Enclosure 13.17 PT/1/A/1103/015 Control Rod Group Worths for Control Rod Page 1 of 1 Drop Time Testing 01C26 NOTE: Interpolate for intermediate temperatures.

Control Rod Group Worths for BOC CRDTTT, HZP, No Overlap Group8 @35% wd, NOXE CRGP 1 performed with CRGP2-7 in, CRGP2 performed with CRGP1,3-7 in, etc.

Rod Group 300F 532F 1 1.188 1.557 2 1.985 2.192 3 - 1.104 1.812 4 0.709 0.852 5 2.238 2.629 6 0.642 0.905 7 1.824 2.042 1-4 4.594 5-7 4.873 NOTE: These rod group worths are for worst-case Xenon conditions for each group.

Groups 1-7 Control Rod Group Worths For Trip Time Tests After BOC HZP, No Overlap, 525-557°F Group8@35%wd CRGP 1 performed with CRGP2-7 in, CRGP2 performed with CRGP1, 3-7 in, etc.

Rod 4 250 500 Group EFPD EFPD EFPD 1 1.638 1.755 1.839 2 2.288 2.310 2.490 3 2.034 2.152 2.263 4 0.983 1.069 1.273 5 2.725 2.802 2.955 6 0.980 1.044 1.112 7 2.119 2.090 2.226

Enclosure 13.18 PT/1/A/11o3/o15 Shutdown Margin Calculation at Power Page 1 of 1

1. Purpose 1.1 The purpose of this enclosure is to perform a shutdown margin calculation while at power.

2. Procedure Performed By:

NOTE: Step 2.1 applies only to control rod groups 1 through 6. Group 7 and the APSRs may be positioned as required.

2.1 IF any groups are NOT at 100% withdrawn (other than Group 7 and the APSRs) due to CRD movement PT:

2.1.1 Verify that only one group is NOT at 100% withdrawn.

2.1.2 Verify that the inserted group is? 95% withdrawn.

NOTE: For a dropped rod/stuck rod scenario, utilize 1 inoperable rod graphs in the COLR. The rod position used should be the position of the controlling group (if the dropped/stuck rod is in the controlling group, the rod positions of remaining rods in that group should be used, not the group average.)

2.2 Verify of the following:

2.2.1 Available shutdown margin is 1% AK/K. This is shown by verifying that the 5V control rod position and power level are within the Acceptable Region or the Restricted Region on the appropriate curve for the number of RC Pumps and Inoperable rods in the COLR.

OR 2.2.2 Appropriate actions are taken per TS 3.1.4, 3.1.5, and 3.2.1 sv

Enclosure 13.19 PT/i/All 103/0 15 Group 7 Control Rod Worth Page 1 of 1 HZP, NOXE and PKXE Group 8 @ Nominal Position 01C26 0

ir 0.2

HH:::

..i ...

...j Note:This graph is provided forinformatiori, it j isnotusedinanycalculationsinthis t-i 2 procedure i / 7 0.4 L -

0.6  ::::

--4EFPD NOXE 0.8 4EFPD PKXE 0

0 4

1 *25OEFPD NOXE 4250EFPD PKXE

:: :: :Z  : :1.  :  :: -5O0EFPD NOXE 500EFPD PKXE 1.2 1.4 1.6 1.8

t Li 0 10 20 30 40 50 60 70 80 90 100 Group 7 Control Rod Position (%wd)

Enclosure 13.20 PT/i/A/i 103/0 15 Page 1 of2 Minimum RCS Boron Concentration to Maintain SSF Operability 01C26 1400 APSR Pull 1300 250 1200 = = = = = 200 150 1100 oXenon I 1000

. 100 3

T 5

. 50

.2 900 0

800 - 450 470 490

- - 410 430 C

0 :1: :I:I -: * *

• C) 700 - -h.

C 0

S 11 -

600 500 -

XenonWorth -

E - -----

o/frJJ - - - - -

C = z c z z =

400 s:  ::IISI:I:::EE:

300 = =

- - - - - - - - .ç ç -

200 == 25%deIta-k/kJE

- --%-c- -

100 0 480 510 270 300 330 360 390 420 450 30 60 90 120 150 180 210 240 0

Burnup (EFPD)

Enclosure 13.20 PT/i/All 103/0 15 Minimum RCS Boron Concentration to Maintain SSF Operability Page 2 of 2 01C26 2% curve NOTE: 1. IF xenon is <2.0%, the No Xenon curve applies. jj xenon is between 2.0% AND 2.5%, the Xenon applies. IF xenon is > 2.5%, the Xenon =2.5% curve applies.

limiting curves, then

2. IF the minimum required boron concentration to maintain SSF operability cannot be met using the interpolation on EFPD and xenon is permitted.

3. Unless otherwise indicated, the boron values below assume Group 8 is at 35% withdrawn.

No Xenon & 525 F Xenon =2.0% Xenon =2.5%

EFPD Mm Boron Required for SSF Mm Boron Required for SSF Mm Boron Required for SSF 1266 1059 1030 0

1258 1050 1021 4

1242 1032 1002 12 1217 1003 972 25 1168 948 914 50 1071 842 802 100 948 715 668 150 825 596 541 200 703 478 421 250 580 359 304 300 441 226 172 350 302 93 40 400 204 -1 -52 435 31 -166 -215 500 435 231 with Group 8 NOT = 35% 25 with Group 8 NOT = 35% -26 with Group 8 NOT = 35%

500 51 with Group 8 NOT = 35% -146 with Group 8 NOT = 35% -196 with Group 8 NOT 35%

Enclosure 13.21 PT/i/A/i 103/015 Minimum RCS Boron Concentration to Maintain SSF Operability with SSF Page i of2 RCMU Letdown Flow Degraded 50% & SSF RCMU Bypass Open 01C26 1400 I I I APSR Pull 1300 80 c c I Xe = 2%

70 jGrBNOT at 35%

1200 50 1100  %

5 S

t a

8 Jr H 1i 40 1000 3D Xe=2.5%

20 Gr8NOTat 35%

=

10 j Xe = 2.5%

V Gr8at35%

0 800 410 420 430 440 460 450

= -

0

° 700 0 - --

0

==ZS=ZZZ=ZZZ=ZZ=:

500

cEXenonwoithz: :

1=2% dlt- ku 400

300  %

r Xenon Worth

=2.5% delta-k/k = = :zzz=z 200

E::Z:E:EE_

100 _._-___...c_

S4_

zzzz:zzZZZZIS 0

0 50 100 150 200 250 300 350 400 450 500 Bumup (EFPD)

Enclosure 13.21 PT/1/A/1103/015 Minimum RCS Boron Concentration to Maintain SSF Operability with SSF ag e 2 0 f2 RCMU Letdown Flow Degraded 50% & SSF RCMU Bypass Open 01C26 NOTE: 1. IF xenon is <2.0%, the No Xenon curve applies. IF xenon is between 2.0% AND 2.5%, the Xenon Worth = 2% delta KIK curve applies. IF xenon is > 2.5%, the Xenon Worth 2.5% delta-KJK curve applies.

2. IF the minimum required boron concentration to maintain SSF operability cannot be met using the limiting curves, then interpolation on EFPD and xenon is permitted.

3. Unless otherwise indicated, the boron values below assume Group 8 is at 35% withdrawn.

No Xenon & 525 F Xenon = 2.0% Xenon = 2.5%

EFPD Mm Boron Required for SSF Mm Boron Required for SSF Mm Boron Required for SSF 0 1266 1187 1186 4 1258 1178 1176 12 1242 1159 1156 25 1217 1131 1127 50 1168 1075 1070 100 1071 966 958 150 948 829 820 200 825 695 683 250 703 563 549 300 580 432 416 350 441 285 267 400 302 140 119 435 204 38 16 500 31 -140 -164 435 231 with Group 8 NOT = 35% 66 with Group 8 NOT = 35% 45 with Group 8 NOT = 35%

500 51 with Group 8 NOT = 35% -119 with Group 8 NOT = 35% -143 with Group 8 NOT 35%

Admin-112 FS Page 1 of 8 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE ADMIN-1 12 Calculate Requirements to Makeup to the BWST CANDIDATE EXAMINER

Admin-112 FS Page2of8 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE Task:

Calculate requirements to makeup to the BWST Alternate Path:

No Facility JPM #:

Bank KIA Rating(s):

System: GEN K/A: 2.1.25 Rating: 3.9/4.2 Task Standard:

Calculate volume of CBAST and DW needed to yield the proper volume at the correct Boron concentration to makeup to the BWST.

Preferred Evaluation Location:

Preferred Evaluation Method:

Simulator In-Plant Classroom X Perform X Simulate

References:

EOP Enclosure 5.4, Makeup to the BWST OP/O/N1108/OO1, Curves and General Information COLR Validation Time: 13 minutes Time Critical: NO Candidate:

Time Start:

NAME Time Finish:

Performance Rating: SAT UNSAT Performance Time:

Examiner:

NAME I SIGNATURE DATE COMMENTS

Admin-112 FS Page3of8 SIMULATOR OPERATOR INSTRUCTIONS NONE

Admin-112 ES Page4of8 ToolslEguipmentlProcedures Needed:

• EOP Enclosure 5.4, Makeup to the BWST (entire enclosure provided to student)

• OP/01A111081001, Curves and General Information (Available in procedures cart)

• Calculator

• Straight edge/ruler

• Note tablet READ TO OPERATOR DIRECTION TO TRAINEE I will explain the initial conditions, and state the task to be perfo rmed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when direc ted by you. Ensure you indicate to me when you understand your assigned task. To indicat e that you have completed your assigned task return the handout sheet I provid ed you.

INITIAL CONDITIONS

• QAC is not available

• Unit 1 shutdown and cool down in progress due to a tube ruptu re in the 1A SG

• SGTR Tab in progress at Step 118

• Unit 1 BWST level = 38 feet

• Unit 1 BWST Boron concentration = 2500 ppm

• 1A BHUT level = 40 inches

• IA BHUT Boron Concentration = 240 ppm

• CBAST Boron Concentration = 12,501 ppm INITIATING CUES The CR SRO instructs you to initiate EOP Enclosure 5.4 (Make up to the BWST) to determine the required volumes of CBAST and DW to begin makeup to the BWST from 1A BHUT.

You are to calculate the required volumes of CBAST and DW to fill 1A BHUT to 180 inches and match the current BWST Boron concentration.

Admin-112 FS Page 5of8 START TIME:

STEP 1: Step 1 CRITICAL STEP Determine current volume in IA BHUT using any of the following:

• QAC graphic CSO1 SAT

• BHUT Volume vs. Level Curve (End. 4.1) in OP/OI A/11081001 (Curves and General Information)

STANDARD: UNSAT Refer to Enclosure 4.1 BHUT Volume vs. Level Curve in OP/0/AJ1 108/001 (Curves and General Information) and determine that the volume of water in the 1A BHUT:

40 14,000 gallons (13,500 to 14,000 gal) 180 81,000 gallons (80,750 to 81,250 gal)

COMMENTS:

STEP 2: Step 2 CRITICAL STEP Determine volume of CBAST required per the follow ing to yield a volume in 1A BHUT of 81,000 gals at 2,500 ppm:

SAT (BHUTvfX BHUTci)

( BHUTvI X 1 CBAST, BHUT

) = # gallons of CBAST needed UNSAT (80,750 x 2,500) - (13,500 x 240) = 15,889 gal of CBAST needed 12,501 (81,250 x2,500) -(14,000 x 240) = 15,980 gal of CBAST needed 12,501 STANDARD: Candidate calculates the required volumes from CBAST between:

15,889 and 15,980 gallons.

BHUTvf= Final BHUT volume (gal) 80,750 to 81,2 50 gals 1

BHU Tv = Initial BHUT volume (gal) 13,500 to 14,000 gals BHUTcf= Final BHUT conc (ppmb) 2,500 ppmb BHUTc = Initial BHUT conc (ppmb) 240 ppmb CBASTc CBAST conc (ppmb) 12,501 ppmb Note: Instructions are to fill IA BHUT to 180 which corre lates to 81,000 gal.

COMMENTS:

Admin-112 FS Page 6 of 8 STEP 3: CRITICAL STEP Step 3 Determine volume of DW required per the following to yield SAT a volume in 1A BHUT of 80,750 to 81,250 gals at 2500 ppm:

UNSAT BHUTvf BHUTvI # gallons CBAST needed

1. gallons of DW needed 81,250 13,500 15,889 = 51,861 gallons of OW needed 80,75014,000 15,980 = 50,770 gallons of DW needed STANDARD: Candidate calculates the required volumes from DW betwee n:

50,770 arid 51,861 gallons COMMENTS END OF TASK STOP TIME:

Admin-112 ES Page7of8 CRITICAL STEP EXPLANATIONS STEP # Explanation 1 Required for determining the correct water volumes.

2 These calculations are required for determining the correct water volumes.

3 These calculations are required for determining the correct water volumes.

CANDIDATE CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETIO N OF TASK)

INITIAL CONDITIONS

• OAC is not available

• Unit 1 shutdown and cool down in progress due to a tube ruptu re in the IA SG

• SGTR Tab in progress at Step 118

• Unit 1 BWST level = 38 feet

• Unit 1 BWST Boron concentration = 2500 ppm

• IA BHUT level = 40 inches

• IA BHUT Boron Concentration = 240 ppm

• CBAST Boron Concentration = 12,501 ppm INITIATING CUES The CR SRO instructs you to initiate EOP Enclosure 5.4 (Makeup to the BWST) to determine the required volumes of CBAST and DW to begin mak eup to the BWST from IA BHUT.

You are to calculate the required volumes of CBAST and DW to fill IA BHUT to 180 inches and match the current BWST Boron concentration.

Enclosure 4.1 oP/O/AJi 108/00 1 BHUT Volume Vs. Level Curve Page I of 1 Level (inches) 0 10 20 30 40 50 60 70 80 90 100 90000 110 120 130 140 150 160 170 180 190 200 lIllllll II 90000 I I I I I I I I II I I I I I I I I I I I I I I I I I I I I I I I I I I I 80000 I I I I I I

I I I II I I li ii 80000 I I I I I I I I I I I I I I I I 70000 I I

• * * * * *II* * * * * * * *** * ** I 70000 I I I I

. . . . . . . . . I[ I I I I I I I I I I I I I I I I I I I I I I 60000 I I II I I I 60000 I I I I I I I I I I

0 I 11111 II I iI.............

0 I 0 50000 NOTE: Bleed Transfer Pump trips at 15 I CU 50000

0) I indicated level (29 actual level). {I0} I -

I 0)

E 40000 0 40000 30000 z: 30000 20000 20000 10000 10000 0

0 10 20 0 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 Level (inches)

File: BHUT.jnb OSC-7129

Enclosure 5.4 EPI1/Al1 800/001 Makeup to the BWST {25} Page 1 of 37 L ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

1. Determine current volume in 1 A BHUT using gy of the following:

OAC graphic CSO1 BHUT Volume vs Level Curve in OP/0/AI1 108/00 1 (Curves and General Information).

2. Determine volume of CBAST and DW required per the following to yield a volume in 1 A BHUT of 80,000 to 82,000 gals at a concentration that complies with COLR requirements for the BWST:

Where:

BHUTf = Final BHUT volume (gal)

BHUT = Initial BHUT volume (gal) 1 BHUTf = Final BHUT conc (ppmb)

BHUT = Initial BHUT conc (ppmb) 1 CBAST = CBAST conc (ppmb)

(BHUTVf x BHUTCf) - 1 (BH uT x BHUT)

= # gallons of CBAST needed CBAST

(____

)

1. gallons of CBAST needed BHUTvf BHUTvi # gallons CBAST needed

1. gallons of DW needed

1. gallons of DW needed

3. Verify boron addition to 1A BHUT GO TO Step 46.

required.

Enclosure 5.4 EP,/1/A!l800/ool Makeup to the BWST {25} Page 3 of 37

[ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

4. Verify quantity of boron needed for GO TO Step 6.

transfer to 1A BHUT is available in the CBAST without going below minimum SLC required for CBAST.

5. GO TO Step 31.

6. 1&2BAMTis<62. GOTO Step9.

7. Locally perform the following:

A. Fill BAMT not to exceed 62 via DW-1 18 (BAMT Fill Isol Vlv)

(A-i, 1&2 BAMT Rm).

B. Start Unit 1&2 BAMT AGITATOR (A-2, 1&2 Chem Add Panel).

C. Place Unit 1&2 BAMT HEATER switch in AUTO (A-2, 1&2 Chem Add Panel).

D. WHEN Unit 1&2 BAMT temperature is 127°F, THEN notify Primary Chemistry to add chemicals.

8. WHEN ready to transfer Unit 1 &2 BAMT to CBAST, THEN continue in this enclosure.

9. Open ICS-62.

10. Locally perform the following (A-i, l&2 BAMT Rm):

A. Close CA-38 (Unit 1/2 HP Boric Acid Pump Suction Tell Tale).

B. Open the following:

CA-4 (Unit 1/2 BAMT Outlet)

CA-20 (Boric Acid Hdr To CBAST)

11. Verify B LP Boric Acid Pump will be 1. Locally start A LP Boric Acid Pump used for transfer of BAMT to CBAST. (A-2, 1&2 Chem Add Panel).

2._ GOTOStep14.

Enclosure 5.4 EP/1/A11800/OOi Makeup to the BWST {25} Page 5 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

12. Locally open CA-li (AIB LP BAMT Pumps Disch Tie) (A-i, l&2 BAMT R).

13. Locally start B LP Boric Acid Pump (A-2, 1 &2 Chem Add Panel).

14. cycle DW-1 19 (Boric Acid Mix Pumps Suction Hdr Flush) (A-i, l&2 BAMT Rm).

15. Inform Units 1 and 2 to monitor for reactivity effects due to possible leakage of l&2 BAMT into LDST.

16. Locally perform the following (A-2, 1&2 Chem Add Panel):

A. Place Unit 1&2 BAMT HEATER switch in OFF.

B. Stop Unit 1&2 BAMT AGITATOR.

17. WHEN transfer is complete, THEN locally stop the selected LP Boric Acid Pump (A-2, 1 &2 Chem Add Panel).

18. Locally perform the following (A-I, 1 &2 BAMT Rm):

A. Close CA-4 (Unit 1/2 BAMT Outlet).

B. Open DW-1 19 (Boric Acid Mix Pumps Suction Hdr Flush).

19. Locally start previously running LP Boric Acid Pump (A-2, 1&2 Chem Add Panel).

20. WHEN LP Boric Acid Pump has run for 5 minutes, THEN locally stop LP Boric Acid Pump (A-2, 1&2 Chem Add Panel).

Enclosure 5.4 EP/1/AJl800/ooi Makeup to the BWST {25} Page 7 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

21. Locally close the following (A-i, i&2 BAMT Rm):

CA-20 (Boric Acid Hdr To CBAST)

DW- 119 (Boric Acid Mix Pumps Suction Hdr Flush)

22. Close 1CS-62.

23. Verify B LP Boric Acid Pump was used GO TO Step 25.

for transfer of BAMT to CBAST.

24. Locally close CA-il (AJB LP BAMT Pumps Disch Tie)

(A-i, 1&2 BAMT Rm).

25. Locally open CA-38 (Unit 1/2 HP Boric Acid Pump Suction Tell Tale) (A-i, 1 &2 BAMT Rm).

26. Verify quantity of boron needed for 1. Notify Primary Chemist of volume transfer to 1 A BHUT is available in the removed from Unit 1 &2 BAMT.

CBAST without going below minimum SLC required for CBAST. 2 GO TO Step 7

27. 1CS-64.

28. Start 1A CBAST PUMP.

29. Inform all units to monitor for reactivity effects due to possible leakage of CBAST into LDST.

30. Notify Primary Chemist of the following:

Volume removed from Unit 1 &2 BAMT To sample Unit 1 CBAST for boron

31. WHEN boron addition to 1A BHUT is desired, THEN close 1CS-46.

32. Place T/O Sheet tag on the following:

1CS-46 1HP-i6

33. Place the following notes on T/O sheet:

Do not open 1CS-46.

Do not open 1HP-i6.

Enclosure 5.4 EP/l/AIl800Iool Makeup to the BWST {25} Page 11 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

43. Locally perform the following (A-i, Unit 1 BTP Rm):

A. Close ICS-66 (CBAST Tie To Bld Xfer Pumps).

B. Close 1CS-150 (BId Xfer Pump 1A Suct Tie).

C._ Open 1CS-148 (1A BHUT Outlet Block).

44. Remove T/O Sheet tag from the following:

1CS-46 IHP-16

45. Remove the following notes from T/O sheet:

Do not open 1CS-46.

Do not open IHP-16.

46. addition to 1A BHUT GO TO Step 58.

required.

47. Ensure space is available in Waste Gas Tanks.

48. open 1DW-174 (Bleed Holdup Tank Supply) (A-i, hallway S of freight elevator).

49. Locally throttle 1CT-87 (Condensate To BHUT 1A) as necessary to control flow and minimize vent header pressure (A-i, hallway).

Enclosure 5.4 EP/1/A11800/OO1 Makeup to the BWST {25} Page 13 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

50. Monitor the following for unexpected level changes:

. 1BBHUT

. Unit 1 CBAST

51. Notify Unit 2 to monitor the following for unexpected level changes:

. 2ABHUT

. 2B BHUT

. Unit 2 CBAST

52. IAAT unexpected level changes occur in GO TO Step 56.

Unit 1, OR Unit 2 BHUTs or CBASTs, THEN GO TO Step 53.

53. close 1DW-174 (Bleed Holdup Tank Supply)

(A-i, hallway S of freight elevator).

54. Determine and correct cause of unexpected level change.

55. GO TO Step 46.

56. WHEN DW addition to 1A BHUT is complete, THEN continue in this enclosure.

57. Locally close the following:

1DW-i74 (Bleed Holdup Tank Supply)

(A-i, hallway S of freight elevator) 1CT-87 (Condensate To BHUT iA)

(A-i, hallway)

58. Start 1A BLEED TRANSFER PUMP.

59. WHEN 1A BHUT has been on recirc for i/2 hour, THEN notify Primary Chemistry to obtain 1A BHUT boron sample.

60. WHEN iA BHUT sample results are available, THEN continue in this enclosure.

Enclosure 5.4 EP/1!AJi800!ool Makeup to the BWST {25} Page 11 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

43. Locally perform the following (A-i, Unit 1 BTP Rm):

A. Close ICS-66 (CBAST Tie To Bld Xfer Pumps).

B. Close 1CS-150 (Bid Xfer Pump 1A Suct Tie).

C. Open 1CS-148 (1A BHUT Outlet Block).

44. Remove T/O Sheet tag from the following:

1CS-46 1HP-16

45. Remove the following notes from T/O sheet:

Do not open 1CS-46.

Do not open 1HP-16.

46. Verify DW addition to 1A BHUT GO TO Step 58.

required.

47. Ensure space is available in Waste Gas Tanks.

48. Locally open 1DW-174 (Bleed Holdup Tank Supply) (A-i, hallway S of freight elevator).

49. Locally throttle 1CT-87 (Condensate To BHUT 1A) as necessary to control flow and minimize vent header pressure (A-i, hallway).

Enclosure 5.4 EP/1/A/l800/ooi Makeup to the BWST {25} Page 13 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

50. Monitor the following for unexpected level changes:

. 1BBHUT

• Unit 1 CBAST

51. Notify Unit 2 to monitor the following for unexpected level changes:

. 2ABHUT

. 2B BRUT

• Unit2CBAST

52. IAAT unexpected level changes occur in GO TO Step 56.

Unit 1, OR Unit 2 BHUTs or CBASTs, THEN GO TO Step 53.

53. close 1DW-174 (Bleed Holdup Tank Supply)

(A-i, hallway S of freight elevator).

54. Determine and correct cause of unexpected level change.

55. TO Step 46.

56. DW addition to 1A BHUT is complete, THEN continue in this enclosure.

57. Locally close the following:

1DW-174 (Bleed Holdup Tank Supply)

(A-i, hallway S of freight elevator) 1CT-87 (Condensate To BHUT 1A)

(A-i, hallway)

58. Start iA BLEED TRANSFER PUMP.

59. WHEN 1A BHUT has been on recirc for 1/2 hour, THEN notify Primary Chemistry to obtain 1 A BHUT boron sample.

60. WHEN iA BHUT sample results are available, THEN continue in this enclosure.

Enclosure 5.4 EP/1/A/1800/OO1 Makeup to the BWST {25} Page 15 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

61. 1A BHUT boron is within COLR GO TO Step 1.

limits for BWST boron requirements.

