EXAMINER CANDIDATE CALCULATE LICENSE REGION …CRD Groups 1-7 are at 0%w/d 13.11, vs. 1 SAT 50% wd)...

REGION IIINITIAL LICENSE EXAMINATIONJOB PERFORMANCE MEASURE

ADM-1 25

CALCULATE SHUTDOWN MARGIN(MANUAL CALCULATION)

ADMIN-125 FSPage 1 of 10

CANDIDATE

EXAMINER

ADMIN-125 ES

Page 2 of 10

REGION II

INITIAL LICENSE EXAMINATION

JOB PERFORMANCE MEASURE

Task:

CALCULATE SHUTDOWN MARGIN (MANUAL CALCULATION)

Alternate Path:

No

Facility JPM #:

C RO-076

KIA Rating(s):

System: GENERIC

K/A: 2.1.43Rating: 4.1/4.3

Task Standard:

Shutdown Margin agrees with attached example (-3.5122 to -3.5935).

Preferred Evaluation Location: Preferred Evaluation Method:

Simulator In-Plant

_____

Classroom X Perform X Simulate

References:

PT/i IA/i 103/15, Reactivity Balance Procedure

Validation Time: 20 minutes Time Critical: NO

Candidate:

_______________________________________

Time Start:

NAME Time Finish:

Performance Rating: SAT

______

UNSAT Performance Time:

Examiner:NAME SIGNATURE DATE

COMMENTS

None

SIMULATOR OPERATOR INSTRUCTIONS


ADMIN-125 ESPage 4 of 10

Tools/EguipmentlProcedures Needed:

• PT/I /A/1103/O1 5, Reactivity Balance Procedure,

o Enclosure 13.1, Shutdown Boron Concentration/Shutdown Margin Calculation

o Enclosures 13.7 through 13.21

• Calculator• Straight edge ruler

READ TO OPERATOR

DIRECTION TO TRAINEE

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/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• Cycle burnup 100 EFPD• RCS temperature = 60°F• Control Rod Group I at 0% withdrawn

• Control Rod Group 8 at 35% withdrawn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 ESPage 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”.

COMMENTS:UNSAT

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 hours. However, any time

interval may be used. This time interval is only required if credit is to be SAT

taken for Xenon/Samarium.

Xenon/Samarium time interval valid from

date/time:___________________ to Date/time:______________ UNSAT

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:


STEP 3: Step 2.3

Obtain reference Shutdown Boron Concentration for the effective Burnup CRITICAL TASK

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

Enclosure 13.11, Shutdown Boron Concentration vs. Burnup (Group 1 @ SAT

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

STANDARD:

Reference Shutdown Boron Concentration is obtained from the point ofUNSAT

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: SATStudent 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 SATSTANDARD:

Determine that