62. IAAT all the following conditions exist: GO TO Step 72.

lB BHUT NOT being transferred to BWST Makeup to BWST required THEN perform Steps 63 71. -

63. Close 1HP-16.

64. Perform the following:

A. T/O sheet tag on 1HP-16 control switch.

B. ?IDo not operate 1HP-16 on TIO sheet.

65. Notify RP to perform the following:

Perform surveys around BWST during transfer.

Adjust BWST radiological boundaries as necessary.

66. Ensure NONE of the following are in recirc:

Unit 1 BWST 2 BWST 1&2 SFP

67. Locally open the following:

1CS-96 (Spent Fuel IX (Rinse) Block)

(A-2, around corner from Caustic Add Pump)

LWD-156 (SF LX Sluice)

(Rm 218, SF CoolerRm)

68. Verify HPI Purification Tagout is hung. GO TO Step 70.

69. open 1CS-59 (Bleed Transfer Pumps Disch Tie) (A-i, RC Bleed Transfer Pump Rm).

Enclosure 5.4 EP/1/All800/ool Makeup to the BWST {25} Page 16 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

Enclosure 5.4 EP/1/A!1800/001 Makeup to the BWST {25} Page 17 of 37

[ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

70. 1CS-46.

71. Locally throttle SF-47 (SF Filter Outlet To Unit 1 BWST) based on the following (Rm 218, SF Cooler Rm):

. BWST < 46 maintain desired flow

. BWST 46 maintain flow

- < 50 gpm

72. IAAT makeup from 1A BHUT to GO TO Step 76.

BWST is in progress, AND py of the following conditions exist:

BWST makeup NO longer required 1ABHUT1eve1 15 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT THEN perform Steps 73 - 75.

73. Stop 1A BLEED TRANSFER PUMP.

74. Close 1CS-46.

75. Locally close the following:

1CS-96 (Spent Fuel IX (Rinse) Block)

(A-2, around corner from Caustic Add Pump)

LWD-156 (SF IX Sluice)

(Rm 218, SF CoolerRm)

SF-47 (SF Filter Outlet To Unit 1 BWST) (Rm 218, SF Cooler Rm)

NOTE At this point, repeated batches from 1A BHUT can be used to makeup to the BWST or lB BHUT can be borated and alternate batches from both BHUTs can be used for makeup.

76. Verify use of lB BHUT for makeup to GO TO Step 81.

BWST is NOT desired.

Enclosure 5.4 EP/1/A/l800/ool Makeup to the BWST {25} Page 18 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

(72) makeup from 1A BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

Enclosure 5.4 EP!1/A/l800/ool Makeup to the BWST {25} Page 19 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE Preparations for mixing another batch in 1A BHUT can be made while 1A BHUT is being transferred to the BWST. If another batch will be necessary, returning to Step 1 will direct actions to mix a boron batch in the BAMT for transfer to CBAST if the CBAST does NOT contain sufficient volume for boron addition to 1A BHUT. This should minimize the time between batches from 1A BHUT to the BWST.

77. IAAT preparations for mixing another batch in 1A BHUT is desired, THEN GO TO Step 1.

78. WHEN makeup operations to the BWST are complete, THEN notify RP of completion.

79. Perform the following:

A. Remove T/O sheet tag from 1 HP- 16 control switch.

B. _Remove Do not operate 1HP-16 from T/O sheet.

80. EXIT this enclosure.

• ..END...

Enclosure 5.4 EPI1/Ail800/ool Makeup to the BWST {25} Page 20 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

(72) makeup from 1A BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

Enclosure 5.4 EP/1/A11800/ool Makeup to the BWST {25} Page 21 of 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Unit Status Alternating batches from 1A and lB BHUTs to the BWST is desired.

81. Determine current volume in lB BHUT using py of the following:

OAC graphic CSOI BHUT Volume vs Level Curve in OP/0/A11 108/00 1 (Curves and General Infonnation).

82. Determine volume of CBAST and DW required per the following to yield a volume in lB BHUT of 80,000 to 82,000 gals at a concentration that complies with COLR requirements for the BWST:

Where:

BHUTf Final BHUT volume (gal) 1 BHUT = hiitial BHUT volume (gal)

BHUTf Final BHUT conc (ppmb) 1 BHUT Initial BHUT conc (ppmb)

CBAST = CBAST conc (ppmb)

(BHUTVf x BHUTCf) - (BHUT 1 x BHUT )

1

= # gallons of CBAST needed CBAST

(____ )

1. gallons of CBAST needed BHUTf - BHUT 1 - # gallons CBAST needed = # gallons of DW needed

1. gallons of DW needed

Enclosure 5.4 EP/1/All800/ool Makeup to the BWST {25} Page 22 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

(72) makeup from IA BHUT to BWST is in progress AND py of the following conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

Enclosure 5.4 EP/1/A1i800/00i Makeup to the BWST {25} Page 23 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

83. quantity of boron needed for GO TO Step 85.

transfer to lB BHUT is available in the CBAST without going below minimum SLC required for CBAST.

84. GO TO Step 110.

85. Unit 1&2 BAMT is < 62. GO TO Step 88.

86. Locally perform the following:

A. Fill BAMT not to exceed 62 via DW-1 18 (BAMT Fill Isol Vlv)

(A-i, 1&2 BAMT Rm).

B. Start Unit i&2 BAMT AGITATOR (A-2, 1&2 Chem Add Panel).

C. Place Unit 1 &2 BAMT HEATER switch in AUTO (A-2, 1 &2 Chem Add Panel).

D. WHEN Unit 1&2 BAMT temperature is 127°F, THEN notify Primary Chemistry to add chemicals.

87. WHEN ready to transfer Unit 1&2 BAMT to CBAST, THEN continue in this enclosure.

88. Locally perform the following (A-i, 1&2 BAMT Rm):

A. Close CA-38 (Unit 1/2 HP Boric Acid Pump Suction Tell Tale).

B. Open the following:

CA-4 (Unit 1/2 BAMT Outlet)

CA-20 (Boric Acid Hdr To CBAST)

89. 1CS-62.

90. Verify B LP Boric Acid Pump will be 1._ Locally start A LP Boric Acid Pump used for transfer of BAMT to CBAST. (A-2, i&2 Chem Add Panel).

2._ GOTO Step 93.

Enclosure 5.4 EP/1/AJl800/ool Makeup to the BWST (25} Page 24 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

(72) makeup from 1 A BHUT to BWST is in progress AND gpy of the following conditions exist:

• BWST makeup NO longer required

• 1 A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

Enclosure 5.4 EP/1/A11800/ool Makeup to the BWST {25} Page 25 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

91. Locally open CA-il (AJB LP BAMT Pumps Disch Tie) (A-i, l&2 BAMT Rni).

92. Locally start B LP Boric Acid Pump (A-2, 1&2 Chem Add Panel).

93. Locally cycle DW- 119 (Boric Acid Mix Pumps Suction Hdr Flush) (A-i, 1 &2 BAMT Rm).

94. Inform all units to monitor for reactivity effects due to possible leakage of 1 &2 BAMT into LDST.

95. Locally perform the following (A-2, 1&2 Chem Add Panel):

A. Place Unit 1 &2 BAMT HEATER switch in OFF.

B. Stop Unit l&2 BAMT AGITATOR.

96. WHEN transfer is complete, THEN locally stop the selected LP Boric Acid Pump (A-2, 1&2 Chem Add Panel).

97. Locally perform the following (A-I, l&2 BAMT Rm):

A. Close CA-4 (Unit 1/2 BAMT Outlet).

B. Open DW-1 19 (Boric Acid Mix Pumps Suction Hdr Flush).

98. Locally start previously running LP Boric Acid Pump (A-2, 1 &2 Chem Add Panel).

99. WHEN LP Boric Acid Pump has run for 5 minutes, THEN locally stop LP Boric Acid Pump (A-2, i&2 Chem Add Panel).

Enclosure 5.4 EP/1!AJ8OO!oO Makeup to the BWST {25} Page 26 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

(72) makeup from 1A BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHIJT...

(stop makeup)

Enclosure 5.4 EP/1./A11800/ooi Makeup to the BWST {25} Page 27 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 100. Locally close the following (A-i, 1 &2 BAMT Rm):

CA-20 (Boric Acid Hdr To CBAST)

DW- 119 (Boric Acid Mix Pumps Suction Hdr Flush) 101._Close 1CS-62.

102._ Verify B LP Boric Acid Pump was used GO TO Step 104.

for transfer of BAMT to CBAST.

103._Locally close CA-il (A/B LP BAMT Pumps Disch Tie) (A-i, 1&2 BAMT Rm).

104._ Locally open CA-38 (Unit 1/2 HP Boric Acid Pump Suction Tell Tale) (A-i, 1&2 BAMT Rm).

105._ Verify quantity of boron needed for 1. Notify Primary Chemist of volume transfer to lB BHUT is available in the removed from Unit 1&2 BAMT.

CBAST without going below minimum SLC required for CBAST. 2 GO TO Step 86 106._Open 1CS-64.

107. Start 1A CBAST PUMP.

1 08._ Inform Jj units to monitor for reactivity effects due to possible leakage of CBAST into LDST.

109.Notify Primary Chemist of the following:

Volume removed from Unit 1 &2 BAMT To sample Unit 1 CRAST for boron.

110. WHEN boron addition to 1 B BHUT is desired, THEN close 1CS-56.

111._Close 1CS-51.

Enclosure 5.4 EP/1/AIl800/ool Makeup to the BWST {25} Page 28 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

(72) makeup from 1A BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

Enclosure 5.4 EP/1/A!1800/ooi Makeup to the BWST {25} Page 29 of 29 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1 12.Locally perform the following (A-i, Bleed Transfer Pump Rm):

A. Close 1CS-149 (Bleed Tank lB Outlet Block).

B. Open 1CS-58 (Bleed Tank lB Recirculation).

C. Open 1 CS-60 (Bleed Transfer Pump lB Suction Tie).

1 13. Locally open 1CS-66 (CBAST Tie To Bleed Transfer Pumps) (A-i hallway, 8 S of column 65 at CBAST).

114._Open ICS-64.

1 15. Start lB BLEED TRANSFER PUMP.

1 16. Monitor the following for unexpected level changes:

. 1ABHUT

. Unit 1 LDST

. Unit 1 CBAST 1 17._ IAAT unexpected level changes occur in GO TO Step 121.

Unit 1 tanks (IA BHUT, LDST, CBAST),

THEN GO TO Step 118.

1 18._ Stop lB BLEED TRANSFER PUMP.

1 19. Determine and correct cause of unexpected level change.

120._GO TO Step 81.

121._WHEN CBAST addition to lB BHUT is complete, THEN stop lB BLEED TRANSFER PUMP.

Enclosure 5.4 EP/1/AIl800/ool Makeup to the BWST (25} Page 30 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST require d... (make up to BWST from 1A BHUT)

(72) makeup from 1 A BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

Enclosure 5.4 EP/1!A/l800/ool Makeup to the BWST {25} Page 31 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1 22._ Locally close 1 CS-66 (CBAST Tie To Bleed Transfer Pumps) (A-i hallway, 8 S of column 65 at CBAST).

123. Locally perform the following (A-i, Bleed Transfer Pump Rm):

A. Close 1CS-60 (Bleed Transfer Pump lB Suction Tie).

B. Open 1CS-149 (Bleed Tank lB Outlet Block).

124._VerifyDW addition to lB BHUT GO TO Step 136.

required.

125._ Ensure space is available in Waste Gas Tanks.

126._Locally open 1DW-174 (Bleed Holdup Tank Supply) (A-i, hallway S of freight elevator).

127._Locally throttle 1CT-88 (lB BHUT Condensate Supply) as necessary to control flow and minimize vent header pressure (A-i, N wall of Unit 1 BTP Rm).

128._ Monitor the following for unexpected level changes:

. 1ABHUT

• Unit I CBAST 129. Notify Unit 2 to monitor the following for unexpected level changes:

. 2ABHUT

. 2B BHUT

• Unit 2 CBAST

Enclosure 5.4 EP/1IA!18001001 Makeup to the BWST {25} Page 32 of 32 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST require d... (make up to BWST from 1A BHUT)

(72) makeup from 1A BHUT to BWST is in progress AND y of the follow ing conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT (stop makeup)

Enclosure 5.4 EP/1/A11800/001 Makeup to the BWST {25} Page 33 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 130._IAAT unexpected level changes occur in GO TO Step 134.

Unit 1, OR Unit 2 BHUTs or CBASTs, THEN GO TO Step 131.

131. Locally close 1DW-174 (Bleed Holdup Tank Supply) (A-i, hallway S of freight elevator).

132. Determine and correct cause of unexpected level change.

133. GO TO Step 124.

134._WHEN DW addition to lB BHUT is complete, THEN continue in this enclosure.

135.Locally close the following:

1DW-174 (Bleed Holdup Tank Supply)

(A-i, hallway S of freight elevator) 1CT-88 (lB BHUT Condensate Supply)

(A-i, N wall of Unit 1 BTP Rm) 136. Start lB BLEED TRANSFER PUMP.

137._ Locally throttle 1CS-58 to obtain 90-110 psig discharge pressure on lB BLEED TRANSFER PUMP (A-i, Bleed Transfer Pump Rm).

138. WHEN lB BHUT has been in recirc for 1/2 hour, THEN notify Primary Chemistry to obtain lB BHUT boron sample.

139._WHEN lB BHUT sample results are available, THEN continue in this enclosure.

140._Verify lB BHUT boron is within COLR GO TO Step 81.

limits for BWST boron requirements.

Enclosure 5.4 EP/11A11800/OOl Makeup to the BWST {25} Page 34 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required...

(make up to BWST from 1A BHUT)

(72) makeup from 1A BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• 1A BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

Enclosure 5.4 EP/1/A/l800/ool Makeup to the BWST {25} Page 35 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 141._IAAT the following conditions exist: GO TO Step 147.

1A BHUT NOT being transferred to BWST Makeup to BWST required THEN perform Steps 142 - 146.

142.Ensure NONE of the following are in recirc:

Unit I BWST Unit 2 BWST 1&2 SFP 143.Locally open the following:

1CS-96 (Spent Fuel IX (Rinse) Block)

(A-2, around corner from Caustic Add Pump)

LWD-156 (SF IX Sluice)

(Rm 218, SF CoolerRm) 144._Open ICS-56.

145. Start lB BLEED TRANSFER PUMP.

146. Locally throttle SF-47 (SF Filter Outlet To Unit I BWST) based on the following (Rm 218, SF Cooler Rm):

. BWST < 46 maintain desired flow

• BWST 46 maintain flow

- < 50 gpm 147._IAAT makeup from lB BHUT to GO TO Step 151.

BWST is in progress, AND y of the following conditions exist:

BWST makeup NO longer required lB BHUT level 15 lB BLEED TRANSFER PUMP stopped due to low level in lB BHUT THEN perform Steps 148 - 150.

Enclosure 5.4 EP/1/A/l800!ool Makeup to the BWST {25} Page 36 of 37 IF AT ANY TIME:

(62) lB BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from 1A BHUT)

(72) makeup from 1A BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• IA BHUT level 15

• 1A BLEED TRANSFER PUMP stopped due to low level in 1A BHUT...

(stop makeup)

(141) 1A BHUT NOT being transferred to BWST AND Makeup to BWST required... (make up to BWST from lB BHUT)

(147) makeup from lB BHUT to BWST is in progress AND y of the following conditions exist:

• BWST makeup NO longer required

• lB BHUT level 15

• lB BLEED TRANSFER PUMP stopped due to low level in lB BHUT...

(stop makeup)

Enclosure 5.4 EP/1/A11800/ool Makeup to the BWST 25} Page 37 of 37 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED I

148. Stop lB BLEED TRANSFER PUMP.

149. Close 1CS-56.

150.Locally close the following:

1CS-96 (Spent Fuel IX (Rinse) Block)

(A-2, around corner from Caustic Add Pump)

LWD-156 (SF IX Sluice)

(Rm 218, SF Cooler Rm)

SF-47 (SF Filter Outlet To Unit 1 BWST) (Rm 218, SF Cooler Rm)

NOTE Preparations for mixing another batch in 1A BHUT can be mad e while 1A BHUT is being transferred to the BWST. If another batch will be necessary

, returning to Step 1 will direct actions to mix a boron batch in the BAMT for transfer to CBAST if the CBAST does NOT contain sufficient volume for boron addition to 1 A BHUT. This shou ld minimize the time between batches from 1A BHUT to the BWST.

151. IAAT preparations for mixing another batch in 1 A BHUT is desired, THEN GO TO Step 1.

152. WHEN makeup operations to the BWST are complete, THEN notify RP of completion.

153.Perform the following:

A. Remove T/O sheet tag from 1HP-16 control switch.

B. Remove Do not operate 1HP-16 from T/O sheet.

154. EXIT this enclosure.

.. . END...

Admin-124 ES Page 1 of 9 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE ADMIN-1 24 Determine Minimum Shift Staffing CANDIDATE EXAMINER

Admin-124 FS Page 2 of 9 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE Task:

Determine MINIMUM staffing requirements for the shift for NEDs, RDs and SROs.

Alternate Path:

NO Facility JPM #:

ADMI N-i 24 KIA Rating(s):

K/AGen 2.1.4 Rating 3.3/3.8 Task Standard:

SLC 16.13.1-1 (Minimum Station Staffing Requirements) is used to correctly determine MINIMUM staffing requirements for the shift.

Preferred Evaluation Location: Preferred Evaluation Method:

Simulator In-Plant Classroom X Perform X Simulate

References:

SLC 16.13.1-1 (Minimum Station Staffing Requirements)

Tech Spec 3.5.2.B Validation Time: 15 mm. Time Critical: NO Candidate: Time Start:

NAME Time Finish:

Performance Rating: SAT UNSAT Performance Time Examiner: /

NAME SIGNATURE DATE Comments

Admin-124 ES Page3of9 SIMULATOR OPERATOR INSTRUCTIONS NONE

Admin-124 FS Page4of9 ToolsIEg ui pmentlProcedu res Needed:

SLC 16.13.1-1 Technical Specification READ TO OPERATOR DIRECTIONS TO STUDENT I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

INITIAL CONDITIONS

• Unit 1 = 100% power

• Unit2 = 73%

> 2A HPI Pump tagged out for the last 4 days

• Unit3 = RFO

> Core off-load in progress

• 2 on-shift NEOs are qualified as Fire Brigade Leader

• SPOC, Chemistry, and RP are staffed with only their MINIMUM number of qualified fire brigade members INITIATING CUE What are the MINIMUM staffing requirements using the MINIMUM number of licensed personnel for the shift?

Assume all SRO Licensed personnel are active for all SRO assignments.

Position Minimum Number OSM STA SRO* *Numr does not include OSM and STA positions RO NLO

Admin-124 ES Page5of9 START TIME:

STEP 1: Reference SLC 16.13.1 STANDARD: Reference SLC 16.13.1-1 table SAT COMMENTS:

U N SAT STEP 2: Reference SLC 16.13.1-1 Table for plant conditions SAT STANDARD: Determine correct table column to be used:

Column for Two units in MODE 1-4 controlled from one control room based on:

. Unit 1 is in MODE 1 at 100%

. Unit 2 is in MODE 1 at 73% with 2A HPIP OOS for the last 4 days

. Unit 3 is in a REO; core off-load in-progress COMMENTS:

STEP 3: Determine correct number from column for Two units in MODE 1-4 controlled from one control room STANDARD: 1 OSM, 1 STA, 4 SRO, 5 RO, and 8 NEO COMMENTS:

UNSAT

Admin-124 ES Page6of9 STEP 4: Determine that an available NEO is fire brigade leader qualified STANDARD: 1 of the 2 on-shift NEOs qualified as fire brigade leader will be assigned SAT as the fire brigade leader.

CUE: If asked, inform the candidate the NEO will be assigned as the fire brigade leader. UNSAT COMMENTS:

STEP 5: Adjust SRO and NEO staffing numbers per Step 4 STANDARD: Subtract 1 SRO and add 1 NEC based on NEC qualified and assigned as fire brigade leader: SAT 1 OSM, 1 STA,3SRO,5R0,and9NEO UNSAT COMMENTS:

STEP 6: Reference TS 3.5.2.B STANDARD: Determine that TS 3.5.2.B is applicable:

SAT 2AHPIPOCSfor>72 hours COMM ENTS:

UNSAT STEP 7: Adjust RO staffing numbers per Step 6 STANDARD: Add 1 RC based on TS 3.5.2.B applying SAT 1 OSM, 1 STA, 3 SRO, 6 RC, and 9 NEC COMM ENTS:

UNSAT

Admin-124 ES Paqe7of9 STEP 8: Adjust NEO staffing numbers per Step 6 STANDARD: Add 2 NEOs based on TS 3.5.2.B applying SAT 1 OSM, 1 STA, 3 SRO, 6 RO, and 11 NEC COMMENTS:

UNSAT STEP 9: Evaluate SRO requirement during fuel handling STAN DARD: Conclude the RB SRO supervising core alterations in the RB is included in the SRO requirement of table 16.13.1-1. SAT 1 OSM, 1 STA, 3 SRO, 6 RO, 11 NEC COMMENTS:

UNSAT STEP 10: Determine total staffing requirements CRITICAL STEP STANDARD: I OSM, I STA, 3 SRO, 6 RO, 11 NLO SAT Position Minimum Number UN SAT OSM I STA I SRO 3 RO 6 NLO II COMMENTS:

END OF TASK TIME STOP:

Admin-124 ES Page8of9 CRITICAL STEP EXPLANATIONS STEP # Explanation 10 Determine staffing requirements

Admin-124 ES Page9of9 CANDIDATE CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS

• Unit 1 = 100% power

• Unit2 = 73%

> 2A HPI Pump tagged out for the last 4 days

• Unit3 = REQ Core off-load in progress

• 2 on-shift NEOs are qualified as Fire Brigade Leader

• SPOC, Chemistry, and RP are staffed with only their MINIMUM number of qualified fire brigade members INITIATING CUE What are the MINIMUM staffing requirements using the MINIMUM number of licensed personnel for the shift?

Assume all SRO Licensed personnel are active for all SRQ assignments.

Position Minimum Number OSM STA SRO* *Numr does not include OSM and STA positions RO NLO

Minimum Station Staffing Requirements 16.13.1 16.13 CONDUCT OF OPERATIONS 16.13.1 Minimum Station Staffing Requirements COMMITMENT a. Minimum station staffing shall be as indicated in Table 16.13.1-1 and shall meet the following additional requirements:

1. At least one RO per unit shall be present in the control room when fuel is in the reactor. In addition, while the unit is in MODES 1, 2, 3, or 4, at least one licensed SRO shall be present in the control room.

2. At least one licensed operator shall be in the reactor building when fuel handling operations in the reactor building are in progress. In addition, during CORE ALTERATIONS including fuel loading and transfer, an SRO or an SRO limited to fuel handling shall be present to directly supervise the activity and, during this time, shall not be assigned to other licensed activities

3. If the computer for a reactor is inoperable for more than eight hours, an operator, in addition to those specified in ITS 5.2.2.b and 10 CFR 50.54(m) shall supplement the control room staff.

b. The Shift Technical Advisor shall be an experienced SRO.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements for A.1 Restore minimum station 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> minimum station staffing levels.

staffing not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 16.13.1.1 N/A N/A 16.13.1-1 05/13/04

Minimum Station Staffing Requirements 16.13.1 Table 16.13.1-1 MINIMUM STATION STAFFING REQUIREMENTS THREE UNITS TWO UNITS IN TWO UNITS IN ONE UNIT IN THREE UNITS IN MODES 1-4 MODES 1-4 MODES 1-4 MODES 1 -4 IN MODES 5 OR CONTROLLED CONTROLLED 6 OR NO MODE FROM iWO FROM ONE CONTROL CONTROL ROOMS ROOM OSM 1 1 1 1 1 STA 1 1 1 1 1 1

SRO 5 5 4 4 3 3

RO 6 5 5 4 3 12 NLO 8 8 8 8 7 SPOC 7 7 7 7 6 Chemistry 1 1 1 1 1 Technician RP Technician 3 3 3 3 3 1 SRO number can be reduced by one when a qualified NLO is designated the fire brigade leader. The NLO number must be increased by one, or one fire brigade member must be supplied from another organization.

2 NLO number must be increased by two when in ITS 3.5.2 Condition B.

3 RO number must be increased by one when in ITS 3.5.2 Condition B.

16.13.1-2 05/13/04

Minimum Station Staffing Requirements 16.13.1 BASES Some of the requirement(s) of this SLC section were relocated from TS 6.1.1.9 and TS Table 6.1-1 during the conversion to ITS. These requirements were initially relocated to SLC 16.13.5, Additiona Operating Shift Requirements, dated 3/27/97.

The requirements of this SLC consolidate ONS station staffing requirements into one document. This SLC includes the shift manning requirements of ITS 5.2.2, 10 CFR 50 Appendix R Section IILH, 10 CFR 50.54.m, Operations Management Procedures (OMP s), NSD 112, and the Emergency Plan. This SLC also includes the old requirements of SLC 16.13.1 Fire Brigade, dated 3/27/99 and SLC 16.13.5; Additional Operating Shift Requirements dated 3/27/99. The numbers for each position per shift are additive. For example, Table 16.13.1

-1 requires a total of 5 SROs per shift (3 SROs required by 10 CFR 50.54(m)(2)(i) plus 1

additional SRO for the Fire Brigade and 1 additional for the ERO). The bases for the numbers in the first column of SLC Table 16.13.1-1 are as follows:

1 OSM (active SRO) Required by 50.54(m)(2)(ii) (implemented by OMP).

1 STA (active or inactive SRO) Required by ITS 5.2.2.g which indicates the individual fulfilling the STA position is the Shift Work Manager (implemented by OMP). Revision 50 to OMP 2-1 renamed the person fulfilling this position an STA. Note that pre-conversion TS Table 6.1-1, which implemented NUREG-0737 requirements, did not require an STA on shift when no units were in MODES 1-4. The SLC Table is more restrictive in that it requires an STA on shift at all times.

3 SROs (active SRO) Required by 10 CFR 50.54(m)(2)(i). Per ITS 5.2.2.b and 10 CFR 50.54(m)(2)(iii) at least 2 SROs must be in the control room.

1 SRO (active or inactive) or NLO Required by Appendix R Section IIl.H.

- Fire Brigade Implemented by OMP and NSD. Individual fulfilling position shall be a SRO or an NLO who is qualified to be a fire brigade leader. Per OMP this individual functions as fire brigade leader and is not available for control room activities when directing the fire brigade. Appendix R does not specify that the brigade leader be an SRO, it only specifies that the fire brigade leader have sufficient training in or knowledge of plant safety-related systems to understand the effects of fire and fire suppression systems on safe shutdown capability. When an 16.13.1-3 05/13/04

Minimum Station Staffing Requirements 16.13.1 NLO is serving as the fire brigade leader, the SRO number for each column in Table 16.13.1-1 may be reduced by one.

1 SRO (licensed or previously Required by Volume A, Section B, Figure B-2 of licensed) ERO the Emergency Plan. Implemented by OMP. SRO serves as the offsite communicator and the NRC communicator in the CR/TSC. This is permissible since the offsite communicator role is completed prior to the NRC communicator role starting.

5 ROs Required by 10 CFR 50.54(m)(2)(i).

1 RO - SSF Required by ITS 5.2.2.h, implemented by OMP.

Per ITS 5.2.2.h, the manpower necessary to operate the SSF will be exclusive of the fire brigade and the minimum operating shift that is required to be present in the Control Room. ITS 5.2.2.b andlO CFR 50.54(m)(2)(iii) require 3 of the 5 ROs required by 10 CFR 50.54(m)(2)(i) to be present in the control room when fuel is in the reactor. When all three units are in MODES 1-3, one RO per unit must be available to be dispatched to the SSF.

Since 3 ROs must be present in the Control Room only two are available to dispatch to the SSF.

Therefore, one additional RO, beyond what is required by 10 CFR 50.54(m)(2)(i), is required.

1 RO ADV Amendment 314, 314, 314 requires that staffing level be increased by an additional RO beyond what is required in Table 16.13.1-1 when in Condition B of ITS 3.5.2. The additional RO is designated to respond to an event requiring activation of the SSF for the unit operating under ITS 3.5.2 Condition B. The additional RO role may be fulfilled by an SRO as long as the SRO is not being counted towards the number of required SROs listed in Table 16.13.1-1 and is qualified to tasks involving operation of the SSF systems.

When all three units are in MODES 1-4, a total of seven ROs are required; five per 10 CFR 50.54(m)(2)(l), one per ITS 5.2.2.h, and one per ITS 3.5.2 Condition B.

8 NLOs Required by 10 CFR 50 Appendix R Part lll.H, ITS 5.2.2.a, Volume A, Appendix 8, Spill Prevention 16.13.1-4 05/13/04

Minimum Station Staffing Requirements 16.13.1 and Control and Counter Measures Plan, Revision 98-04, 10/98 of the Emergency Plan, and Volume A, Section B, Figure B-8 of the Emergency Plan.

Implemented by OMP. (Four for fire brigade, one NLO per Unit to complete critical AP and EOP actions and 1 for SSF equipment verification for the design basis Appendix R fire.) When an NLO is serving as the fire brigade leader, the NLO number for each column in Table 16.13.1-1 must be increased by one or one fire brigade member must be supplied from another organization.

The number of NLOs that are fire brigade qualified may be reduced provided that a like number of fire brigade qualified personnel are provided from other organizations. This does not change the total number of NLOs required; only the number required to be fire brigade qualified.

2 NLOs ADV License Amendment 314, 314, 314 requires that staffing levels be increased by an additional two NLOs beyond those required in Table 16.13.1-1 when in Condition B of ITS 3.5.2. The additional NLOs are designated for the purpose of operating the Atmospheric Dump Valves (ADVs) for the unit under ITS 3.5.2 Condition B. In addition, the NLOs with the responsibility for operating the ADVs will be designated to respond to the control room within five minutes and will not be given duties that will prevent this from happening.

7 SPOC Required by Volume A, Section B, Figure B-8 of the Emergency Plan and the Fire Plan (Volume A, Appendix 8, Spill Prevention and Control and Counter Measures Plan, Revision 98-04, 10/98).

Implemented by OMP 1-7 and NSD 112. Consists of two I&E technicians ERO qualified and knowledgeable of IP/0/A0050/003 (Power SSF Submersible Pump), two MM technicians ERO qualified and knowledgeable of MP/0/AI1 300/059 (Install SSF Submersible Pump), one supervisor or temporary supervisor qualified to establish the OSC and perform the OSC Maintenance Supervisor functions, and one additional person to help with pump installation as directed by SPOC supplied by one of the following groups in the order 16.13.1-5 05/13/04

Minimum Station Staffing Requirements 16.13.1 listed: SPOC, other maintenance personnel onsite, C&F, Chemistry, RP and Maintenance Overtime resources. Security will automatically supply one Security Guard to open doors and gates who will also assist with any maintenance activities to be performed. The Security Guard is counted as one of a total of 6 people needed to install the submersible pump. One other person is needed to establish the OSC for a total of 7. In the event of a fire, SPOC will respond to the fire until directed to install the submersible pump. A total of 5 SPOC personnel are assigned to the fire brigade. Per PIP 4-099-2987 problem evaluation, it is acceptable to consider these additional 5 Fire Brigade members to be available for other duties, such as installation of the SSF pump. This is based on Oconee Fire Brigade Guide #2, which contains guidance that allows fire brigade members to be released from the brigade for operational needs at the discretion of the OSCITSC.

The number of SPOC personnel qualified as fire brigade members may be reduced, provided that the qualified fire brigade members from other organizations are increased by a like number. This does not change the total number of SPOC personnel required, only the number required to be fire brigade qualified.

1 Chemistry Technician ERO Required by Volume A, Section B, Figure B-8 of the Emergency Plan. Implemented by OMP and Station Chemistry Manual 2.6. A Chemistry Technician who is fire brigade qualified may be credited toward fulfilling the ERO requirement and the fire brigade requirement. In the event of a fire, the Chemistry technician will respond to the fire until directed otherwise.

3 RP Technicians Three are required by Volume A, Section B, Figure B-8 of the Emergency Plan. One is required by ITS 5.2.2.d and may be counted towards fulfilling the ERO requirement. Implemented by HPIOIBI1000IO54. RP technicians who are fire brigade qualified may be credited toward fulfilling the ERO and TS requirements and the fire brigade requirement. In the event of a fire, the RP 16.13.1-6 05/13/04

Minimum Station Staffing Requirements 16.13.1 technician will respond to the fire until directed otherwise.

Minimum Station Staffing numbers for the SRO and RO positions in Table 16.13.1

-1 change as a function of the number of units in MODES 1-4 and whether the operating Units are controlled from one or two Control Rooms. The number for the remaining positions in Table 16.13.1-1 is not affected by operational condition of the units.

10 CFR 50.54(m)(2)(i) requires 3 SROs when two units are in MODES 1-4 and contro lled from two Control Rooms, 2 SROs when two units are in MODES 1-4 and controlled from a common control room, 2 SROs when one unit is MODES 1-4 and 1 SRO when no units are MODES 1-4. Thus considering fire brigade and ERO requirements, this results in the requirement for 5 SROs when two units are in MODES 1-4 and controlled from two Control Rooms, 4 SROs when two units are in MODES 1-4 and controlled from a commo n control room, 4 SROs when one unit is MODES 1-4 and 3 SROs when no units are MODES 1-4.

10 CFR 50.54(m)(2)(i) requires 5 ROs when two units are in MODES 1-4 and controlled from two Control Rooms, 4 ROs when two units are in MODES 1-4 and contro lled from a common control room, 4 ROs when one unit is MODES 1-4 and 3 ROs when no units are MODES 1-4. OMPs require 2 ROs to man the SSF when two units are in MODES 1-3 and 1 RO when one unit is MODES 1-3. None are required when no units are in MODES 1-3.

Therefore, no additional ROs are required beyond what is required by 10 CFR 50.54(m)(2)(i) when less than three units are in MODES 1-3 with one exception.

When two units are in MODES 1-3 and controlled from one Control Room one additio nal RO is required since 10 CFR 50.54(m)(2)(i) only requires 4 ROs when the two operating units (Units 1 and 2) are controlled from one control room. Since one RO (or SRO) must be present in the Control Room when fuel is in the reactor vessel, the two ROs required to man the SSF for the operating units are exclusive of the one RO require d for each unit.

Therefore, a total of 5 ROs are required for this configuration.

The minimum staffing number for the SPOC and NLO positions is reduce d by one when all three units are in MODE 4 or below. This reduction is allowed since the SSF is not required to be OPERABLE in these MODES. Therefore, there is no need for SPOC to provide a qualified individual to establish the OSC and no need for an NLO to perform SSF equipment verification.

SLC 16.13.1.a.1 requires at least one ROper unit to be present in the contro l room when fuel is in the reactor and one SRO to be present in the control room while in MODES 1-4. This requirement is based on 10 CFR 50.54(m)(2)(iii) and ITS 5.2.2.b. The first part of SLC 16.13.1 .a.2, which requires at least one licensed operator to be in the reactor building when fuel handling operations in the reactor building were in progress, was relocat ed during the ITS conversion from TS Table 6.1-1, Additional Requirement 3. This require ment has existed since the initial issuance of Oconee Technical Specifications. The second part of SLC 16.13.a.2, which requires that a SRO or an SRO limited to fuel handling activities be present to directly supervise CORE ALTERATIONS including fuel loading or transfer and be assigned no other duties, is based on 10 CFR 50.54(m)(2)(iv). SLC 16.13.1.a.3 which requires an operator, in 16.13.1-7 05/13/04

Minimum Station Staffing Requirements 16.13.1 addition to those specified in ITS 5.2.2.b to supplement the control room staff if the computer for a reactor is inoperable for more than eight hours, was relocated during the ITS conversion from TS Table 6.1-1, Additional Requirement 6. This requirement has also existed since the initial issuance of Oconee Technical Specifications. SLC 16.13.1.b, which specifies the STA shall be an experienced SRO was relocated during the ITS conversion from TS 6.1.1.9.

The primary purpose of the Fire Protection Program is to minimize both the probability and consequences of postulated fires. Despite designed active and passive Fire Protection Systems installed throughout the plant, a properly trained and equipped Fire Brigade organization of at least ten (Reference 8) members is needed to provide immediate response to fires that may occur at the site. This number is the result of a corrective action from Reference

10. This Fire Brigade requirement is normally met by using one SRO (or NLO qualified to be a

fire brigade leader), 4 NLOs, and 5 SPOC personnel. However, this requirement can also be met by using personnel from other organizations (e.g., Chemistry, Radiation Protection, and Security).

Fire Brigade equipment and training conform to Oconees commitments to Appendix A to Branch Technical Position 9.5-I and supplemental NRC Staff guidelines including Nuclea r Plant Functional Responsibilities, Administrative Controls and Quality Assurance.

This SLC is part of the Oconee Fire Protection Program and therefore subject to the provis ions of Oconee Facility Operating License Conditions.

The following requirement was relocated from the TS 6.1.1.8 during the conversion to ITS.

A training program for the fire brigade shall meet or exceed the requirements of Section 27 of the NFPA Code-i 975, except that training sessions may be held quarterly.

ACTIONS Al With the requirements for minimum station staffing not met, the minimum station staffin g levels shall be restored within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. The 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Completion Time is consistent with ITS 5.2.2.c and d which allows 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to accommodate unexpected absence of on-duty shift crew members provided that immediate action is taken to restore the shift crew composition to within the minimum requirements.

REFERENCES:

1. Oconee UFSAR, Chapter 9.5.1.

2. Oconee Fire Protection SER dated August ii, 1978.

3. Oconee Fire Protection Review, (currently contained in the Fire Protection DBD) as revised.

4. Duke letter of January 16, 1978 to NRC in response to Nuclear Plant Functional Responsibilities, Administrative Controls, and Quality Assurance.

5. ITS 5.2.2, Amendment 300/300/300.

16.13.1-8 05/13/04

Minimum Station Staffing Requirements 16.13.1

6. 10 CFR 50.54(m).

7. Emergency Plan, Volume A, Section B, Figure B-8, Revision 97-01, 7/97.

8. Emergency Plan, Volume A, Appendix 8, Spill Prevention and Control and Counter Measures Plan, Revision 98-04, 10/98.

9. Station Chemistry Manual 2.6.

10. Problem Investigation Report Serial No. 1-089-0001.

11. Problem Investigation Process (PIP) Serial No. 4-099-2987.

12. ITS 3.5.2, Amendment 314/314/314.

13. NRC Regulatory Issue Summary (RIS) 2002-16, Current Incident Response Issues.

14. PIP 0-03-0233 16.13.1-9 05/13/04

ADMIN 212 FS Page 1 of 12 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE ADMIN-21 2 DETERMINE LTOP REQUIREMENTS CANDIDATE EXAM IN ER

ADMIN 212 ES Page 2 of 12 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE Task:

Determine LTOP Requirements Alternate Path:

No Facility JPM #:

MODIFIED K/A Rating(s):

System: 001 K/A: Gen2.2.14 Rating: 3.9/4.3 Task Standard:

Per OP/I /A/1104/049, Low Temperature Overpressure Protection, based on conditions provided and plant knowledge determine that LTOP requirements are not being met based upon 6 plant conditions.

Preferred Evaluation Location: Preferred Evaluation Method:

Simulator In-Plant Classroom X Perform X Simulate

References:

OP/I /A/1 104/049 Low Temperature Overpressure Protection (LTOP)

OP/O/A/1 108/001 Curves and General Information Validation Time: 30 mm Time Critical: NO Candidate: Time Start:

NAME Time Finish:

Performance Rating: SAT UNSAT Performance Time:

Examiner: /

NAME SIGNATURE DATE COMMENTS

ADMIN 212 ES Page 3 of 12 SIMULATOR OPERATOR INSTRUCTIONS NONE

ADMIN 212 ES Page 4 of 12 ToolslEguipmentlProcedures Needed:

Unit 1 Conditions For Determining LTOP Requirements (Last page of JPM)

OP/I/A/i 104/049 OP/I/A/l 104/049, End. 4.13 (LTOP Requirements Logic Diagram)

OP/O/A/l108/00l Curves and General Information (Available in procedures cart)

Highlighter READ TO OPERATOR DIRECTION TO TRAINEE I will explain the initial conditions, and state the task to be performed. All contro l room steps shall be performed for this JPM, including any required communications.

I will provide initiating cues and reports on other actions when directed by you. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet provided.

INITIAL CONDITIONS Unit 1 controlling procedure for unit shutdown and cooldown is in progre ss for entering a refueling outage. Plant conditions are as described in the attachment provid ed.

INITIATING CUES Based on the conditions described above and by using any associated plant procedures, verify that LTOP requirements are being met per the provided End. 4.13 (LTOP Requirements Logic Diagram) of OP/I /A/1104/049 (Low Temperature Overpressure Protec tion).

If being met, then all the LTOP requirements that ULTIMATELY result in LTOP not met. If any requirements are being being met, THEN document by listing on the provided copy of LTOP Requirements Logic Diagram End. 4.13 of OP/I/Ni 104/04 9, LTOP.

ADMIN 212 ES Page 5 of 12 STARTTIME:

STEP 1:

LTOP (HPI) Verify HPI deactivated per OP/i/Ni 104/049 (LTOP). SAT STANDARD: Refers to OP/i/Ni 104/049 (LTOP) End. 4.13 and attachment and determines that HPI is deactivated. UNSAT COMMENTS:

CRITICAL STEP STEP 2:

LTOP (CFT) Verify each CFT isolated per OP/i/Ni 104/049 (LTOP) when SAT GET pressure 373 psig.

STANDARD: Determines from attachment that Core Flood Tanks (CFTs) are NOT UNSAT isolated in that:

1. lB CFT pressure is 375 psig (>373 psig)

2. i CE-2 is Closed with handwheel tagged BUT breaker NOT tagged open COMMENTS:

STEP 3:

LTOP (Pzr Level)

SAT Verify Pzr level within LTOP limits per heatup/cooldown curves in OP/0/Ni 108/001 (Curves And General Information).

STANDARD: Determines that Pzr Level is within limits; Pzr Level must be <220 UNSAT inches. It is currently 218 inches.

COMMENTS:

ADMIN 212 FS Page 6 of 12 STEP 4:

LTOP (Pressurizer Heater Bank 3 or 4)

Verify Pressurizer Heater Bank 3 OR 4 white tagged open per OP/i IN1 104/049 (Low Pressure Overpressure Protection (LTOP

). SAT STANDARD: Determines from attachment that Bank 4 Heaters are white tagged open.

Either Bank 3 or 4 heaters being deactivated meets requirements. UNSAT COMMENTS:

STEP 5:

LTOP (1 RC-4)

Verify 1 RC-4 open when PORV is required to be operable.

SAT STANDARD: 1 RC-4 is open when PORV required to be operable UNSAT COMMENTS:

STEP 6:

LTOP (1RC-4)

Verify 1 RC-4 open when the following conditions are met:

• PORV removed

• 1 RC-4 installed SAT

• 1 RC-4 part of LTOP vent path UNSAT STANDARD: Verifies 1 RC-4 is open; but none of the above conditions require 1 RC-4 to be open COMMENTS:

ADMIN 212 ES Page 7 of 12 STEP 7:

LTOP (RC Pressure)

Verify RCS <525 psig when RCS SAT

> 220°F and 325°F.

OR Verify RCS <375 psig when RCS 220°F.

UNSAT STANDARD: Determines RC Pressure to be within limits COMMENTS:

STEP 8:

LTOP (RC Makeup Flow)

Verify 1HP-120 travel stop operable per OP/1/N1104/049 (LTOP) SAT or HPI Pumps NOT capable of starting and injection into RCS via 1HP-120.

STANDARD: 1HP-120 Travel Stop operable UNSAT COMMENTS:

STEP 9: -Page 9-SR 3.4.12.6 LTOP (OAC Alarms)

SAT NOTE: The 225 Pressurizer Level Computer alarm is included in this check.

Verify 01 L31 53 jQI in alarm fl OAC operable. UNSAT IF 01 L31 53 in alarm, evaluate LTOP input points valid by using LTOP OAC Screen.

Refer to OP/1/A/1104/049 (Low Temperature Over pressure Protection (LTOP).

STANDARD: Per Attachment, computer point is not in alarm (Pzr Level is <225 so the alarm is not actuated.)

COMMENTS:

ADMIN 212 ES Page 8 of 12 STEP 10: SR 3.4.12.6 LTOP (OAC Alarms) (260 Pressurizer Level Computer alarm.)

Verify the following:

1 SA-2/C-3 RC Pressurizer Level High/Low Statalarm SAT card NOT Pulled.

f Either iSA/i 8/A-3 OR iSA/i 8/A-4 is in alarm OR card pulled, THEN verify the following Computer Point status:

• 01X2256 UNSAT Quality = GOOD Value = FALSE

• O1X2274 Quality GOOD Value = FALSE

• O1X2285 Quality = GOOD Value FALSE STANDARD: Per attachment, SA Cards are not pulled and not in alarm COMMENTS:

STEP 11: SR 3.4.12.6 LTOP (OAC Alarms) (315Pressurizer Level Computer CRITICAL STEP alarm)

Verify 1 SA-2/C-4 RC Pressurizer Level Emerg High/L ow Statalarm card NOT Pulled. SAT STANDARD: Determines per attachment, SA card UNSAT is IS PULLED COMMENTS:

ADMIN 212 FS Page 9 of 12 STEP 12: SR 3.4.12.6 CRITICAL STEP LTOP (HP Nitrogen System)

Verify 1N-121 white tagged closed per OP/i/A/i 104/049 (LTOP).

SAT STANDARD: Determines per attachment that 1N-121 is closed but NOT white tagged

. UNSAT COMMENTS:

STEP 13: End. 4.13 LTOP (Logic Diagram) CRITICAL STEP Verify LTOP requirements met per Enclosure LTOP Requirements Logic Diagram of OP/i/Ni 104/049 (LTOP).

SAT STANDARD: Determines from the Logic diagram and the attachment that LTOP surveillance requirements are NOT satisfied due to 6 items in that:

• 1 B CFT is NOT isolated due to its breaker not tagged open UNSAT

• lB CFT pressure is 375 psi 9 (must be less than 373 psig)

• 1SA-2/C4 alarm card is pulled (must be installed with no HIGH alarm)

• 1N-121 is closed but NOT tagged closed

• No dedicated LTOP operator is assigned

• LTOP vent or Pzr Relief standpipe (valve removed or greater vent path) is NOT established Candidate may list items such as the following that are LTOP gy requirements not surveillance requirements. These shall not be counte d

as part of the required answers and are annotated as such on the provided End. 4.13:

• Tc325°F

• RV Head Off / or SG Primary Manway Off / or Pzr Manway Off NOTE: Incorrectly listing a reason(s) that satisfies LTOP requirements or does NOT ultimately result in requirements not being met will be counted towards overall unsatisfactory completion of the task.

COMMENTS:

END OF TASK STOP TIME:

ADMIN 212 ES Page 10 of 12 CRITICAL STEP EXPLANATIONS STEP # Explanation 2 Requires determination of 1 B CFT NOT being isolated or depressurized 11 Requires determination that 1SA-2/C4 alarm card is pulled (must be installe d with no HIGH alarm) 12 Requires determination that 1N-121 is closed but NOT tagged closed 13 Requires determination that:

• No dedicated LTOP operator is assigned

• LTOP vent or Pzr Relief standpipe (valve removed or greater vent path) is NOT established

CANDIDATE CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS Unit 1 controlling procedure for unit shutdown and cooldown is in progress for entering a refueli ng outage. Plant conditions are as described in the attachment provided.

INITIATING CUES Based on the conditions described above and by using any associated plant procedures, verify that LTOP requirements are being met per the provided End. 4.13 (LTOP Requirements Logic Diagram) of OP/I/Ni 104/049 (Low Temperature Overpressure Protection).

If not being met, then list all the LTOP requirements that ULTIMATELY result in LTOP not being met. If any requirements are not being met, THEN document by listing on the provided copy of LTOP Requirements Logic Diagram End. 4.13 of OP/I/N1104/049, LTOP.

Unit I Conditions For Determining LTOP Require ments (TO BE RETURNED TO EXAMINER UPON COMPLE TION OF TASK)

Procedures in progress:

OP/I/Ni 102/010, Controlling Procedure for Unit Shut down

• End. 4.10, S/D from Mode 3 to Mode 4 in progress NOTE: Any equipment or components associated with LTOP requirements that are not described below can be assumed to be in the desired position/

condition to support Unit ls current plant status.

RCS Parameters:

• Tc 225° F slowly decreasing

• RCS Pressure 285 psig decreasing

• Pressurizer Level = 218 inches decreasing slowly

• LPI operation (Series Mode) in progress Primary Systems/Components status:

• All HPI pumps are OFF

• lB and IC HPI Pumps are racked out and tagged

• 1A HPI Pump is racked in the TEST position and tagg ed

• I HP-26 and I HP-27 are closed; handwheels tagg ed; breakers tagged open

• IHP-409 and -410 switches in CR have been tagg ed closed

• 1 CF-i is Closed / handwheel tagged and breaker tagged open

• 1 CF-2 is Closed / handwheel tagged and breaker not tagged open

• 1A CFT pressure = 368 psig stable

• 1 B CFT pressure = 375 psig stable

• 1HP-i20 Travel Stop installed

• LTOP computer point 01L3153 is in alarm

• 1SA-21C-3 and 1SA-18/A-3, A-4 cards are not pulle d and not in alarm

• 1 SA-2/C-4 card is pulled

• iN-12i is closed but not tagged

• Pressurizer Heater Bank 4 is deactivated with brea ker white tagged

• No dedicated LTOP Operator assigned

• An LTOP Vent path ( 3.6 square inches) is not estab lished

• I RC-4 is open

o Enclosure 4.13 OP/i/All 104/049 LTOP Requirements Logic Diagram Page 1 of I

)( Tc 0 325 F Performed By NOTOperd/ng LTOP TRAIN I Date/Time LTOP TRPJ N 2 1A & 18 1-IPIPs racked cot or crest, and tagged 1HP-26 closed/hardwheel lagged and bkr tagged open tHP.409 CR swdch tagged closed 1HP.415 CR sw/ch tagged closed Pzr reliel staodpipn (valve ram000d) or greeter venl path established OC HPIP bkr racked oct or in test, and tagged tl-IP-27 closedlhandwhnel tagged and bbs tagged opec LTOP 1 HP-409 CR switch lagged closed Requirements 1HP-410 CR switch tagged closed Satisfied ICF-IClssedi handwheel lagged and kkr lagged open IA CFT depressurized 10 <373 psig

)(CF-2 closedlhandwheel lagged and bbr lagged open NOTE: Enc. 4.7 (LTOP Computer

)(1B CFT depressanzed to <373 psig Points) contains a list of points associated with LTOP operability.

HPI NOT in operation and aligned cia 1 HP-120 on 1HP-120 Travel Stop Operable LTOP Computer point 01L3153 not is alarm 1SA-2)C-3,cards not pulled.toot in alarm HIGH ISA-181A.3 card cot pulled/nat in alarm Comnp. p15. OtX2256 AND 00<2274 Operalsle ISA.lgfA-4 card not pulled/nd isalane Camp. pt. O1X2285 OporOble OAC operable

)1N.l21 Tagged Closed Pzr Htr Bank 3 Deactmualed Pzr HIr Bank 4 Deacgrdaled RCS pressure wilhn limes RV Head Ott PZR level wilhin lirrats Xso Prurrary Macsnap 011 Dedicaled LT0POpemalorassigned XPzr Macreap Off Unit 1 LTOP Logic Rev. 22.des LTOP cent established O1LTOP0001.DES 08/20/09 rlr If an RC5 vent path is established per Enclosure 4.5 (LTOP VenI Paths), Ibis requirernest con be considered mccl daring HPI testing.

0 Enclosure 4.13 OP/i/A/i 104/049 LTOP Requirements Logic Diagram Page 1 of I Performed By LTOP TRAIN 1 Date/Time 1A& lB HPIPs racked oat or/n Inst. end tagged llIP-26 closedlhendwheel tagged and bkr lagged open 1HP-40g CR switch lagged closed 4 r

ar 1HP-410 CR ow/ch lagged closed Pzr relict standplpe (valve removed) or greater vent path established 1C HPIP bkr racked outer/n lest, end tagged 1HP-27 closedlbarrdwlreel tagged and bkr tagged open LTOP 000 il-/P-dog CR match tagged closed  ::--- Requirements 1HP-415 CR switch lagged closed Satisfied ICF-IClosedl bandwhenl tagged and bkr tagged open IA CFT dnpressorized 10<373 pSig ..4_

1CF.2 closedltrandwheel lagged and bkr lagged open NOTE: Enc. 4.7 (LTOP Computer 18 CF7 depressar/zed to c373 pug Points) contains a list of points 1-/Fl NOT rr operation and aligned via IHP-120 associated with LTOP operability.

1HP-12g Travel Step Operable LTOP Ce,npsler psint 01L3153 not in alarm ISA-21C-3. C-4 cords net polled/not in alarm HIGH tSA-lg/A-3 card not polled/not in alarm Comp. plo. 01X2256 AND 0152274 Ope<<

1SA.181A-4 card not pulledlnot in alarm Comp. p1. 0152285 Operable OAC operable 1N-121 Tagged Closed PZr Htr Bank 3 Dnactraaled PZr HIr Bank 4 Onactraated RCS pressure edthrn mes

<so PZR level willen liwds 513 PrrmaryMarrwayOff___-_

Dedicated LTOPOperatorassigned Unit I LTOP Logic Rev. 22.des LTOP vent established O1LTOP0001.DES

• 08/20109 rtr If an RCS vent path is established per Enclos sre 4.5 (LTOP Vent Paths), this requirement can considered met dunng HPI testing, be

Duke Energy Procedure No.

Oconee Nuclear Station oP1l1A111o41049 LOW TEMPERATURE OVERPRESSURE Revision No.

PROTECTION (LTOP) 045 Electronic Reference No.

Continuous Use OX002VM4 PERFORMANCE UNCONTROLLED FOR PRINT* * * * * * * * * *

(ISSUED) PDF Format

OP/i/A/i 104/049 Page 2 of 5 Low Temperature Overpressure Protection (LTOP)

1. Purpose This procedure provides guidance to comply with Technical Specification (TS) 3.4.i2 and SLC 16.5.2 as well as provide protection from a low temperature overpr essure (LTOP) event.

2. Limits And Precautions 2.1 LTOP must be set per this procedure under the following plant conditions:

• MODE 3 when any RCS cold leg temperature is 325°F

• MODES 4, 5, and 6 when an RCS vent path capable of mitigating the most limiting LTOP event is NOT open 2.2 Conditions for which a dedicated LTOP Operator can compensate are shown graphically in Enclosure 4.13 (LTOP Requirements Logic Diagram).

NOTE: For purpose of performance of HPI Full Flow testing, LTOP controls are met by having both OTSG handholes removed.

2.3 The LTOP requirement of deactivating HPI can be considered met during HPI System testing when a LTOP vent path 3.6 square inches is open. Refer to Enclosure 4.5 (LTOP Vent Paths) for vent path flow area sizes.

2.4 Refer to Enclosure 4.8 (LTOP Pressure Instruments) for detailed inform ation concerning acceptable pressure instruments to be used during LTOP.

2.5 1N-121 (High Pressure Supply to Pzr) should remain closed when LTOP is required.

This valve has a permanent tag stating this.

2.6 A dedicated LTOP Operator is a compensatory measure allowed by TS 3.4.12 Condition F to monitor for an initiation of an LTOP event. Entry into this Condition is required any time a dedicated LTOP Operator is established.

2.7 Removing an ICCM Train from service renders the associated Pressu rizer level(s) for that ICCM train inoperable, and therefore the 260 inch audible Pressu rizer level alarm inoperable. A dedicated LTOP Operator will be required if the RCS

< 325°F and a vent path is NOT established.

OP/i/AR 104/049 Page 3 of 5 2.8 A dedicated LTOP Operator is required when RCS 325°F and any of the following administrative controls CANNOT be impl emented:

2.8.1 RCS closed (no LTOP vent path establishe d),

AND HPI pump operating and capable of injecting into RCS via 1HP-120 (RC VOLUME CONTROL),

AND 1HP-120 travel stop is inoperable.

2.8.2 RCS closed, AND RCS has deviated from pressure, temp erature, or level limits.

2.8.3 RCS closed, AND controls on use of high pressure Nitro gen NOT established.

2.8.4 RCS closed, AND number of available Pressurizer Heat er Banks NOT restricted.

2.8.5 RCS closed, AND OAC inoperable, 2.8.6 RCS closed, AND LTOP computer alarms inoperable.

2.8.7 RCS closed, AND any required audible Pressurizer level alarm inoperable.

2.8.8 RCS closed, AND the required audible RCS high press ure alarms inoperable.

2.9 When 1HP-120 travel stop is installed, available makeup flow is limited. RCS rate should be monitored and controlle cooldown d.

2.10 At least one HPI train shall be available as a makeup source from the BWST RCS vent equivalent to two SG primary whenever a handholes one SG primary manway is NOT established. {3}

OP/i/A/i 104/049 Page 4 of 5 2.11 OAC computer points:

2.11.1 When Computer Points are credited for LTOP, the Computer Pomts MUST be used from a Computer Display that indicates the Qual ity of the Computer Point.

The point Value must represent actual plant cond itions and the point Quality MUST indicate one of the following:

• GOOD

• INHB

• LALM

• HALM

• LOLO

• HIHI

• ALM

• DALM 2.11.2 Computer points 01 L3 154 (LTOP-RCS Pres sure High (Channel 1)) and O1L3 156 (LTOP-Pzr Lvi High (Channel 1)) are non-credited backup LTOP alarms fed from the RC LR PRESS TRAIN A instrument. Inoperability of these alarms requires no action.

2.11.3 Computer points 01L3 169 (LTOP-RCS Pressure High (Channel 2)) and 01L3 168 (LTOP-Pzr Lvi High (Channel 2))

are the RCS high pressure and 225 inch Pzr level alarms that are credited in the LTOP analysis. These alarms receive pressure input from the RC LR PRESS TRAiN B instrument which does NOT control the PORV. If eithe r of these computer points is inoperable, entry into TS 3.4.12 Condition F is required.

2.12 Enclosure 4.13 (LTOP Requirements Logi c Diagram) aids in determining if LTOP requirements are satisfied. This diagram shou ld be used as a reference when planning 3 performing activities that may affect LTOP.

2.12.1 Enclosure 4.13 (LTOP Requirements Logic Diag ram) should be verified as follows:

• Applicable plant/equipment configuration statu s should be circled.

• Logic diagram path should be traced out to verif y LTOP requirements are satisfied.

2.13 Enclosure 4.15 (Swapping LTOP Components) is available for swapping to alternate configuration for LTOP components after LTO P has been set, if needed.

OP/i/A/l 104/049 Page 5 of 5

3. Procedure None

4. Enclosures 4.1 Unit Startup 4.2 Unit Shutdown 4.3 Securing From LTOP Prior To 350°F 4.4 Dedicated LTOP Operator Guidelines 4.5 LTOP Vent Paths 4.6 1HP-120 Travel Stop Removal 4.7 LTOP Computer Points 4.8 LTOP Pressure Instruments 4.9 LTOP RCS Pressure High Alarm Logic (Channel 1) 4.10 LTOP RCS Pressure High Alarm Logic (Channel 2) 4.11 LTOP Pzr Level High Alarm Logic (Channel 1) 4.12 LTOP Pzr Level High Alarm Logic (Channel 2) 4.13 LTOP Requirements Logic Diagram 4.14 LTOP Travel Stop Schematic 4.15 Swapping LTOP Components 4.16 Establishing LTOP Administrative Controls 4.17 Removal Of LTOP White Tags 4.18 Securing From LTOP Prior To Mode 2 4.19 Appendix

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 1 of 11

1. Initial Conditions 1.1 Review Limits and Precautions.

2. Procedure NOTE: Enclosure 4.8 (LTOP Pressure Instruments) contains detailed information on acceptable pressure instruments to be used during LTOP conditions.

2.1 Prior to RxV Head installation perform Section 3 (LTOP Requir ements For RxV Head Installation).

2.2 Prior to closing RCS (no LTOP vent paths available), perform Section 4 (LTOP Requirements For Closing RCS (No LTOP Vent Paths Availa ble)).

2.3 Prior to HPI System Startup Or RCS> 100 psig, perform Sectio n 5 (LTOP Requirements For HPI System Startup Or RCS> 100 PSIG).

2.4 WHEN Enclosure (HPI System Startup) completed per OP/I/All 104/002 (HPI System),

perform Section 6 (LTOP Verification After HPI System Startup).

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 2 of 11

3. LTOP Requirements For RxV Head Installation NOTE: Steps 3.1 - 3.4 maybe performed in any order.

3.1 Verify LTOP vent path established per Enclosure 4.5 (LTOP Vent Paths):

(check vent path(s) credited)

O SG primary manway

[] SG primary handhole O Pzr manway 0 Pzr relief valve standpipe (valve removed) 3.2 Deactivate 1A CFT by performing Step 3.2.1 Step 3.2.2:

3.2.1 Perform the following:

A. Using CR indication, verify closed 1CF-i (1A CFT OUTLET).

B. Perform the following:

• White Tag Do Not Operate HW for 1CF-1 (1A CFT OUTLET)

(R-B under 1A CFT)

• White Tag open 1XO-F5C (1CF-1 Bkr (1A CFT Disch))

(T-3-Equip Rm) 3.2.2 Ensure 1A CFT <373 psig.

3.3 Deactivate lB CFT by performing Step 3.3.1 Step 3.3.2:

3.3.1 Perform the following:

A. Using CR indication, verify closed 1CF-2 (lB CFT OUTLET).

B. Perform the following:

• White Tag Do Not Operate HW for 1CF-2 (lB CFT OUTLET).

(R- 1 under 1 B CFT)

• White Tag open 1XP-F5C (1CF-2 Bkr (lB CFT Disch Isol)).

(T-3-Equip Rm) 3.3.2 Ensure lB CFT < 373 psig.

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 3 of 11 3.4 Ensure a minimum of two CETCs are available and in service. {8}

3.5 Return to Section 2 (Procedure).

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 4 of 11

4. LTOP Requirements For Closing RCS (No LTOP Vent Paths Available)

NOTE: Steps 4.1 - 4.3 may be performed in any order.

4.1 Verify one HPI train available as a makeup source from BWST SRO . {3}

4.2 Verify I&E has completed required PORV functional testing per IP/0/A10200/047 A (Reactor Coolant System LTOP Instrument Calibration) within previous 31 days.

1&E Contact Date NOTE:

• A dedicated LTOP Operator may NOT be used as a compensatory measure for convenience. LTOP Administrative Controls shall be established unless the associated condition CANNOT be met.

Steps 4.3.1 - 4.3.11 may be performed in any order.

4.3 Establish LTOP Administrative Controls as follows:

4.3.1 Perform one of the following:

A. Ensure White Tagged closed 1N-121 (Pzr High Pressure Supply).

(R-3G-East Side at stairs)

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 5 of 11 NOTE:

• Control of the following breakers may be temporarily trans ferred to IP/0/B/0200/05 1 B (Reactor Coolant Narrow Range Functional Test) while this IP is in progress.

• White Tagging open Pressurizer Heater Bank 3 is prefe rred to maximize Pzr heater capacity to establish a Pressurizer steam bubble. (Bank 3 has less heating capacity than Bank 4) {1i}

• A dedicated LTOP Operator may NOT be used as a com pensatory measure for convenience. LTOP Administrative Controls shall be established unless the associated condition CANNOT be met.

4.3.2 Perform one of the following:

A. Perform one of the following to tag a Pressurizer Heat er Bank:

1. IF desired to tag Pressurizer Heater Bank 3, perfo rm the following:

(A-4-402)

• White Tag open MCC 1XJ-3A (PZR Htr. Group G Bkr)

• White Tag open MCC 1XI-3A (PZR Htr. Group F Bkr)

• White Tag open MCC 1XH-3A (PZR Htr. Group E Bkr)

2. IF desired to tag Pressurizer Heater Bank 4, perform the following:

(A-4-402)

• White Tag open MCC 1XJ-4A (PZR Htr. Group J Bkr)

• White Tag open MCC 1XI-4A (PZR Htr. Group I Bkr)

• White Tag open MCC 1XH-.4A (PZR Htr. Group H Bkr)

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 6 of 11 NOTE: A dedicated LTOP Operator may NOT be used as a compensatory measure for convenience. LTOP Administrative Controls shall be establi shed unless the associated condition CANNOT be met.

4.3.3 Perform one of the following:

A. Verifi OAC operable.

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

NOTE: An INVALID input to LTOP may indicate LTOP Train 1 or Train 2 is inoperable, requiring entry into TS 3.4.12.

4.3.4 Perform one of the following:

A. Verify NOT in alarm computer point O1L3 153 (ONE OR MORE INPUTS TO LTOP iNVALID).

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

4.3.5 IF computer point O1L3 153 (ONE OR MORE INPUTS TO LTOP INVALID) is in alarm, perform the following:

A. Bring up the LTOP OAC screen and view computer point(s

) causing INVALID alarm.

B. Evaluate invalid LTOP computer points with LTOP points listed in Enclosure 4.7 (LTOP Computer Points) to determine which point(s) are NOT operable. {i0}

C. Take actions as necessary to return any inoperable points to service.

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 7 of ii NOTE: A dedicated LTOP Operator may NOT be used as a compe nsatory measure for convenience. LTOP Administrative Controls shall be establi shed unless the associated condition CANNOT be met.

4.3.6 1 SA- 1 8/A-3 RVLIS/ICCM/RG 1.97 Train A t Troubl e card pulled OR in alarm, perform of the following:

A. Verify the following Computer Point status: {7}

• Computer Point 01X2256 (PZR LEVEL 1 HI)

D Verify Quality = GOOD D Verify Value FALSE

• Computer Point 01 X2274 (PZR LEVEL 2 HI)

U Verify Quality = GOOD U Verify Value FALSE B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

4.3.7 IF 1SA-18/A-4 RVLIS/ICCM/RG 1.97 Train B Trouble card pulled alarm, perform one of the following: 2j in A. Verify the following Computer Point status: {7}

• Computer Point 01X2285 (PZR LEVEL 3 HI)

U Verify Quality GOOD U Verify Value = FALSE B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

4.3.8 Perform one of the following:

A. Verify RCS pressure/temperature is within limits of applicable Low Range Heatup curve.

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 8 of 11 NOTE: A dedicated LTOP Operator may NOT be used as a compe nsatory measure for convenience. LTOP Administrative Controls shall be establi shed unless the associated condition CANNOT be met.

4.3.9 Perform one of the following:

A. Verify Pzr level is within limits of Low Range Heatup curve.

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

4.3.10 Perform one of the following:

A. Verify 1SA-2/C-3 RC Pressurizer Level HighlLow Statala rm card NOT pulled AND NOT in alarm HIGH. {7}

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

4.3.11 Perform pç of the following:

A. Verify 1 SA-2/C-4 RC Pressurizer Level Emerg HighlLow Statala rm card NOT pulled AND NOT in alarm HIGH. {7}

B. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 9 of 11 4.4 WHEN all HPI testing required prior to closing RCS (no LTOP vent paths available) is completed, continue with the procedure.

NOTE: Major Steps 4.5 and 4.6 may be performed in any order.

4.5 Deactivate 1A HPI Train in preparation for HPI System startup by performing the following:

4.5.1 Using CR indication, verif, closed IHP-26 (1A HP INJECTION).

4.5.2 Perform the following:

• White Tag Do Not Operate HW for 1HP-26 (1A HP INJECTION)

(A-4-E-Pent)

• White Tag open 1XS1-F5E (1HP-26 Bkr (ES-i 1A HP Jnj))

(T-3-Equip Rm)

• White Tag closed CR switch for 1HP-409 (1HP

-27 BYPASS)

• White Tag closed CR switch for 1HP-410 (1HP

-26 BYPASS) 4.6 Deactivate 1 B HPI Train in preparation for HPI System startup by performing the following:

4.6.1 Using CR indication, verify closed 1HP-27 (lB HP INJECTION).

4.6.2 Perform the following:

• White Tag Do Not Operate HW for 1HP-27 (lB HP iNJECTION)

(A-4-W-Pent)

• White Tag open 1XS2-F3C (1HP-27 Bkr (ES-2 lB HP Inj))

(T-3-Equip Rm)

• White Tag closed CR switch for 1HP-409 (1HP

-27 BYPASS)

• White Tag closed CR switch for IHP-410 (1HP

-26 BYPASS) 4.7 Return to Section 2 (Procedure).

Enclosure 4.1 OP/i/A/i 104/049 Unit Startup Page 10 of ii

5. LTOP Requirements For HP! System Startup Or RCS> 100 PSIG NOTE:

• HPI Pump may be operated (for testing/CFT fill) prior to PORV being automatically operable if RCS vent capable of mitigating most limiting LTOP event established.

Steps 5.1.1 - 5.1.4 may be performed in any order.

5.1 Verify PORV automatically operable:

5.1.1 Verify open 1RC-4 (PZR RELIEF BLOCK).

5.1.2 Verify RC LR PRESS ENABLE switch selected to ON.

5.1.3 Verify PORV relief setting selected to LOW.

5.1.4 IF following a refueling outage, verify completed the following:

D IP/0/A10200/047 A (Reactor Coolant System LTOP Instrument Calibration)

D IP/0/B/0200/05 1 A (RC Narrow Range Pressure Instrument Calibration) 0 IP/0/B/0200/05 1 B (RC Narrow Range Pressure Functional Test).

I&E Contact Date 5.1.5 Verify complete PT/1/A/020 1/004 (1 RC-66 Stroke Test).

NOTE: Dedicated LTOP operator required until setup of 1HP-120 Travel Stop is completed per OP/i/A/i 104/002 (HPI System).

5.2 Ensure established a dedicated LTOP operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines due to 1HP-120 Travel Stop NOT being set.

5.3 Return to Section 2 (Procedure).

Enciosure 4.1 OP/i/A/i 104/049 Unit Startup Page 11 of 11

6. LTOP Verification After HPI System Start up NOTE: A dedicated LTOP Operator may NOT be used as a compensatory measure for convenience. LTOP Administrative Controls shall be established unless the associated condition CANNOT be met.

6.1 Perform one of the following:

6.1.1 Ensure complete PT/l/A/0202/014 (Setup Of 1HP

-i20 Travel Stop).

6.1.2 Ensure established a dedicated LTOP operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

6.2 Return to Section 2 (Procedure).

Enclosure 4.2 oP/i/All 104/049 Unit Shutdown Page 1 of 8

1. Initial Conditions 1.1 Review Limits and Precautions.

NOTE: Enclosure 4.8 (LTOP Pressure Instruments) contains detailed inform ation on acceptable pressure instruments to be used during LTOP conditions.

2. Procedure NOTE:

• Steps 2.1, 2.2, 2.3 and 2.4 may be performed in any order.

• Steps 2.1.1 through 2.1.4 may be performed in any order.

• Steps should be begun early enough to prevent unnecessary holds during unit shutdown.

2.1 Prior to py RCS Cold Leg 325°F, perform the following:

2.1.1 Verify I&E has completed required PORV functional testing per IP/0/A10200/047 A (Reactor Coolant System LTOP Instrument Calibration) within previous 31 days.

I&E Contact Date 2.1.2 Tag the following in preparation for CF Tank deactivation:

• White Tag Do Not Operate HW for 1CF-1 (1A CFT OUTLET)

(R-B under 1 A CFT)

• White Tag Do Not Operate HW for 1CF-2 (lB CFT OUTLET)

(R- 1 under 1 B CFT) 2.1.3 Tag the following in preparation for HPI deactivation:

• White Tag Do Not Operate HW for 1HP-26 (1A HP INJECTION)

(A-4-E Pent)

• White Tag Do Not Operate HW for 1HP-27 (lB HP INJECTION)

(A-4 W-Pent)

Enclosure 4.2 oP/i/A/i 104/049 Unit Shutdown Page 2 of 8 2.1.4 Tag the following in preparation for establishing LTOP Admin istrative Controls:

A. White Tag closed 1N-121 (Pzr High Pressure Supply

). (R-3G East Side at stairs)

NOTE:

• Control of the following breakers may be temporarily transfe rred to IP/0/B/0200/05 1 B (Reactor Coolant Narrow Range Functional Test) while this IP is in progress.

• White Tagging open Pressurizer Heater Bank 3 is preferred.

(Bank 3 has less heating capacity than Bank 4) { 11 }

B. Perform one of the following:

1. IF desired to tag Pressurizer Heater Bank 3, perform the follow ing:

(A-4-402)

• White Tag open MCC 1XJ-3A (PZR Htr. Group G Bkr)

• White Tag open MCC 1XI-3A (PZR Htr. Group F Bkr)

• White Tag open MCC 1XH-3A (PZR Htr. Group E Bkr)

2. IF desired to tag Pressurizer Heater Bank 4, perform the following:

(A-4-402)

• White Tag open MCC 1XJ-4A (PZR Htr. Group J Bkr)

• White Tag open MCC 1XI-4A (PZR Htr. Group I Bkr)

• White Tag open MCC 1XH-4A (PZR Htr. Group H Bkr)

Enclosure 4.2 OP/i/A/i 104/049 Unit Shutdown Page 3 of 8 2.2 After RCS < 800 psig, complete CF Tank deactivation by performing the follow ing:

2.2.1 Verify closed the following:

• 1CF-1 (1A CFT DISCH ISOL)

• 1CF-2 (lB CFT DISCH ISOL) 2.2.2 White Tag open the following: (T-3-Equip Rm)

• 1XO-F5C (1CF-1 Bkr (1A CFT Disch))

• 1XP-F5C (1CF-2 Bkr (lB CFT Disch Isol))

2.3 After RCS <350°F, complete HPI deactivation by performing the follow ing:

2.3.1 Verify closed the following:

• 1HP-26 (1A HP INJECTION)

• 1HP-27 (lB HP INJECTION) 2.3.2 White Tag open the following: (T-3-Equip Rm)

• 1XS1-F5E (1HP-26 Bkr (ES-i iA HP Inj))

• 1X52-F3C (1HP-27 Bkr (ES-2 lB HP Inj))

2.3.3 White Tag closed the following:

• CR switch for 1HP-409 (1HP-27 BYPASS)

• CR switch for 1HP-410 (1HP-26 BYPASS) 2.4 After RCS <600 psig AND RCS <350°F, initiate PT/1/A/0202/014 (Setup Of 1HP-120 Travel Stop).

Enclosure 4.2 OP/i/A/i 104/049 Unit Shutdown Page 4 of 8 2.5 WHEN RCS 345-325°F, perform the following.

NOTE:

• A dedicated LTOP Operator may NOT be used as a compensatory measure for convenience. LTOP Administrative Con trols shall be established unless the associated condition CANNOT be met.

• Steps 2.5.1A 2.5.1L maybe performed in any order.

2.5.1 Establish LTOP Administrative Controls as follows:

A. Perform one of the following:

1. Ensure White Tagged closed per Step 2.1 .4A 1 N-i 21 (Pzr High Pressure Supply). (R-3G, East side at stair s)

2. Ensure established a dedicated LTOP Oper ator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

NOTE:

• Control of the following breakers may be temp orarily transferred to IP/0/B/0200/05 1 B (Reactor Coolant Narrow Range Functional Test) while this IP is in progress.

• White Tagging open Pressurizer Heater Bank 3 is preferred. (Bank 3 has less heating capacity than Bank 4) {1 i}

B. Perform one of the following:

1. Verify one of the following White Tagged open per Step 2.1 .4B:

a. Pressurizer Heater Bank 3

b. Pressurizer Heater Bank 4

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guid eline s).

Enclosure 4.2 OP/i/A/i 104/049 Unit Shutdown Page 5 of 8 NOTE: A dedicated LTOP Operator may NO T be used as a compensatory measure convenience. LTOP Administrative for Controls shall be established unless the condition CANNOT be met. associated C. Perform one of the following:

1. Verify OAC operable.

2. Ensure established a dedicated LTOP Ope rator per Enclosure 4.4 (Dedicated LTOP Operato r Guidelines).

NOTE: An INVALID input to LTOP may indicat e LTOP Train 1 or Train 2 is inoperable requiring entry into TS 3.4.12. ,

D. Perform ç of the following:

1. Verify NOT in alarm computer point 01 L3 153 (ONE OR MORE INPUTS TO LTOP INVALID).

2. Ensure established a dedicated LTOP Ope rator per Enclosure 4.4 (Dedicated LTOP Operato r Guidelines).

E. jj computer point 01L3 153 (ONE OR MO RE INPUTS TO LTOP iNVALID) is in alarm, perform the followi ng:

1. Bring up the LTOP OAC screen and view computer point(s) causing INVALID alarm.

2. Evaluate invalid LTOP computer points wit h LTOP points listed in Enclosure 4.7 (LTOP Computer Points) to determine which point(s) are NOT operable. {10}

3. Take actions as necessary to return any ino perable points to service.

Enclosure 4.2 OP/i/All 104/049 Unit Shutdown Page 6 of 8 NOTE: A dedicated LTOP Operator may NOT be used as a compensatory measure for convenience. LTOP Administrative Controls shall be established unless the associated condition CANNOT be met.

F. IF 1SA-18/A-3 RVLIS/ICCM/RG 1.97 Train A Troubl

& card pulled OR in alarm, perform one of the following:

1. Verify the following Computer Point status: {7}

• Computer Point 01X2256 (PZR LEVEL 1 HI)

LI Verify Quality = GOOD LI Verify Value = FALSE

• Computer Point O1X2274 (PZR LEVEL 2 HI)

LI Verify Quality = GOOD LI Verify Value FALSE

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

G. 1SA-18/A-4 RVLIS/ICCM/RG 1.97 Train B Troub1e card pulled OR in alarm, perform one of the following:

1. Verify the following Computer Point status: {7}

• Computer Point O1X2285 (PZR LEVEL 3 HI)

LI Verify Quality = GOOD LI Verify Value = FALSE

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

H. Perform one of the following:

1. Verify RCS pressure/temperature is within limits of appl icable Low Range CooldownlHeatup curve.

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guideline s).

Enclosure 4.2 OP/i/A/i 104/049 Unit Shutdown Page 7 of 8 NOTE: A dedicated LTOP Operator may NOT be used as a compensatory measu re for convenience. LTOP Administrative Controls shall be established unless the associated condition CANNOT be met.

I. Perform one of the following:

1. Verify Pzr level is within limits of applicable Low Range CooldownlHeatup curve.

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

J. Perform ç of the following:

1. Verify 1 SA-2/C-3 RC Pressurizer Level HighJLow Statalarm card NOT pulled AND NOT in alarm HIGH. {7}

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

K. Perform one of the following:

1. Verify 1 SA-2/C-4 RC Pressurizer Level Emerg HighlLow Statalarm card NOT pulled AND NOT in alarm HIGH. {7}

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

L. Perform one of the following:

1. Ensure PT/1/A/0202/014 (Setup Of 1HP-120 Travel Stop) complete.

2. Ensure established a dedicated LTOP Operator per Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

Enclosure 4.2 OP/i/A/i 104/049 Unit Shutdown Page 8 of 8 2.6 WHEN RCS 475-450 psig and 345-325° F, perform the following.

2.6.1 Verify PORV automatically operable:

• Verify open 1 RC-4 (PZR RELIEF BLOCK)

• Verify RC LR PRESS ENABLE switch is selected to ONe

• Verify PORV relief setting selected to LO W.

2.7 Verify LTOP established per Enclosure 4.13 (LTOP Requirements Logic Diagram).

2.8 Continue Unit shutdown per OP/1/A/1102/0l0 (Controlling Procedure For Unit Shutdown).

2.9 j Unit shutdown is for refueling:

2.9.1 Contact OWPG Coordinator as to whether equi pment White Tagged for LTOP purposes will need to have LTOP White Tags cleared.

2.9.2 IF LTOP White Tags need to be cleared, Go To Enclosure 4.17 (Removal Of LTOP White Tags).

Enclosure 4.3 OP/i/A/i 104/049 Securing From LTOP Prior to 350°F Page 1 of 2

1. Initial Conditions 1.1 Review Limits and Precautions.

1.2 Verify RCS Temperature is > 325°F.

2. Procedure NOTE: Steps 2.1 - 2.3 may be performed in any order.

2.1 Ensure following LTOP White Tags removed:

• 1TC-09 Bkr (1A HPI Pump) (T-3-K26)

• 1TE-09 Bkr (lB HPI Pump) (T-3-K23)

• 1TD-09 Bkr (1C HPI Pump) (T-3-K25)

• 1XS1-F5E (1HP-26 Bkr (ES-l 1A HP Inj)) (T-3-Equ ip Rm)

• 1XS2-F3C (1HP-27 Bkr (ES-2 lB HP lnj)) (T-3

-Equip Rm)

• 1XO-F5C (1CF-l Bkr (1A CFT Dischl)) (T-3-Equ ip Rm)

• 1XP-F5C (1CF-2 Bkr (lB CFT Disch Isol)) (T-3-Equ ip Rm)

• 1HP-409 (1HP-27 BYPASS) switch

• 1HP-410 (1HP-26 BYPASS) switch (CONTINUED ON NEXT PAGE)

Enclosure 4.3 OP/i/A/i 104/049 Securing From LTOP Prior to 350°F Page 2 of 2 2.2 IF required, remove LTOP White Tags AND close the following Pressurizer Heater breakers:

• MCC 1XJ-3A (PZR Htr. Group G Bkr) (A-4

-402)

• MCC 1XI-3A (PZR Htr. Group F Bkr) (A-4-402

)

• MCC 1XH-3A (PZR Htr. Group E Bkr) (A-4-402

)

• MCC 1XJ-4A (PZR Htr. Group J Bkr) (A-4-402

)

• MCC 1XI-4A (PZR Htr. Group I Bkr) (A-4-402

)

• MCC 1XH-4A (PZR Htr. Group H Bkr) (A-4

-402) 2.3 Begin Enclosure 4.18 (Securing From LTOP Prio r To Mode 2).

Enclosure 4.4 OP/i/A/i 104/049 Dedicated LTOP Operator Guideline s Page 1 of 6

1. Initial Conditions NOTE:

• The OATC may fulfill the duties of the LTOP Operator.

• Enclosure 4.8 (LTOP Pressure Instruments) contains detailed information on acceptable pressure instruments to be used during LTOP conditions.

• A dedicated LTOP Operator may NOT be used as a compensatory measure for convenience.

1.1 Verif, one or more of the conditions in SRO Enclosure 4.16 (Establishing LTOP Administrative Controls) CANNOT be met.

2. Procedure NOTE: The following step is intended as an Oper ator aid to track conditions NOT met that require establishing LTOP Operator. Conditio ns may be added/deleted by one-lining as necessary.

2.1 IF desired, list conditions that require estab lishing of LTOP Operator (may use Enclosure/Step number if applicable):

2.2 Perform the following:

2.2.1 Designate an RO or SRO as dedicated LTO P Operator.

2.2.2 LTOP Operator review Limits and Precautio ns.

2.2.3 LTOP Operator review Section 3 of this enclo sure.

2.3 EnterTS3.4.l2ConditionF. {5}

2.4 LTOP Operator performs surveillance as requ ired by Section 4.

2.5 WHEN LTOP Operator is no longer requ ired, exit TS 3.4.12 Condition F.

Enclosure 4.4 OP/i/A/i 104/049 Dedicated LTOP Operator Guidelines Page 2 of 6

3. Dedicated LTOP Operator responsibilities:

• Prevent low temperature overpressurization.

• Monitor and control RCS temperature, pressure, inventory, and Reactor power.

• Dedicated LTOP Operator shall NOT make log entries use the telephone.

• Ensure a new LTOP Operator has reviewed this entire proced ure prior to turning over LTOP responsibility.

Enclosure 4.4 OP/i/A/l 104/049 Dedicated LTOP Operator Guidelines Page 3 of 6

4. Surveillance Requirements:

4.1 IF available, monitor LTOP computer points via the LTOP OAC screen.

NOTE:

• Trending the following points alerts LTOP Operator of potential problems relating to RCS pressure or RCS pressure instruments. {2}

Prior to relaxing Dedicated LTOP Operator requirem ents, computer points 01A2004 (RC LR PRESS (TRAIN A)) and O1A2235 (RC LR PRESS TRAIN B))

must be operable as defined by Limits And Precautio ns Step 2.10. {10}

4.2 IF available, trend LR Cooldown RCS Pressure points O1A2004 and O1A2235 to verify the points track together.

4.3 IF either RC LR PRESS TRAIN A/B is unavailable, trend the operable computer point and one of the RCS Wide Range pressure points (01A 1416, 01A1417, or O1A1418) to verify the points track together.

4.4 Monitor the following indications to detect excessive makeu p flow due to 1HP-120 (RC VOLUME CONTROL) failing open:

• RCS Pressure.

• RCSMakeupFlow.

• Pzr Level.

Enclosure 4.4 OP/i/A/i 104/049 Dedicated LTOP Operator Guidelines Page 4 of 6 4.5 excessive RCS makeup flow is indicated due to failing open of 1HP-1 20 (RC VOLUME CONTROL):

4.5.1 Start lB HPI Pump.

4.5.2 Verify proper pump parameters.

4.5.3 Stop 1A HPI Pump.

4.5.4 Close 1HP-i 15 (1A & lB HPIPs DISCH XCONN).

4.5.5 IF 1HP-i 15 (1A & lB HPIPs DISCH XCONN) fails to close, stop HPI Pumps, as required, to prevent exceeding IRC-66 (PORV) setpoint and RCS P/T Limits.

4.5.6 Refer to the following, as applicable:

• AP/1/A/1700/014 (Loss of Normal HPI Makeup And/Or RCP Seal Injection)

• AP/1/A/1700/016 (Abnormal Reactor Coolant Pump Operation).

4.6 IF PORV fails to open automatically at 530 psig, perform the following:

4.6.1 Verify open 1RC-4 (PZR RELIEF BLOCK).

4.6.2 Open 1RC-66 (PORV).

Enclosure 4.4 oP/i/A/i 104/049 Dedicated LTOP Operator Guidelines Page 5 of 6 CAUTION: If the restrictions for RCS pressure or Pzr level are exceeded, the heatup/cooldown will be stopped and acceptable RCS pressure and/or pzr level established within one hour.

NOTE: 1. Low Range Heatup/Cooldown curves are located in OP/0/A I1 108/001 (Curves and General Information).

2. RCS temperature is defined as:

• Lowest indicated WR Tc with RCPs on.

. LPI cooler outlet temperature with RCPs off.

3. RCS pressure is defined as RC LR PRESS TRAiN A/B instrument reading.

4.7 Verify RCS pressure within the following limits:

4.7.1 WHEN RCS > 220°F and < 325°F, verify RCS <525 psig.

4.7.2 WHEN RCS <220°F, verify RCS <375 psig.

4.8 Verify the following Pzr level restrictions are maintained:

4.8.1 WHEN RCS 100 psig and <160°F, AND No HPI pumps operating, AND RCS loops NOT water solid, verify Pzr level 380 inches.

4.8.2 WHEN RCS 100 psig and 220°F with EITHER:

HPI pump(s) operating, OR RCS loops water solid (loops filled and vented),

verify Pzr level <310 inches.

4.8.3 WHEN RCS> 100 psig and 325°F, verify Pzr level 220 inches.

Enclosure 4.4 OP/i/A/i 104/049 Dedicated LTOP Operator Guidelines Page 6 of 6 NOTE: An INVALID input to LTOP may indicate LTOP Train 1 or Train 2 is inoper able, requiring entry into TS 3.4.12.

4.9 IF computer point 01L3 153 (ONE OR MORE INPUTS TO LTOP iNVAL ID) is in alarm, perfonu the following:

4.9.1 Bring up the LTOP OAC screen and view computer point(s) causing INVALID alarm.

4.9.2 Evaluate invalid LTOP computer points with LTOP points listed in Enclosure 4.7 (LTOP Computer Points) to detenuine which point(s

) are NOT operable. {i0}

4.9.3 Take actions as necessary to return any inoperable points to service

Enclosure 4.5 OP/i/A/i 104/049 LTOP Vent Paths Page 1 of2 NOTE:

• Relief flow paths, other than those listed below, may be used.

. Alternate paths must be analyzed by Safety Analysis Group prj.Qr to use.

1. Initial Conditions 1.1 Review Limits and Precautions.

2. Procedure 2.1 If any of the following conditions exist, LTOP restrictio ns are satisfied:

• Reactor vessel head removed

• SG primary manway removed

• Pzr manway removed.

2.2 The following is a list of approved LTOP vent paths and flow area sizes. Should it be necessary to establish an LTOP vent path, use one of the following options:

• SG primary manway. (flow area 201 square inches)

• SG primary handhole. (flow area = 28.3 square inches) per handhole

• Pzr manway. (flow area 201 square inches)

• Pzr relief valve standpipe (valve removed). (flow area 3.6 square inches) per standpipe (PORV or either Code relief valve)

• Reactor vessel head removed.

2.3 Acceptable HPI System testing vent paths (requires 3.6 square inch area):

• Pzr relief valve standpipe (valve removed). (flow area 3.6 square inches) per standpipe for PORV or either Code relief valve

• SG primary manway. (flow area = 201 square inches)

• SG primary handhole. (flow area = 28.3 square inches

) per handhole

• Pzr manway. (flow area = 201 square inches)

• Reactor vessel head removed.

Enclosure 4.5 OP/i/A/i 104/049 LTOP Vent Paths Page 2 of 2 2.4 Acceptable CF System testing vent paths (requires 201 square inch area):

• SG primary manway. (flow area 201 square inches)

• Pzr manway. (flow area = 201 square inches)

• Reactor vessel head removed.

Enclosure 4.6 oP/i/Au 104/049 1HP-120 Travel Stop Removal Page 1 of 1

1. Initial Conditions 1.1 Review Limits and Precautions.

2. Procedure 2.1 Establish communications between Control Room personnel at 1HP-120 (RC VOLUME CONTROL).

NOTE: Enclosure 4.14 (LTOP Travel Stop Schematic) may be referred to for positions of LTOP travel stop in the set and disengaged positions, and for wrench size needed.

2.2 Adjust 1HP-120 (RC VOLUME CONTROL) dem and to verify 1HP-120 actuator/stem coupling NOT in contact with 1HP-120 travel stop plate.

2.3 Loosen upper two hex nuts.

2.4 Adjust upper two hex nuts until they are at the full up position and contacting the actuator base.

2.5 Adjust lower two hex nuts until travel stop plate contac ts the upper hex nuts.

2.6 Tighten the lower hex nuts.

NOTE: Too rapid stroke of 1HP-120 will cause start of standb y HPI Pump due to low RCP seal injection flow.

2.7 Perform a full stroke of 1HP-120 (RC VOLUME CONT ROL) to verify travel stop is disengaged.

2.8 Set letdown flow as required per OP/i/A/i 103/04 (Solub le Poison Control).

2.9 Delete note from Unit 1 Turnover Sheet regarding 1HP-1 20 travel stop.

Enclosure 4.7 OP/i/A/i 104/049 LTOP Computer Points Page 1 of 2 NOTE: To be considered OPERABLE, a com puter points Value must represent actual conditions and the point Quality MUST indic plant ate one of the following:

• GOOD

• INHB

• LALM

• HALM

• LOLO

• HIHI

• ALM

• DALM Points Associated With LTOP Train 1

LI 01A2004 RC LR PRESS (TRAIN A) {10}

LI O1D2605 RC LR PRESS TRANS POW ER LOSS (TRAIN A)

Points Associated With LTOP Train 2

LI O1A2235 RC LR PRESS (TRAIN B)

LI O1D2979 RC LR PRESS TRANS PO WER LOSS (TRAIN B)

LI O1D2125 HPI PUMP 1A LI O1D2127 HPI PUMP lB LI 01D2129-HPIPUMP 1C LI 01E2046 RC COLD LEG Al WR TEM P

LI O1E2044 RC COLD LEG A2 WR TEM P

LI O1E2017-RCCOLDLEGB1 WRTEM P

LI 01E2040 RC COLD LEG B2 WR TEM P

LI O1E2275 RC PZR LEVEL 1 TEMP CORREC TED LI 01E2276 RC PZR LEVEL 2 TEMP COR RECTED LI O1E2277 RC PZR LEVEL 3 TEMP COR RECTED LI O1L3 154 LTOP-RCS PRESSURE HIGH (CHANNEL 1)

LI O1L3 169 LTOP-RCS PRESSURE HIG H (CHANNEL 2)

LI O1L3 156 LTOP PZR LEVEL HIGH (CHANNEL 1)

LI 01L3 168 LTOP PZR LEVEL HIGH (CHANNEL 2)

LI 01E2171 NNI STAR MODULE RCO 6 110 ERROR

Enclosure 4.7 OP/i/A/i 104/049 LTOP Computer Points Page 2 of 2 Points Associated With Both LTOP Trains El 01D2978 RC LR PRESS ENABLE SWITCH El 01L3 155 LTOP SYSTEM DISABLED El 01L3 153- ONE OR MORE INPUTS TO LTOP INVALID

Enclosure 4.8 OP/i/A/i 104/049 LTOP Pressure Instruments {2}

Page 1 of 1 General Information

1. LTOP computer point 01 L3 153 (One Or More Inputs To LTOP Invalid) continu monitors all computer points that have inpu ously t to various LTOP control and alarm functions. If this alarm is received, steps shall be taken immediately to determine impa on LTOP System operability and compens ct atory actions required.

2. There are two independent trains of LR Cooldown RCS Pressure instrumentation:

A. RC LR PRESS TRAIN A provides input to the PORV (LTOP Train 1) lift setpo and to the LTOP alarm logic. These alarm int s (OAC computer points 0 1L3 154 and 01L3 156) are non-credited backup RCS high pressure and Pzr level alarms.

• IF RC LR PRESS TRAIN A becomes inop erable, the PORV will be inoperable and Condition D of TS 3.4.12 will apply.

B. RC LR PRESS TRAIN B provides input to the LTOP alarm logic (LTOP Train 2) that is a part of the Administrative Controls that assure that 10 minutes are available for operator action to mitigate an LTOP even

t. These alarms (OAC computer points 01 L3 169 and 01 L3 168) are the credited alarms in the LTOP analysis.

• IF RC LR PRES S TRAIN B becomes inoperable, computer point 01 L3 (One Or More Inputs To LTOP Invalid) shou 153 ld come into alarm, indicating this path is unavailable on Enclosure 4.13 (LTO P Requirements Logic Diagram). A dedicated LTOP operator shall be establishe d per Condition F of TS 3.4.12 unless a LTOP vent is established.

Enclosure 4.9 LTOP RCS Pressure High Alarm OP/i/All 104/049 Logic (Channel 1)

Page 1 of I Cold Leg Temp> 220° F Cold Leg Temp <= 325° F RCS Pressure > 525 psig LTOP RCS Pressure High (Channel 1) 01L3154 Cold Leg Temp < 2200 F RCS Pressure > 375 psig LTOP Computer Point tnputs Turn uo code LTOP L

Cold Leg Temp = Lowerl Indicated RCS Cold Leg Ternprruluro 0lE2O46 RC COLD LEO Al WRTE MP 011i2044 RC COLD LEG A2 WR TEMP 01H2017 SC COLDLIiGBIWRT hMP 01E2040 RC COLD LEO B2 WR TEMP RCS Pressure OlA2llO4 SC LR PRESS (TRAI N A)

IPRI1SSRI Rnv5.DI3S 412/08 SIR

Enclosure 4.10 LTOP RCS Pressure High Alarm Logic (Channel 2) op/i/A/i 104/049 Page 1 of I Cold Leg Temp > 220° F Cold Leg Temp <= 325° F RCS Pressure >= 525 psig LTOP -

RCS Pressure High (Channel 2)

OiL 3169 Cold Leg Temp <= 220° F RCS Pressure >= 375 psig 10pu15 Cold Leg Temp Lowest htdicated RCS Cold Leg Tempemtwe 01E2046 RC COLD LEGAl WRTEMP 01 E2044 EC COLD LEG A2 WR TEMP O1E2ol7 EC C0LDLpGBlWRTh 01E2040 RC COLD LEG 82 WRTEMP RCS PressLIre=O1A2235 RC LkPRESS(Tp,O1NB)

IPRES5R2 Rev 3.DES 4/2108 RTR

Enclosure 4.11 OP/i/A/i 104/049 LTOP Pzr Level High Alarm Logic (Channel 1)

Page 1 of 1 A HPI Pump On B HP! Pump On C HP! Pump On RCS Pressure> 100 psig LTOP -

RCS Te < 325F PZR LVL HIGH (Channel 1)

Pressurizer Level > 225 in 01 L3 156 Pressurizer Level Highest Indicated Level lIP! Pump Status 01112275 RC PZR LVL I TEMP CORE OlD2I25 HPI PUMP IA 01 E2276 EC PZE LVL 2 TEMP CORR 011)2127 I-1PI PUMp lB 01112277 RC PZE LVL 3 TEMp CORE 01D2129 HplpUMpIC Cold Lug Temp Lowest Indicated RCS Cold Leg Tempemtnee 01112046 ECCOLD LEGAl WE TEMP 01E2044 RC COLD LEG A2 WE TEMP 01112017 EC COLD LEG RI WE TEMP 01112040 EC COLD LEO 132 WE TEMP IPRIOGtct Res2 DES 4258 RTtr ECS Pressure OlA2Og4 EC LE PRESS (TRAIN A)

Enclosure 4.12 oP/i/A]! 104/049 LTOP Pzr Level High Alarm Logic (Channel 2)

Page 1 of 1 A HPI Pump On B HPI Pump On C HPI Pump On RCS Pressure> 100 psig LTOP -

RCS Tc325 F

5 PZR LVL HIGH (Channel 2)

Pressurizer Level >

01L3 168 225 in rCnnrputcr Point Inputs Turn on code: LTOP

[

Pressurizer Level = Highest Indicated Level I-tPt Pump Status 0102275 RCPZRLVL I TEMP CORR 0102125 HP! PUMP IA 0102276 RC PZR LVL 2 TEMP CORR 0102127 HPtPUMPIB 0102277 RC PZR LVL 3 TEMP CORR 0102129 tIPt PUMP IC Cold Leg Tcnsp Lowest Indicated RCS Cold Leg Temporature 0102046 RC COLD LEGAl WRTEMP 0102044 RC COLD LEG A2 WE TEMP 0102017 RC COLD LEO RI WRTEMP 0tE2040 ECCOLD LEG 02 WE TEMP IPZRLOOIC2 Rev 3.01/S 4/>08 RTR RCS Pressure = 01A2235 RC US. PRESS (TRAIN B)

Enclosure 4.13 oP/i/All 104/049 LTOP Requirements Logic Diagram Page 1 of I RC-4 Open PORV Ai,to Ope able PORV RereovJ.__.

.._..____ Performed By RCS V 100 prig HPI NOT Operating LTOPTRAIN1 Date/lime LTOP TRAIN 2

• IA& HPIP: rashe:nrdor in test ned tagged IHP-26 closed/handwheel lagged and bkr lagged open r 1 Rh-dOg CR switch tagged closed von 1HP-410 CR switch lagged closed PZr relief slandpipe (valve removed) or greater Vent path established 9C HPIP bkr racked nut or in test, and tagged 1HP-27 nlnsed/handwheel lagged and bkr tagged open [TOP UIP-409 CR snatch tagged closed Requirements 1 HP-410 CR switch lagged closed Satisfied 1CF-lClvsedl handwheel tagged aed bkr lagged open IA CFT depresssrized to n 373 pnig 1CF-2 dvsedlhandwheel lagged and bbr tagged open NOTE: Enc. 4.7 (LTOP Computer 15 CFT depressunzed to <373 psig Points) contains a list of points associated with LTOP operability.

HFI NOTi5 operation and aligned via IHP-12 1l-IP-120 Travel Stop Operable LTOP Computer point 01131 53 not in alarm 1SA-2)C-3. C-4 cards not pulled/vol in alarm HIOH 1SA-lg/A-3 card oat pulled/ovt in alarm Camp. p15. 0IX2256 AND O1X2274 Operable 1SA-Ig/A-4 card not pulled/not in alarm Camp. p1. 01x22g5 Operable OAC operable IN-121 Tagged Closed Ii Pzr Htr Bank 3 Dendivated Pzr I-/tm Bank 4 Deadr,aled RCS pressure withmn hefs 055 PZR level within limits 513 PrireamyManwayOff Oedicated LTOP Operator assigned Unit 1 LTOP Logic Rev. 22.des LTOP vent established O1LTOP0001.DES 08/20109 rtr If an RCS vent path is eslablisbed per Enclosure 4.5 (LTOP Vent Paths), this requirement corn be considered mel during HPI testing.

Enclosure 4.14 OP/i/A/i 104/049 LTOP Travel Stop Schematic Page 1 of I Note: L View rotated 90 degrees for clarity.

2. 1-1/4 open end wrench needed to adjust travel stop.

Actuator Base Upper Hex Nuts Travel Stop Plate Lower Hex Nuts L

Actuator Stem LEfH Actuator/Valve Coupling Valve Stem TRAVEL STOP DISENGAGED TRAVEL STOP SET HPl2Olock Rev. 3.TCW 3/7/02 rtr

Enclosure 4.15 oP/i/AR 104/049 Swapping LTOP Components Page 1 of 5

1. Initial Conditions 1.1 Review Limits and Precautions.

2. Procedure 2.1 IF desired swap LTOP Components for 1A HPI Train per Section 3 lA HPI Train 2.2 IF desired swap LTOP Components for lB HPI Train per Section 4 lB HPI Train 2.3 1E desired swap LTOP Components for 1A CFT per Section 5 IA CFT 2.4 j desired swap LTOP Components for 18 CFT per Section 6 lB CFT

Enclosure 4.15 oP/i/A/i 104/049 Swapping LTOP Components Page 2 of 5

3. lAilPiTrain 3.1 Deactivate 1A HPI Train by performing Step 3.1.1 or Step 3.1.2:

3.1.1 Perform the following:

A. Using CR indication, verify closed 1HP-26 (1A HP INJECTION).

B. White Tag Do Not Operate HW for 1HP-26 (1A HP Injection).

(A-4 E Pent)

C. Perform the following:

• White Tag open breaker 1XSI-F5E (1HP-26 Bkr (ES-i iA HP Inj))

(T-3-Equip Rm)

• White Tag closed CR switch for 1HP-409 (1HP

-27 BYPASS)

• White Tag closed CR switch for 1HP-410 (1HP

-26 BYPASS) 3.1.2 Ensure the following:

• White Tag Racked out or in TEST 1TC-09 Bkr (1A HPI Pump) (T-3-K26)

• White Tag Racked out or in TEST 1TE-09 Bkr (lB HPI Pump) (T-3-K23) 3.2 Attach this Enclosure to in-progress copy of this procedure.

Enclosure 4.15 OP/i/A/i 104/049 Swapping LTOP Components Page 3 of 5

4. lB HP! Train 4.1 Deactivate lB HPI Train byperforming Step 4.1.1 Step 4.1.2:

4.1.1 Perform the following:

A. Using CR indication, verify closed 1HP-27 (lB HP INJECTION).

B. White Tag Do Not Operate HW for 1HP-27 (lB HP Injection).

(A-4 W-Pent)

C. Perform the following:

• White Tag open breaker 1XS2-F3C (1HP-27 Bkr (ES-2 lB HP Inj))

(T-3-Equip Rrn)

• White Tag closed CR switch for 1HP-409 (1HP-27 BYPASS)

• White Tag closed CR switch for 1HP-410 (1HP-26 BYPASS) 4.1.2 Ensure White Tag Racked out or in TEST 1TD-09 Bkr (1C HPI Pump).

(T-3-K25) 4.2 Attach this Enclosure to in-progress copy of this procedure.

Enclosure 4.15 OP/i/A/i 104/049 Swapping LTOP Components Page 4 of 5

5. 1ACFT 5.1 Deactivate 1A CFT by perfonuing Step 5.1.1 Step 5.1.2:

5.1.1 Perform the following:

A. Using CR indication, verify closed 1CF-1 (1A CFT OUTLET).

B. White Tag Do Not Operate HW for 1CF-1 (1A CFT Outlet) (R-B under IA CFT)

C. White Tag open 1XO-F5C (1CF-1 Bkr (IA CFT Disc h)). (T-3-Equip Rm) 5.1.2 Ensure 1A CFT <373 psig 5.2 Attach this Enclosure to in-progress copy of this proc edure.

EncLosure 4.15 OP/i/A/i 104/049 Swapping LTOP Components Page 5 of 5

6. 1BCFT 6.1 Deactivate lB CFT byperforming Step 6.1.1 or Step 6.1.2:

6.1.1 Perform the following:

A. Using CR indication, verify closed 1CF-2 (lB CFT OUTLET).

B. White Tag Do Not Operate HW for 1CF-2 (lB CFT Outlet)

(R- 1 under I B CFT)

C. White Tag open 1XP-F5C (1CF-2 Bkr (lB CFT Disch Isol)). (T-3-Equip Rm) 6.1.2 Ensure lB CFT <373 psig.

6.2 Attach this Enclosure to in-progress copy of this procedure.

Enclosure 4.16 OP/i/A/i 104/049 Establishing LTOP Administrative Controls Page 1 of 2

1. Initial Conditions 1.1 Review Limits and Precautions.

2. Procedure NOTE: Steps2.1.1 -2.1.11 maybeperformedinanyorder.

2.1 Establish LTOP Administrative Controls as follows:

2.1.1 Verify OAC operable.

NOTE: An INVALID input to LTOP may indicate LTOP Train 1 or Train 2 is inoperable, requiring entry into TS 3.4.12.

2.1.2 Verify NOT in alarm computer point 01L3 153 (ONE OR MORE INPUTS TO LTOP INVALID).

2.1.3 IF 1SA-18/A-3 RVLIS/ICCM/RG 1.97 Train A Troubl& card pulled OR in alarm, verify the following Computer Point status: {7}

• Computer Point 01X2256 (PZR LEVEL 1 HI)

D Verify Quality = GOOD D Verify Value FALSE

• Computer Point O1X2274 (PZR LEVEL 2 HI)

D Verify Quality = GOOD U Verify Value = FALSE 2.1.4 IF ISA-18!A-4 RVLIS/ICCMJRG 1.97 Train B Trouble card pulled OR in alarm, verify the following Computer Point status: {7}

• Computer Point 01X2285 (PZR LEVEL 3 HI)

U Verify Quality = GOOD U Verify Value FALSE 2.1.5 Verify RCS pressure/temperature is within limits of applicable Low Range CooldownlHeatup curve.

Enclosure 4.16 OP/i/A/i 104/049 Establishing LTOP Administrative Controls Page 2 of 2 2.1.6 Verify Pzr level is within limits of applicable Low Range Cooldown/Heatup curve.

2.1.7 Verify I SA-2/C-3 RC Pressurizer Level HighlLow Statalarm card NOT pulled AND NOT in alarm HIGH. {7}

2.1.8 Verify 1 SA-2/C-4 RC Pressurizer Level Emerg HighlLow Statalarm card NOT pulled AND NOT in alarm HIGH. {7}

2.1.9 White Tag closed iN- 121 (Pzr High Pressure Supply) (R-3G, East side at stairs)

NOTE:

• Control of the following breakers may be temporarily transferred to IP/0/B/0200/05 1 B (Reactor Coolant Narrow Range Functional Test) while this IP is in progress.

• White Tagging open Pressurizer Heater Bank 3 is preferred. (Bank 3 has less heating capacity than Bank 4) {1i}

2.1.10 White Tag open one of the following Pressurizer Heater Banks:

A. IF desired, Pressurizer Heater Bank 3: (A-4-402)

• White Tag open MCC 1XJ-3A (PZR Htr. Group G Bkr)

• White Tag open MCC 1XI-3A (PZR Htr. Group F Bkr)

• White Tag open MCC 1XH-3A (PZR Htr. Group E Bkr)

B. IF desired, Pressurizer Heater Bank 4: (A-4-452)

• White Tag open MCC 1XJ-4A (PZR Htr. Group J Bkr)

• White Tag open MCC 1XI-4A (PZR Htr. Group I Bkr)

• White Tag open MCC 1XH-4A (PZR Htr. Group H Bkr)

NOTE: Travel stop operability or the dedicated LTOP operator is no longer required when all HPI pumps are secured.

2.1.11 IF an HPI pump is operating aligned to RCS via 1HP-120 (RC VOLUME CONTROL), ensure PT/1/A!0202/014 (Setup Of 1HP-120 Travel Stop) complete.

2.2 Verify LTOP Operator no longer required per Enclosure 4.13 (LTOP Requirements Logic Diagram).

2.3 Complete Enclosure 4.4 (Dedicated LTOP Operator Guidelines).

Enclosure 4.17 OP/i/A/i 104/049 Removal Of LTOP White Tags Page 1 of 2

1. Initial Conditions 1.1 Review Limits and Precautions.

1.2 LTOP restrictions are satisfied per one or more of the following:

SRO

• Reactor vessel head removed

• SG primary manway removed

• Pzr manway removed.

2. Procedure NOTE: 1. Any or all of the LTOP White Tags listed in Step 2.1 may be removed as requested by the OWPG Coordinator.

2. The following step removes only White Tags installed for LTOP, and does not reposition any plant equipment.

2.1 IF required, remove the following LTOP White Tags:

1TC-09 Bkr (1A HPI Pump) (T-3-K26)

• 1TE-09 Bkr (lB HPI Pump) (T-3-K23)

• 1TD-09 Bkr (1C HPI Pump) (T-3-K25)

• 1XS1-F5E (1HP-26 Bkr (ES-i 1A HP Inj)) (T-3-Equip Rm)

• 1HP-26 (iA HPI INJECTION) HW. (A-4 E-Pent)

• 1XS2-F3C (1HP-27 Bkr (ES-2 lB HP Inj)) (T-3-Equip Rm)

• 1HP-27 (lB HPI INJECTION) HW. (A-4 W-Pent)

• 1XO-F5C (1CF-1 Bkr (iA CFT Dischl)) (T-3-Equip Rm)

• 1CF-l (1A CFT OUTLET)HW. (R-B-under 1A CFT)

Enclosure 4.17 OP/i/A/i 104/049 Removal Of LTOP White Tags Page 2 of 2

• 1XP-F5C (1CF-2 Bkr (lB CFT Disch Isol)) (T-3-Equip Rm)

• ICF-2 (lB CFT OUTLET) HW. (R-1-under lB CFT)

• 1HP-409 (1HP-27 BYPASS) switch

• 1HP-410 (1HP-26 BYPASS) switch

• 1N-121 (Pzr High Pressure Supply). (R-3G East Side at stairs))

• MCC 1XJ-3A (PZR Htr. Group G Bkr) (A-4-402)

• MCC IXI-3A (PZR Htr. Group F Bkr) (A-4-402)

• MCC 1XH-3A (PZR Htr. Group E Bkr) (A-4-402).

• MCC 1XJ-4A (PZR Htr. Group J Bkr) (A-4-402)

• MCC 1XI-4A (PZR Htr. Group I Bkr) (A-4-402)

• MCC 1XH-4A (PZR Htr. Group H Bkr) (A-4-402)

Enclosure 4.18 oi1ii 104/049 Securing From LTOP Prior To MODE 2 Page 1 of 1

1. Initial Conditions 1.1 Review Limits and Precautions.

1.2 Verify RCS Temperature is > 325°F.

2. Procedure NOTE: Steps 2.1 - 2.2 may be perfonned simultaneously or in any order.

2.1 Disable 1HP-120 Travel Stop per Enclosure 4.6 (1HP-120 Travel Stop Removal).

2.2 Ensure following LTOP White Tags removed:

• 1HP-26 (1A HPI INJECTION) HW. (A-4 E-Pent)

• 1HP-27 (lB HPI INJECTION) HW. (A-4 W-Pent)

• 1CF-1 (IA CFT OUTLET) HW. (R-B-under 1A CFT)

• ICF-2 (lB CFT OUTLET) HW. (R-1-under lB CFT)

• 1N-121 (Pzr High Pressure Supply). (R-3G East Side at stairs))

Enclosure 4.19 OP/i/A/i 104/049 Appendix Page 1 of 1

1. Not used.

2. PIP 0-98-02552: Single failure of LR Cooldown RCS pressure instrument can affect both trains of LTOP. Compensatory measures have been taken to establish a second train of OAC alarms using a converted RCS NR pressure instrument. This instrument has been recalibrated to the same range as the RCS LR pressure instrument.

3. PIP 0-98-02532: Shutdown Protection Plan (Station Directive 1.3.5) requires an HPI pump to be available before closing the RCS where a vent equivalent to two SG handholes or one primary manway is NOT available.

4. PIP 0-01-00730 CA #1: Changes made to Enclosure 4.13 (LTOP Requirements Logic Diagram).

5. Steps revised in response to PIP 0-02-05552 CA #1.

6. PIP 0-03-025 19 CA #1: Revised Enclosure 4.13 (LTOP Requirements Logic Diagram).

7. PIP 0-03-05916 CA #1: Revised steps in Enclosure 4.1 (Unit Startup) and Enclosure 4.2 (Unit Shutdown) that verify Pzr LTOP Statalarm operability.

8. PIP 0-05-07538 CA #2: Step added to ensure CETCs available.

9. NOT used.

10. PIP 0-06-08576 CA #7: Steps added to ensure required LTOP RCS pressure computer points operable.

11. PIP 0-09-1897 CA #5: White Tagging Pressurizer Heater Bank 3 is preferred for LTOP. (Bank 3

has less heating capacity than Bank 4)

Admin-215 FS Page 1 of 7 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE Admin-21 5 Determine Tech Spec requirements for inoperable Pzr Heaters CANDIDATE EXAMINER

Admin-215 ES Page2of7 REGION II INITIAL LICENSE EXAMINATIO N

JOB PERFORMANCE MEASUR E

Task:

Determine Tech Spec requiremen ts for inoperable Pzr Heaters Alternate Path:

No Facility JPM #:

NEW KIA Rating(s):

System: GEN K/A: 2.2.40 Rating: 3.4/4.7 Task Standard:

Determine that minimum number of Pzr heaters for SSF operability Condition A must be entered. The are NOT operable and as a resu Required Action and Completion lt TS 3.10.1 Operable within 7 days. Time is to restore Station ASW sys tem to Preferred Evaluation Location:

Preferred Evaluation Method:

Simulator In-Plant Classroom X Perform X Simulate

References:

Technical Specifications Validation Time: 15 minutes Time Critical: NO Candidate:

Time Start:

NAME Time Finish:

Performance Rating: SAT UNSAT Performance Time:

Examiner:

NAME SIGNATURE DATE COMMENTS

Admin-215 FS Page 3 of 7 SIMULATOR OPERATOR INSTRUCTIONS:

None

Admin-215 FS Tools/Equipment/Procedure Page4of7 s Needed:

Technical Specifications READ TO OPERATOR DIRECTION TO TRAINEE:

I will explain the initial condit ions, and state the task to be steps shall be performed for performed. All control room this JPM, including any requir provide initiating cues and rep ed communications. I will orts on other actions when indicate to me when you un directed by you. Ensure you derstand your assigned task.

completed your assigned tas To indicate that you have k return the handout sheet I provided you.

INITIAL CONDITIONS:

Unit 2 is operating at 100%

power.

Pressurizer Steam Space Le akage 0.2 gpm Number of Bank 2 Pressurize r Heaters available = 16 INITIATING CUES:

The OSM directs you to:

1. Evaluate TS 3.10 (SSF) and determine if the required Pr essurizer heaters are operab le.

2. As a result of your evaluatio n above, document all applica Actions, and Completion Tim ble Conditions, Required es (if any) below.

Admin-215 ES Page 5 of 7 START TIME:

STEP 1: Candidate will evaluate Tech Spec requirements.

• Evaluate TS B 3.10.1 for Uni CRITICAL STEP t2 STANDARD: Determine that: SAT

• For Unit 2 the maximum allowed Pzr Steam Space Lea Pzr heaters available is 0.10 kage with 16 gpm.

UNSAT

• As a result the minimum num ber of Pzr heaters for SSF ope are NOT operable. rability COMMENTS:

STEP 2: Candidate will evaluate the Table on Page B 3.10.1-4.

CRITICAL STEP STANDARD: Determine that the SSF AS W system inoperable,

• TS 3.10.1 Condition A sho SAT uld be entered.

• Required Action and Complet ion Time is to restore Station system to Operable within 7 ASW UNSAT days Note: Although normally the SSF ASW System being ino of the SSF inoperable. Howeve perable would render ALL r in this case due to a not that is not true. If the SSF e at the bottom of the table ASW System is inoperabl 5SF systems are NOT inoper e due to Pzr heaters the oth able. er COMMENTS:

END TASK STOP TIME:

Admin-215 ES Page 6 of 7 CRITICAL STEP EXPLANATIO NS:

STEP #

Expanation I This step is required to determ ine if required SSF Pzr heaters are operabe 2 This step is required to ensure compliance with TSs

CANDIDATE CUE SHEET (TO BE RETURNED TO EXAM INER UPON COMPLETION OF TASK)

DIRECTION TO TRAINEE:

I will explain the initial conditions, and state the task to be performe steps shall be performed for thi d. All control room s JPM, including any required com provide initiating cues and report munications. I will s on other actions when direct indicate to me when you unders ed by you. Ensure you tand your assigned task. To ind completed your assigned task ret icate that you have urn the handout sheet I provided you.

INITIAL CONDITIONS:

Unit 2 is operating at 100% pow er.

Pressurizer Steam Space Leaka ge = 0.2 gpm Number of Bank 2 Pressurizer Heaters available = 16 INITIATING CUES:

The OSM directs you to:

1. Evaluate TS 3.10 (SSF) and determine if the required Pressu rizer heaters are operable.

2. As a result of your evaluatio n above, document all applica Actions, and Completion Times ble Conditions, Required (if any) below.

SSF 3.10.1 3.10 STANDBY SHUTDOWN FACILITY 3.10.1 Standby Shutdown Facility (SSF)

LCO 3.10.1 The SSF Instrumentation and the following SSF Systems shall be OPERABLE:

a. SSF Auxiliary Service Water System;

b. SSF Portable Pumping System;

c. SSF Reactor Coolant Makeup System; and

d. SSF Power System.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. SSF Auxiliary Service A.1 Restore SSF Auxiliary Water System 7 days Service Water System inoperable, to OPERABLE status.

B. SSF Portable Pumping B.1 Restore SSF Portable System inoperable. 7 days Pumping System to OPERABLE status.

(continued)

OCONEE UNITS 1,2, & 3 3.10.1-1 Amendment Nos. 300, 300, & 300

SSF 3.10.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. SSF Reactor Coolant C.1 Restore SSF Reactor 7 days Makeup System Coolant Makeup inoperable.

System to OPERABLE status.

D. SSF Power System D.1 Restore SSF Power 7 days inoperable.

System to OPERABLE status.

E. SSF Instrumentation E.1 Restore SSF 7 days inoperable.

Instrumentation to OPERABLE status.

F. Required Action and F.1 Restore to OPERABLE associated Completion NOTE status. Not to exceed 45 days Time of Condition A, B, C, D, or E not met cumulative per calendar when SSF Systems or year Instrumentation are inoperable due to maintenance, 45 days from discovery of initial inoperability G. Required Action and G.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition F not AND met.

G.2 Be in MODE 4.

OR 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> Required Action and associated Completion Time of Condition A, B, C, D, or E not met for reasons other than Condition F.

OCONEE UNITS 1,2, & 3 3.10.1-2 Amendment Nos. 300, 300, & 300

SSF 3.10.1 SURVEILLANCE REQUIREMENT S

SURVEILLANCE FREQUENCY SR 3.10.1.1 NOTE Not applicable to RCS temperatur e instrument channels.

Perform CHANNEL CHECK for eac h required 7 days SSF instrument channel.

SR 3.10.1.2 Verify required SSF battery term inal voltage is 7 days 125 VDC on float charge.

SR 3.10.1.3 Verify the day tank contains 200 gallons of 31 days fuel.

SR 3.10.1.4 Verify the underground oil storage tank 31 days contains 25,000 gallons of fuel.

SR 3.10.1.5 NOTE All DG starts may be preceded by an engine prelube period followed by a warmu p period prior to loading.

Verify the DG starts from standby con ditions 31 days and achieves steady state voltage and frequency.

SR 3.10.1.6 Verify DG required air start receiver pressure 31 days is 150 psig.

(continued)

OCONEE UNITS 1,2, & 3 3.10.1-3 Amendment Nos. 300, 300, & 300

SSF 3.10.1 SURVEILLANCE REQUIREMENT S (continued)

SURVEILLANCE FREQUENCY SR 3.10.1.7 Verify the fuel oil transfer system operates to 92 days automatically transfer fuel oil from the storage tank to the day tank.

SR 3.10.1.8 Verify the fuel oil properties of the fuel oil 92 days stored in the day tank and underg round storage tank are tested in accord ance with, and maintained within the limits of the Diesel Fuel Oil Testing Program.

SR 3.10.1.9 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. All DG starts may be preceded by an engine prelube period followed by a

warmup period prior to loading.

Verify the SSF DG is synchronized and 92 days loaded and operated for 60 minutes at a load 3280 kW.

SR 3.10.1.10 Verify for required SSF battery that the cells, 12 months cell plates and racks show no visu al indication of physical damage or abnormal dete rioration that could degrade battery performanc e.

(continued)

OCONEE UNITS 1,2, & 3 3.10.1-4 Amendment Nos. 331, 331, & 332 I

SSF 3.10.1 SURVEILLANCE REQUIRE MENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.1.1 1 Verify for required SSF batter y that the cell to 12 months cell and terminal connections are clean, tight and coated with anti-corrosion material.

SR 3.10.1.12 Verify battery capacity of req uired battery is 12 months adequate to supply, and maint ain in OPERABLE status, the requir ed maximum loads for the design duty cyc le when subjected to a battery service tes t.

SR 3.10.1.13 Perform CHANNEL CALIBRA TION for each 18 months required SSF instrument channe l.

SR 3.10.1.14 Verify OPERABILITY OF SSF valves in In accordance with the accordance with the Inservice Testing Inservice Testing Program.

Program SR 3.10.1.15 NOTE Not applicable to the SSF sub mersible pump.

Verify the developed head of each required In accordance with the SSF pump at the flow test point is greater Inservice Testing than or equal to the required dev eloped head. Program SR 3.10.1.16 Verify the developed head of the SSF 2 years submersible pump at the flow test point is greater than or equal to the req uired developed head.

OCONEE UNITS 1,2, & 3 3.10.1-5 Amendment Nos. 328, 328

& 329 I

SSF B 3.10 STANDBY SHUTDOWN FA 3.10.1 CILITY B 3.10.1 Standby Shutdown Facility (SSF)

BASES BACKGROUND The Standby Shutdown Facility (SS F) is designed as a standby system for use under certain emergency con ditions. The system provides additional defense in-depth pro tection for the health and safety of public by serving as a backup to exis the ting safety systems. The SSF is provided as an alternate means to achieve and maintain the unit in MODE 3 with average RCS temper ature 525°F (unless the initiating event causes the unit to be driven to a lower temperature) following CFR 50 Appendix R fire, sabotage, 10 turbine building flood, station blackou (SBO) and tornado missile events, t and is designed in accordance wit criteria associated with these events. h In that the SSF is a backup to existing safety systems, the sing le failure criterion is not required.

Failures in the SSF systems will not cause failures or inadvertent operations in other plant systems.

The SSF requires manual activati and can be activated if emergency on systems are not available.

The SSF is designed to maintain the reactor in a safe shutdown conditi for a period of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following on 10 CFR 50 Appendix R fire, turbine building flood, sabotage, SBO, or tornado missile events. This is accomplished by re-establishing and maintaining Reactor Coolant Pum Seal cooling; assuring natural circulat p ion and core cooling by maintainin the primary coolant system filled g to a sufficient level in the pressurize while maintaining sufficient second r ary side cooling water; and maintaining the reactor subcritical by isolating all sources of Reactor Coolant System (RCS) addition exc ept for the Reactor Coolant Makeu System which supplies makeup of p a sufficient boron concentration.

The main components of the SSF are the SSF Auxiliary Service Wa (ASW) System, SSF Portable Pum ter ping System, SSF Reactor Coolant (RC) Makeup System, SSF Power System, and SSF Instrumentation The SSF ASW System is a high hea d, high volume system designed to provide sufficient steam generator (SG) inventory for adequate decay heat removal for three units during a loss of normal AC power in conjunction with the loss of the nor mal and emergency feedwater systems. One motor driven SSF ASW pump, located in the SSF, serv all three units. The SSF ASW pum es p, two HVAC service water pumps, and the Diesel Service Water (DS W) pump share a common suction supply of lake water from the emb edded Unit 2 condenser circulating water (CCW) piping. The SSF DS W pump and an HVAC pump mu operable in order to satisfy the ope st be rability requirements for the Power System. (Only one HVAC service water pump is required to be ope to satisfy the LCO.) rable OCONEE UNITS 1, 2, & 3 B 3.10.1-1 BASES REVISION DATED 05/18/

10

SSF B 3.10.1 BASES BACKGROUND The SSF ASW System is used to provide (continued) adequate cooling to maintain single phase RCS natural circ ulation flow in MODE 3 with an average RCS temperature 525°F (unless the initiating event causes the unit to be driven to a lower temperature).

In order to maintain single phase RCS natural circulation flow, an adequate number of Bank 2, Group B and C pressurizer heaters must be OPERABLE. These heaters are needed to compensate for ambient heat loss from the pressurizer.

As long as the temperature in the pressu rizer is maintained, RCS pressure will also be maintained. This will preclude hot leg voiding and ensure adequate natural circulation cool ing.

The SSF Portable Pumping System, whic h includes a submersible pump and a flow path capable of taking suction from the intake canal and discharging into the Unit 2 CCW line, is designed to provide a backup supply of water to the SSF in the eve nt of loss of CCW and subsequent loss of CCW siphon flow. The SSF Por table Pumping System is installed manually according to procedures.

The SSF RC Makeup System is design ed to supply makeup to the RCS in the event that normal makeup sys tems are unavailable. An SSF RC Makeup Pump located in the Reactor Building of each unit supplies makeup to the RCS should the normal makeup system flow and seal cooling become unavailable. The system is designed to ensure that sufficient borated water is provided from the spent fuel pools to allow the SSF to maintain all three units in MOD E 3 with average RCS temperature 525°F (unless the initiating event cau ses the unit to be driven to a lower temperature) for approximately 72 hou rs. An SSF RC Makeup Pump is capable of delivering borated water from the Spent Fuel Pool to the RC pump seal injection lines. A portion of this seal injection flow is used to makeup for reactor coolant pump sea l leakage while the remainder flows into the RCS to makeup for other RC S leakage (non LOCA).

The SSF Power System provides elec trical isolation of SSF equipment from non-SSF equipment. The SSF Power System includes 4160 VAC, 600 VAC, 208 VAC, 120 VAC and 125 VDC power. It consists of switchgear, a load center, motor con trol centers, panelboards, remote starters, batteries, battery chargers, inverters, a diesel generator (DG),

relays, control devices, and interconne cting cable supplying the appropriate loads.

The AC power system consists of 416 0 V switchgear OTS1; 600 V load center OXSF; 600 V motor control cen ters XSF, 1XSF, 2XSF, 3XSF, PXSF; 208 V motor control centers 1XS F, 1XSF-1, 2XSF, 2XSF-1, 3XS 3XSF-1; 120 V panelboards KSF, KSF F, C.

000NEE UNITS 1, 2, & 3 B 3.10.1-2 BASES REVISION DATED 05/18/10

SSF B 3.10.1 BASES BACKGROUND The SSF 125 VDC Power Sy (continued) stem provides a reliable sou DC loads needed to black sta rce of power for rt the diesel. The DC power consists of two 125 VDC batter system ies and associated chargers, 125 VDC distribution centers two (DCSF, DCSF-1), and a DC pow panelboard (DCSF). Only one er battery and associated charge to be operable and connected r is required to the 125 VDC distribution cen supply the 125 VDC loads. ter to In this alignment, which is nor is floated on the distribution mal, the battery center and is available to ass without interruption upon los ure power s of its associated battery cha power source. The other 125 rger or AC VDC battery and its associate in a standby mode and are d charger are not normally connected to the distribution center. However 125 VDC

, they are available via manua the 125 VDC distribution cen l connection to ter to supply SSF loads, if req uired.

The SSF Power System is pro vided with standby power fro DG. The SSF DG and suppor m a dedicated t systems consists of the diesel fuel oil transfer system, air generator, start system, diesel engine ser system, as well as associate vice water d controls and instrumentatio DG is rated for continuous ope n. This SSF ration at 3500 kW, 0.8 pf, The SSF electrical design and 4160 VAC.

load does not exceed the con the DG. The auxiliaries requir tinuous rating of ed to assure proper operat DG are supplied entirely fro ion of the SSF m the SSF Power System.

provided with manual start The SSF DG is capability from the SSF only.

compressed air starting system It uses a with four air storage tanks.

independent fuel system, com An plete with a separate underg tank, duplex filter arrangement round storage

, a fuel oil transfer pump, is supplied for the DG. and a day tank, OCONEE UNITS 1, 2, & 3 B 3.10.1-3 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 BASES BACKGROUND The following information wil (continued) l aid in determination of SSF Operability:

Associated Inoperable Syste ms SSF SSF SSF SSF SSF ASW Portable RCMU Power Instruments System Pumping System System System SSF ASW a) System YES YES C., YES YES YES SSF Portable YES YES a) YES YES YES Cl) Pumping E SSF RCMU 0

System NO NO U- YES NO NO

-D SSF Power System YES YES

> YES YES YES 0 SSF Instr.

E System NO a) NO NO SSF PZR. NO YES E Heaters** YES G) NO NO NO 0 SSF RCS NO U)

Isolation NO NO YES NO NO Valves U) SSF HVAC U)

System YES YES YES YES YES When SSF pressurizer hea ters are inoperable, the res inoperability of the SSF AS ulting W System does NOT render systems inoperable. other SSF SSF ASW System Provides motive force for SSF ASW suction pipe air ejector is needed to maintain ejector. The air siphon flow to the SSF HV pump, the SSF DSW pump, AC service water and the SSF ASW pump wh level in the U2 CCW supply en the water pipe becomes too low. If pump becomes inoperable, the SSF DSW the SSF Power System wil inoperable. Since an inoper l become able SSF Power System SSF subsystems to be ino cau ses all other perable, an inoperable SS also cause other SSF Su F ASW System will bsystems to be inoperable.

Provides adequate SG coo ling to reduce & maintain the pressure where the SS RCS pressure below F RC makeup pump discha HP-404, begins to leak flow rge relief valve,

. Therefore, full SSF RC seal injection flow will be pro Makeup System vided to the RC pump sea prevent seal degradation ls in time to or failure.

000NEE UNITS 1, 2, &

3 B 3.10.1-4 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 BASES BACKGROUND SSF ASW pump should be operated whe (continued) n the diesel is operated to provide a load for the diesel. This is not a requirement for operability since the diesel could be operated to pro vide long term power to one or more units RC makeup pumps without ope rating the SSF ASW pump as long as a large load (SSF ASW pump )

is not added later (diesel desouping concern).

SSF Portable Pumping Supplies makeup water to the SSF AS W System, the SSF DSW System, and the SSF HVAC Service Water Sys tem after siphon flow I gravity flow and forced CCW flow are lost.

SSF Power System Other SSF Systems cannot operate wit hout receiving power from the diesel for SSF scenarios where power from U2 MFB is not available.

SSF Pressurizer Heaters Single phase RCS natural circulation flow cannot be maintained without the pressurizer heaters. The number of SSF heaters utilized is based on testing and calculations performed on a unit by unit basis to determine the minimum number of required hea ters needed to overcome actual pressurizer ambient losses. Since the heaters do not have their own action statement, the SSF ASW System is declared inoperable when the heaters are inoperable.

SSF RCS Isolation Valves (HP-3, HP

-4, HP-20, RC-4, RC-5, RC-6)

These valves do not have their own acti on statement. When they are inoperable, their corresponding SSF RC makeup system is considered inoperable.

SSF HVAC System Portions of the SSF HVAC System, con sisting of the SSF Air Conditioning (AC) and Ventilation Sys tems support the SSF Power System OPERABILITY. The SSF AC System, which includes the HVAC service water system and AC equipm ent (fan motors, compressors, condensers, and coils), must be ope rable to support SSF Power System operability. Since an inoperable SSF Power System results in all other SSF subsystems being inoperable, an SSF HVAC System operability problem that makes the SSF Power System inoperable also results in other SSF Subsystems being inoper able.

OCONEE UNITS 1, 2, & 3 B 3.10.1-5 BASES REVISION DATED 05/18/

10 I

SSF B 3.10.1 BASES BACKGROUND The SSF AC System is designed to maintain the (continued) SSF Control Room, Computer Room, and Battery Rooms within their design temperature range. Elevated temperatures in the SSF Control Room and Computer Room could cause the SSF Power System to fail during an accident which requires operation of the SSF. The SSF AC System consists of two refrigeration circuits and an air handling unit. The requirements for the refrigeration circuits vary with outdoor air temperatu re. Depending on outdoor air temperature and Air Conditioning Syst em performance, the two refrigeration circuits may not be required to supp ort SSF power system OPERABILITY. The air handling unit is required to circulate air regardless of the number of refrigeration circu its required. Since the SSF HVAC service water pumps perform a redundan t function, only one of the two are required to be operable for the SSF HVA C service water system to be considered operable. The SSF Ventilatio n System, which supplies outside air to the Switchgear, Pump, HVAC and Diesel Generator Rooms, is composed of the following four subsystem s: Constant Ventilation, Summer Ventilation, On-line Ventilatio n, and Diesel Generator Engine Ventilation. These ventilation systems work together to provide cooling to the various rooms of the SSF under both standby and on-line modes. The Diesel Generator Engine Ventilation fan is required for operability of the SSF Power System. The six fans associated with the other three ventilation systems may or may not be required for SSF operability dependent upon outside air temperatu re. If the SSF AC System refrigeration circuits or one of the vent ilation fans fail, an engineering evaluation must be performed to determine if any of the SSF Systems or instrumentation are inoperable.

SSF Instrumentation System SSF Instrumentation is provided to monitor RCS pressure, RCS Loop A and B temperature (hot leg and cold leg), press urizer water level, and SG A and B water level. Indication is displayed on the SSF control panel.

APPLICABLE The SSF serves as a backup for existing safet SAFETY ANALYSES provide an alternate and y systems to independent means to achieve and maintain one, two, or three Oconee units in MODE 3 with average RCS temperature 525°F (unless the initiating even t causes the unit to be driven to a lower temperature) for up to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following 10 CFR 50 Appendix R fire, a turbine building flood, sabo tage, SBO, or tornado missile events (Refs. 1,6, 7, and 8).

The OPERABILITY of the SSF is consistent with the assumptions of the Oconee Probabilistic Risk Assessment (Ref

. 2). Therefore, the SSF satisfies Criterion 4 of 10 CFR 50.36 (Ref.

3).

OCONEE UNITS 1, 2, & 3 B 3.10.1-6 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 BASES LCO The SSF Instrumentation in Table B 3.10.1-1 and the following SSF Systems shall be OPERABLE:

a. SSF Auxiliary Service Water System;

b. SSF Portable Pumping System;

c. SSF Reactor Coolant Makeup System; and

d. SSF Power System.

An OPERABLE SSF ASW System includes pressurize r heaters capable of being powered from the SSF, and an SSF ASW pum p, piping, instruments, and controls to ensure a flow path capable of taking suction from the Unit 2 condenser circulating water (CCW) line and discharging into the secondary side of each SG. The minimum num ber of pressurizer heaters capable of being powered from the SSF is base d on maintaining RCS natural circulation flow. The number of SSF cont rolled pressurizer heaters needed to meet this requirement is dependent upon ambient heat loss from the pressurizer and the steam leakage rate from the pressurizer. The following table provides combina tion of SSF controlled pressurizer heaters versus steam space leakage rates that have been previously determined to meet Operability requirements for the SSF.

This is based on an Oconee calculation, with additiona l margin to prevent frequent revision. Engineering Input is needed to deter mine if other combinations of pressurizer heaters versus steam space leakage rate are acceptable.

Unit 1 Number of Bank 2, Group B & C Maximum Allowed Pressurizer Pressurizer Heaters Available Steam Space Leakage 17 0.50 GPM 16 0.25 GPM 15 0.10 GPM 14 0.00 GPM Unit2 Number of Bank 2, Group B & C Maximum Allowed Pressurizer Pressurizer Heaters Available Steam Space Leakage 18 0.50 GPM 17 0.25 GPM 16 0.10 GPM 15 0.00 GPM OCONEE UNITS 1, 2, & 3 B 3.10.1-7 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 BASES LCO Unit 3 (continued) Number of Bank 2, Group B & C Maximum Allowed Pressurizer Pressurizer Heaters Available Steam Space Leakage 17 0.50 GPM 16 0.25 GPM 15 0.10 GPM 14 0.00 GPM An OPERABLE SSF Portable Pumping System includes an SSF submersible pump and a flow path capable of taking suction from the intake canal and discharging into the Unit 2 CCW line. An OPERABLE Reactor Coolant Makeup System includes an SSF RC Makeup pump, piping, instruments, and controls to ensure a flow path capable of taking suction from the spent fuel pool and discharging into the RCS. The following leakage limits are applicable for the SSF RC Makeup System to be considered OPERABLE:

Maximum Allowed Total Combined RCS Leakage for SSF RC Makeup System Operability The maximum allowed total combined RCS leakage is 24.7 GPM. A Units total combined RCS leakage shall be 24.7 GPM for its corresponding SSF RC Makeup System to be considered OPERABLE Total Combined RCS leakage is based on Total RCS Leakage Rate +

Quench Tank Level Increase + Total RC Pump Seal Return Flow. Total RC Pump Seal Return Flow is determined by summing the seal return flow rate for all four RC Pumps. If the seal return flow rate for a RC Pump is not available, 3.35 GPM may be used as the seal return flow rate for the affected pump. This worst case seal leakage occurs when two seal stages are failed with the third seal stage leaking maximum outflow to the leakage system.

An OPERABLE SSF Power System includes the SSF DG, diesel suppor t

systems, 4160 VAC, 600 VAC, 208 VAC, 120 VAC, and 125 VDC systems. Only one 125 VDC SSF battery and its associated charger are required to be OPERABLE to support OPERABILITY of the 125 VDC system.

OCONEE UNITS 1, 2, & 3 B 3.10.1-8 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 BASES (continued)

APPLICABILITY The SSF System is required in MODES 1, 2, and 3 to provide an alternate means to achieve and maintain the unit in MODE 3 with average RCS temperature 525°F (unless the initiating event causes the unit to be driven to a lower temperature) follo wing 10 CFR 50 Appendix R fire, turbine building flood, sabotage, SBO and tornado missile events.

The safety function of the SSF is to achie ve and maintain the unit in MODE 3 with average RCS temperature 525°F (unless the initiating event causes the unit to be driven to a lowe r temperature); therefore, this LCO is not applicable in MODES 4, 5, or 6.

ACTIONS The exception for LCO 3.0.4, provided in the Note of the Actions, permits entry into MODES 1, 2, and 3 with the SSF not OPERABLE. This is acceptable because the SSF is not required to support normal operation of the facility or to mitigate a design basis accid ent.

A.1, B.1, C.1, D.1, and E.1 With one or more of the SSF Systems inop erable or the required SSF instrumentation of Table B 3.10.1-1 inoperab le, the SSF is in a degraded condition and the system(s) or instrumentation must be restored to OPERABLE status within 7 days. The 7 day Completion Time is based on the low probability of an event occurring which would require the SSF to be utilized.

F. 1 If the Required Action and associated Com pletion Time of Condition A, B, C, D, or E are not met when SSF Systems or Instrumentation are inoperable due to maintenance, the unit may continue to operate provided that the SSF is restored to OPERAB LE status within 45 days from discovery of initial inoperability.

This Completion Time is modified by a Note that indicates that the SSF shall not be in Condition F for more than a total of 45 days in a calendar OCONEE UNITS 1, 2, & 3 B 3.10.1-9 BASES REVISION DATED 05/18/10

SSF B 3.10.1 BASES ACTIONS F.1 (continued) year. This includes the 7 day Completion Time that leads to entry into Condition F. For example, if the SSF ASW System is inoperable for 10 days, the 45 day special inoperability period is reduced to 35 days. If the SSF ASW System is inoperable for 6 days, Condition A applies and there is no reduction in the 45 day allowance. The limit of 45 days per calendar year minimizes the number and duration of extended outages associated with exceeding the 7 day Completion Time of a Condition.

G.1 and G.2 If the Required Action and associated Completion Time of Condition F are not met or if the Required Action and associated Completion Time of Condition A, B, C, D, or E are not met for reasons other than Condition F, 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 MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and MODE 4 within 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br />. The allowed Completion Times are appropriate, to reach the required unit conditions from full power conditions in an orderly manner and without challenging plant systems, considering a three unit shutdown may be required.

SURVEILLANCE SR 3.10.1.1 REQUIREMENTS Performance of the CHANNEL CHECK once every 7 days for each required instrumentation channel ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel with a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; therefore, it is key in verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. This SR is modified by a Note to indicate that it is not applicable to the SSF RCS temperature instrument channels, which are common to the RPS RCS temperature instrument channels and are normally aligned through a transfer isolation device to each Unit control room. The instrument string to the SSF control room is checked and calibrated every 18 months Agreement criteria are determined based on a combination of the channel instrument uncertainties, including indication and readability. If a OCONEE UNITS 1, 2, & 3 B 3.10.1-10 BASES REVISION DATED 05/18/10

SSF B 3.10.1 BASES SURVEILLANCE SR 3.10.1.1 (continued)

REQUIREMENTS channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. If the channels are within the criteria, it is an indication that the channels are OPERABLE. If the channels are normally off scale during times when surveillance is required, the CHANNEL CHECK will only verify that they are off scale in the same direction. Off scale low current loop channels are verified to be reading at the bottom of the range and not failed downscale.

The Frequency is based on unit operating experience that demonstrates channel failure is rare.

SR 3.10.1.2 Verifying battery terminal voltage while on float charge for the batteries 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 a 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 recommendations and IEEE-450 (Ref. 4).

SR 3.10.1.3 and 3.10.1.4 SR 3.10.1.3 provides verification that the level of fuel oil in the day tank is at or above the level at which fuel oil is automatically added. The level is expressed as an equivalent volume in gallons. The day tank is sized based on the amount of fuel oil required to successfully start the DG and to allow for orderly shutdown of the DG upon loss of fuel oil from the main storage tank.

SR 3.10i.4 provides verification that there is an adequate inventory of fuel oil in the storage tanks to support SSF DG operation for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> at full load. The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> period is sufficient time to place the unit in a safe shutdown condition The 31 day Frequency for these SRs is adequate to assure that a sufficient supply of fuel oil is available, since low level alarms are provided and unit operators would be aware of any large uses of fuel oil during this period.

OCONEE UNITS 1,2, &3 B 3.10.1-11 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 BASES SURVEILLANCE SR 3.10.1.5 REQUIREMENTS (continued) The SR requires the DG to start (normal or emergency) from standby conditions and achieve required voltage and frequency. Standby conditions for a DG means that the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations. This SR is modified by a Note to indicate that all DG starts for this Surveillance may be preceded by an engine prelube period and followed by a warmup period prior to loading. This minimizes wear on moving parts that do not get lubricated when the engine is running.

The 31 day Frequency is consistent with Regulatory Guide 1.9 (Ref. 5).

This Frequency provides adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.

SR 3.10.1.6 This Surveillance ensures that sufficient air start capacity for the SSF DG is available, without the aid of the refill compressor. The SSF DG air start system is equipped with four air storage tanks. Each set of two tanks will provide sufficient air to start the SSF DG a minimum of three successive times without recharging. The pressure specified in this SR is intended to reflect the lowest value at which the three starts can be accomplished.

The 31 day Frequency takes into account the capacity, capability, redundancy, and diversity of the AC sources.

SR 3.10.1.7 This Surveillance demonstrates that the fuel oil transfer pump automatically starts and transfers fuel oil from the underground fuel oil storage tank to the day tank. This is required to support continuous operation of SSF DG. This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for automatic fuel transfer systems are OPERABLE.

The 92 day Frequency is considered acceptable based on operating experience.

OCONEE UNITS 1, 2, & 3 B 3.10.1-12 BASES REVISION DATED 05/18/10

SSF B 3.10.1 BASES SURVEILLANCE SR 3.10.1.8 REQUIREMENTS (continued) A sample of fuel oil is required to be obtained from the SSF day tank and underground fuel oil storage tank in accordance with the Diesel Fuel Oil Testing Program in order to ensure that fuel oil viscosity, water, and sediment are within the limits of the Diesel Fuel Oil Testing Program.

The 92 day Frequency is considered acceptable based on operating experience related to diesel fuel oil quality.

SR 3.10.1.9 This Surveillance verifies that the SSF DG is capable of synchronizing with the offsite electrical system and accepting loads greater than or equal to the equivalent of the maximum expected accident loads. A minimum run time of 60 minutes is required to stabilize electrical loads, while minimizing the time that the DG is connected to the offsite source.

Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between 0.8 lagging and 1.0.

The 0.8 value is the design rating of the machine, while the 1.0 is an operational limitation to ensure circulating currents are minimized. The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.

The normal 92 day Frequency for this Surveillance is consistent with Regulatory Guide 1.9 (Ref. 5).

This SR is modified by three Notes. Note 1 indicates that diesel engine runs for this Surveillance may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are minimized. Note 2 states that momentary transients because of changing bus loads do not invalidate this test. Similarly, momentary power factor transients above the limit will not invalidate the test. Note 3 indicates that all DG starts for this Surveillance may be preceded by an engine prelube period and followed by a warmup period prior to loading.

This minimizes wear on moving parts that do not get lubricated.

OCONEE UNITS 1, 2, & 3 B 3.10.1-13 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 BASES SURVEILLANCE SR 3.10.1.10 REQUIREMENTS (continued) 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.

The presence of physical damage or deterioration does not necessarily represent a failure of this SR, provided an evaluation determines that the physical damage or deterioration does not affect the OPERABILITY of the battery (its ability to perform its design function).

The 12 month Frequency for this SR is consistent with IEEE-450 (Ref. 4),

which recommends detailed visual inspection of cell condition and rack integrity on a yearly basis.

SR 3.10.1.11 Visual inspection of battery cell to cell and terminal connections provides an indication of physical damage that could potentially degrade battery performance. The anti-corrosion material is used to help 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 limits established for this SR must be no more than 20% above the resistance as measured during installation or not above the ceiling value established by the manufacturer.

The Surveillance Frequency for these inspections is 12 months. This Frequency is considered acceptable based on operating experience related to detecting corrosion trends.

000NEE UNITS 1, 2, & 3 B 3.10.1-14 BASES REVISION DATED 05/18/10

SSF B 3.10.1 BASES SURVEILLANCE SR 3.10.1.12 REQUIREMENTS (continued) A battery service test is a special test of the battery 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. The design basis discharge time for the SSF battery is one hour.

The Surveillance Frequency for this test is 12 months. This Frequency is considered acceptable based on operating experience.

SR 3.10.1.13 CHANNEL CALIBRATION is a complete check of the instrument channel, including the sensor. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.

CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift to ensure that the instrument channel remains operational between successive tests. CHANNEL CALIBRATION shall find that measurement errors and bistable setpoint errors are within the assumptions of the setpoint analysis. CHANNEL CALIBRATIONS must be performed consistent with the assumptions of the setpoint analysis.

This Frequency is justified by the assumption of an 18 month calibration interval to determine the magnitude of equipment drift in the setpoint analysis.

SR 3.10.1.14 Inservice Testing of the SSF valves demonstrates that the valves are mechanically OPERABLE and will operate when required. These valves are required to operate to ensure the required flow path.

The specified Frequency is in accordance with the 1ST Program requirements. Operating experience has shown that these components usually pass the SR when performed at the 1ST Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

OCONEE UNITS 1, 2, & 3 B 3.10.1-15 BASES REVISION DATED 05/18/10

SSF B 3.10.1 BASES SURVEILLANCE SR 3.10.1.15 REQUIREMENTS (continued) This SR requires the SSF pumps to be tested in accordance with the 1ST Program. The 1ST verifies the required flow rate at a discharge pressure to verify OPERABILITY. The SR is modified by a note indicating that it is not applicable to the SSF submersible pump.

The specified Frequency is in accordance with the 1ST Program requirements. Operating experience has shown that these components usually pass the SR when performed at the 1ST Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.10.1.16 This SR requires the SSF submersible pump to be tested on a 2 year Frequency and verifies the required flow rate at a discharge pressure to verify OPERABILITY.

The specified Frequency is based on the pump being not QA grade and on operating experience that has shown it usually passes the SR when performed at the 2 year Frequency.

REFERENCES 1. UFSAR, Section 9.6.

2. Oconee Probabilistic Risk Assessment.

3. 10 CFR 50.36.

4. IEEE-450-1987.

5. Regulatory Guide 1.9, Rev. 0, December 1974.

6. NRC Letter from L. A. Wiens to H. B. Tucker, Safety Evaluation Report on Effect of Tornado Missiles on Oconee Emergency Feedwater System, dated July 28, 1989.

7. NRC Letter from L. A. Wiens to J. W. Hampton, Safety Evaluation for Station Blackout (10 CFR 50.63) Oconee Nuclear Station, Units 1,2, and 3, dated March 10, 1992.

OCONEE UNITS 1, 2, & 3 B 3.10.1-16 BASES REVISION DATED 05/18/10

SSF B 3.10.1 BASES REFERENCES 8. NRC Letter from L. A. Wiens to J. W. Hampton, Supplemental (continued) Safety Evaluation for Station Blackout (10 CFR 50.63) Oconee Nuclear Station, Units 1, 2, and 3, dated December 10, 1992.

000NEE UNITS 1, 2, & 3 B 3.10.1-17 BASES REVISION DATED 05/18/10 I

SSF B 3.10.1 Table B 3.10.1-1 (page 1 of 1)

SSF Instrumentation FUNCTION REQUIRED CHANNELS PER UNIT

1. Reactor Coolant System Pressure 1

2. Reactor Coolant System Temperature (Tc) 1/Loop

3. Reactor Coolant System Temperature (Th) 1/Loop

4. Pressurizer Water Level 1

5. Steam Generator A & B Water Level 1/SG OCONEE UNITS 1, 2, & 3 B 3.10.1-18 BASES REVISION DATED 05/18/10

Admin-305 ES Page 1 of 8 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE Admin-305 Calculate the Maximum Permissible Stay Time Within Emergency Dose Limits (EDL)

CANDIDATE EXAMINER

Admin-305 ES Page2of8 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE Task:

Calculate the Maximum Permissible Stay Time Within the Emergency Dose Limits.

Alternate Path:

N/A Facility JPM #:

N/A KIA Rating(s):

K/A: Gen2.3.4 Rating: 3.2/3.7 Task Standard:

Calculate the Maximum Permissible Stay Time Within the Emergency Dose Limits.

Preferred Evaluation Location: Preferred Evaluation Method:

Simulator In-Plant Classroom X Perform X Simulate

References:

NSD-507, Radiation Protection OMP 1-18, Implementation Standard During Abnormal And Emergency Events Validation Time: 20 mm. Time Critical: NO Candidate: Time Start:

NAME Time Finish:

Performance Rating: SAT UNSAT Performance Time Examiner:

I NAME SIGNATURE DATE COMMENTS

Admin-305 FS Page3of8 SIMULATOR OPERATOR INSTRUCTIONS NONE

Admin-305 ES Page4of8 Tools/EguipmentlProcedures Needed:

Calculator Note tablet READ TO OPERATOR DIRECTIONS TO STUDENT I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

INITIAL CONDITIONS

1. Steam Generator Tube Rupture has occurred on Unit 3

2. Emergency Dose Limits are in effect

3. NEC A has received 1.26 Rem TEDE this year

4. The following tasks are required to be performed:

1. TASK TIME REQUIRED DOSE RATE 1 Close 3C-573 11 mm 6.15 R/hr 2 Open 3FDW-313 6 mm 18.25 R/hr 3 Open all Unit 3s ADVs 4.65 R/hr Note: Assume no dose is received while traveling between tasks.

INITIATING CUE Refer to the above information. NEC A has completed tasks 1 and 2 in the time required.

Determine how long the NEC has to complete task 3 without exceeding his/her Emergency Dose Limits.

Admin-305 FS Page5of8 START TIME:

Note: Candidate may perform these steps in a different order; however, the calculated stay time should be correct.

Note: Candidate should understand the following:

1. EDL is 5 Rem per event (LOCA or SGTR).

2. Current exposure for the year is not counted toward the Emergency Dose Limits (EDL).

STEP 1: Determine dose received while performing task 1. CRITICAL STEP STANDARD: Determine dose received while performing task 1. SAT 6.15R/hrXlhr/6OminXllminl.1275R (1.12 to 1.13 R) UNSAT COMMENTS:

STEP 2: Determine dose received while performing task 2. CRITICAL STEP SAT STANDARD: Determine dose received while performing task 2.

18.25 RIhr X 1 hrI6O mm x 6 mm = 1.825 R UNSAT (1.82 to 1.83 R)

COMMENTS:

STEP 3: Determine dose remaining from EDLs. CRITICAL STEP SAT STANDARD: Determine dose remaining from EDLs.

5R 1 .1275R 1 .825R

= 2.0475 R UNSAT (2.04 to 2.06 R)

COMMENTS:

Admin-305 ES Page 6 of 8 STEP 4: Determine time available for the NEC to complete task 3 without CRITICAL STEP exceeding EDL.

SAT STANDARD: Stay time is calculated to be:

Available Dose = 2.0475 R = .44 hr X 60 mm = 26.42 mm Dose Rate 4.65 RJhr lhr UNSAT (26 to 27 Minutes)

COMMENTS:

END OF TASK STOP TIME:

Admin-305 FS Page 7 of 8 CRITICAL STEP EXPLANATIONS STEP #

Explanation 1 Required to calculate stay time.

2 Required to calculate stay time.

3 Required to calculate stay time.

4 Required to calculate stay time.

CANDIDATE CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS

• Steam Generator Tube Rupture has occurred on Unit 3

• Emergency Dose Limits are in effect

• NEC A has received 1.26 Rem TEDE this year

• The following tasks are required to be performed:

1. TASK TIME REQUIRED DOSE RATE 1 Close 3C-573 11 mm 6.15 R/hr 2 Open 3FDW-313 6 mm 18.25 R/hr 3 Open all Unit 3s ADVs 4.65 R/hr Note: Assume no dose is received while traveling between tasks.

INITIATING CUE Refer to the above information. NED A has completed tasks 1 and 2 in the time required.

Determine how long the NEC has to complete task 3 without exceeding his/her Emergency Dose Limits.

ADMIN-409 FS Page 1 of 11 REGION II INITIAL LICENSE EXAMINATION JOB PERFORMANCE MEASURE ADMIN-409 Determine Emergency Classification and Protective Action Recommendations (Complete Emergency Notification Form)

CANDIDATE EXAMINER

ADMIN-409 FS Page 2 of 11 REGION II INITIA L LICEN SE EXAMINATION JOB PERFO RMAN CE MEASURE Task:

rgency tive Action Recommendations (Complete Eme Determine Emergency Classification and Protec Notification Form)

Alternate Path:

NO Facility JPM #:

New K/A Rating(s):

System: Gen K/A: 2.4.38 Rating: 2.4/4.4 Task Standard:

d with the time ciated Emergency Notification Form is complete Appropriate classification is determined and asso critical criteria.

Preferred Evaluation Method:

Preferred Evaluation Location:

X Perform X Simulate_____

Simulator In-Plant Classroom

References:

RP/0/B/1 000/0 1 RP/0/B/1 000/02 Emergency Plan)

BASIS Document (Volume A, Section D of the RPIOIB/1 000/0 1 5A for EAL 4.4.S.1 Nuclear Power Plant Emergency Notification Form Time Critical: Yes Validation Time: 20 mm.

Time Start:

Candidate:

Time Finish:

NAME UNSAT Performance Time:

Performance Rating: SAT

/

Examiner: SIGNATURE DATE NAME Comments

ADMIN-409 FS Page3of 11 SIMULATOR OPERATOR INSTRUCTIONS NONE

ADMIN-409 ES Page4of 11 Tools/Equipment/Procedures Needed:

RP/0/B/1 000/01 / RP/0/B/1 000/02 READ TO OPERATOR DIRECTIONS TO STUDENT ed. All control room I will explain the initial conditions, and state the task to be perform ons. I will steps shall be performed for this JPM, including any required communicati you. Ensure you provide initiating cues and reports on other actions when directed by you have indicate to me when you understand your assigned task. To indicate that completed your assigned task return the handout sheet I provided you.

INITIAL CONDITIONS: THIS IS A DRILL TIME: 5 minutes ago Unit 1 operating at 45% power Units 2 & 3 operating at 100% power Unit I is performing the Secondary System Protective Test Turbine Trips while testing the Mechanical Overspeed Trip Circuit Reactor Fails to Trip Manual Trip Pushbutton fails to trip the Reactor Control Rods are taken to Manual and are being inserted into the reactor Rule #1 and the EOP are in progress CURRENT CONDITIONS:

TIME: Current time control rods inserting A NEO manually opens the CRD AC Breakers, this action results in all into the core.

No RIAs are increasing or in alarm Containment is intact Containment pressure is 0 psig INITIATING CUE:

Perform the required actions of the Emergency Coordinator:

1. Determine Emergency Classification ons

2. Complete appropriate Emergency Notification Form for current conditi THIS IS A TIME CRITICAL JPM Notify the examiner when the event is classified.

event. When Note: Do not use Emergency Coordinators judgment while classifying the required, other operators will maintain the Emergency Coordinators Log and perform the duties of the Control Room Offsite Communicator.

ADMIN-409 FS Page 5of 11 STARTTIME:

(Actual time)

CRITICAL STEP STEP 1: Classify the Event Enclosure 4.4 (Loss STANDARD: Refer to RPIO/BI1000/O1 (Emergency Classification) SAT of Shutdown Functions) to the following:

Classify the event as a Site Area Emergency due require d WITH OUT automatic A.1 Valid reactor trip signal received or UNSAT scram AND A.2 DSS has NOT inserted Control Rods AND A.3 Manual trip from the Control Room was NOT decreasing successful in reducing reactor power to less than 5% and COMMENTS:

STEP 2: Commence the Off-Site Notification Form.

inator SAT STANDARD: Go to RPIOIBI1000IOO2 (Control Room Emergency Coord ure by determ ining sympto ms for entry Procedure) and initiate proced exist and check Step 1.1 UNSAT COMMENTS:

STEP 3: Step2.1.

SAT STANDARD: Determine step 2.1 does not apply COMMENTS:

UNSAT

ADMIN-409 FS Page 6 of 11 TIME STEP 4: Step 2.2 CRITICAL STEP Declare the appropriate Emergency Classification level.

Classification SAE (UE, ALERT, SAE, GE)

Time Declar ed:

SAT STANDARD: Declare a Site Area Emergency due to:

The reactor control rods have failed to automatically or manually shut down the reactor. Reactor shutdown is required by operator action UNSAT outside of the control room. Current plant conditions DO NOT threaten public safety.

STOP TIME #1: Time SAE Declared (Actual time) (SAT is <Start Time + 15 minutes)

COMMENTS:

STEP 5: Step 2.3 & 2.4 SAT Determine Steps 2.3 and 2.4 do not apply STANDARD:

COMMENTS:

UNSAT STEP 6: Step 2.5 Appoint Control Room Offsite Communicator(s) and notify him to be prepared to transmit messages.

SAT STANDARD: Any name (real or imaginary) is acceptable.

COMMENTS: UNSAT

ADMIN-409 FS Page 7of 11 STEP 7: Step 2.6 classification IAAT Changing plant conditions require an emergency to compl ete the in-progress upgrade, THEN Notify Offsite Communicator SAT e Comm unicati ons From The notifications per RPIOIBI1000I15A, (Offsit CR) the upgraded AND Re-initiate a clean copy of this procedure for classification and stop this procedure. UNSAT STANDARD: An Upgrade is not expected.

COMMENTS:

CRITICAL STEP STEP 8: Step 2.7 the Emergency Plan Obtain the appropriate Offsite Notification form from SAT cart.

d and candidate STANDARD: Initial Site Area Emergency form # 4.4.S.1 isselecte UNSAT continues to fill-out form per the Step 2.7 subste ps.

COMMENTS:

ADMIN-409 ES Page 8of 11 CRITICAL STEPS STEP 9: Step 2.7 (4.4.Si) _Line I Ensure EAL # as determined by RP/O/B/1000/0O1 matches Line 4. IVIesae #)

L)

(NC) Line 1 Mark appropriate box Drill or Actual Event (DRIL

• Line 6 (C) Line 1 - Enter Message # (#1) Line 7

_Ljne 10 (C) Line 2 Mark Initial (INITIAL marked)

Line 12 (C) Line 6 (None marked)

A. Mark Is Occurring if any of the following are true:

• RlAs 40, 45, or 46 are increasing or in alarm

• If containment is breached SAT

• Containment pressure> 1 psig B. Mark None if none of the above is applicable.

UNSAT (C) Line 7 If Line 6 Box B or C is marked, mark Box D. Otherwise mark Box A (A marked) ated within (NC) Line 8 - Mark Stable unless an upgrade or additional PARs are anticip an hour.

• Refer to Enclosure 4.9, (Event Prognosis Definitions) in Step 2.2)

(C) Line 10 Military time and date of declaration (Refer to date/time critical as long (Insert time from STEP I and todays date, military time is not as time is specific and accurate.)

)

(NC) Line 11 If more than one unit affected, mark All (Unit I marked level of (C) Line 12- Mark affected unit(s) (reference Line 11) AND enter power affected unit(s) or time/date of shutdown {14} (Unit 1 0% power, Shutdown at 1405 with todays date.)

date may provide (NC) Line 13 If the OSM has no remarks, write None (Candi relevant information as applica ble)

If Condition A exists ensure following PARs are included Line 5.

e A. Evacuate: Move residents living downstream of the Keowe Hydro Project dams to higher ground B. Other: Prohibit traffic flow across bridges identified on your inundation maps until the danger has passed. (Condition A does not exist. No PAR required) with STANDARD: Correctly fills out Emergency Notification Form in accordance Key.

COMMENTS:

ADMIN-409 ES Page9of 11 TIME STEP 10: Step 2.7 Continued CRITICAL STEP (C) Line 17 - OSM signature, CURRENT Time/Date (MUST SIGN) s of STANDARD: Correctly fills out Emergency Notification Form within 15 minute classification time recorded in step 1.

STOP TIME #2: Time for Notification (Actual time) (SAT is <Stop Time #1 ÷ 15 minutes)

COMMENTS:

END OF TASK

ADMIN-409 FS Page lOof 11 CRITICAL STEP EXPLANATIONS STEP # Explanation determine the conditions meet a 1 The candidate needs to be able to utilize the procedure and Site Area Emergency classification.

the SAE within 15 minutes of 4 This is a time critical step. The candidate needs to declare of the assessment period) beginning the JPM. (The start of the JPM is the beginning 8 The correct form that matches the EAL # is selected.

entry identified as critical 9 The emergency notification form is filled-out with each line complete and accurate.

the notification form within 15 10 This is a time critical step. The Candidate needs to complete time is the time recorded in JPM minutes from the time the EAL was declared. (Declaration step 4)

CANDIDATE CUE SHEET TASK)

(TO BE RETURNED TO EXAMINER UPON COMPLETION OF INITIAL CONDITIONS: THIS IS A DRILL TIME: 5 minutes ago

• Unit I operating at 45% power

• Units 2 & 3 operating at 100% power

• Unit us performing the Secondary System Protective Test

• Turbine Trips while testing the Mechanical Overspeed Trip Circuit

• Reactor Fails to Trip

• Manual Trip Pushbutton fails to trip the Reactor

• Control Rods are taken to Manual and are being inserted into the reactor

• Rule #1 and the EOP are in progress CURRENT CONDITIONS:

TIME: Current time all control rods

• A NED manually opens the CRD AC Breakers, this action results in inserting into the core.

• No RIAs are increasing or in alarm

• Containment is intact

• Containment pressure is 0 psig INITIATING CUE:

Perform the required actions of the Emergency Coordinator:

1. Determine Emergency Classification ions

2. Complete appropriate Emergency Notification Form for current condit THIS IS A TIME CRITICAL JPM Notify the examiner when the event is classified.

the event. When Note: Do not use Emergency Coordinators judgment while classifying and required, other operators will maintain the Emergency Coordinators Log perform the duties of the Control Room Offsite Communicato r.

,4i21/t1 fD7 t

NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM

1. DRILL ACTUAL EVENT MESSAGE#

2. INITIAL FOLLOW-UP NOTIFICATION: TIME DATE I I AUTHENTICATION#

3. SITE: Oconee Nuclear Site Confirmation Phone # (864) 882-7076

4. EMERGENCY ØUNUSUAL EVENT ALERT SITE AREA EMERGENCY QGENERAL EMERGENCY CLASSIFICATION:

BASED ON EAL# 4.4.S.1 EAL DESCRIPTION The reactor control rods have failed to automatically or manually shut down the reactor. Reactor shutdown is required by operator action outside of the control room. Current plant conditions DO NOT threaten public safety.

5. PROTECTIVE ACTION RECOMMENDATIONS: ENONE EVACUATE J

SHELTER J

CONSIDER THE USE OF KI (POTASSIUM IODIDE) IN ACCORDANCE WITH STATE PLANS AND POLICY.

EJ OTHER EJ

6. EMERGENCY RELEASE: one Is Occurring Has Occurred

7. RELEASE SIGNIFICANCE: 1ot applicable B Within normal operating limits Above normal operating limits ØUnder Evaluation

8. EVENT PROGNOSIS: A Improving Stable C Degrading

9. METEOROLOGICAL DATA: Wind Direction* from degrees Wind Speed* mph

(* May not be available for Initial Notifications)

Precipitation* Stability Class* B EJ EJ ED [I] []

1O. DECLARATION Time Date £4/t

[] TERMINATION

11. AFFECTED UNIT(S):

12. Unit Status:

J J J Ui A.?  % Power Shutdown at: Time 1 h1 S Date 1,)DJ (Unattected Unit(s) status Not Required tor Initial Notifications) i:: U2  % Power Shutdown at: Time Date I I U3  % Power Shutdown at: Time Date I I

13. REMARKS: /t/L9Al FOLLOW-UP INFORMATION (Lines 14 through 16 Not Required for Initial Notifications)

EMERGENCY RELEASE DATA. NOT REQUIRED IF LINE 6A IS SELECTED.

14. RELEASE CHARACTERIZATION: TYPE: EElevated Mixed Ground UNITS: ECi EDCi/sec EDPCi/sec MAGNITUDE: Noble Gases:

lodines: Particulates: Other:

FORM: Airborne Start Time: Date: I / Stop Time: Date I I

ØLiquid Start Time: Date: / I Stop Time: Date I /

15. PROJECTION PARAMETERS: Projection Period: Hours Estimated Release Duration: Hours Projection performed: Time Date I /

16. PROJECTED DOSE: DISTANCE TEDE (mrem) Adult Thyroid CDE (mrem)

Site boundary 2 Miles 5 Miles 10 Miles F

çqci.r1

17. APPROVED BY:_________________________________

Title:

Emergency Coordinator Time: iTM Date: I I NOTIFIED BY: RECEIVE BY: Time: Date: I I IE7

Duke Energy Procedure No.

Oconee Nuclear Station RP/O/B/1 000/001 Emergency Classification Revision No.

028 Electronic Reference No.

0X002w0s Reference Use PERFORMANCE UNCONTROLLED FOR PRINT * * * * * * * * * *

(ISSUED) PDF Format L.)f,c P

Procedure No.

Duke Energy Oconee Nuclear Station Rp/OIBI1000/002 Revision No.

Control Room Emergency Coordinator Procedure 022 Electronic Reference No.

OXOO2WOT Reference Use PERFORMANCE

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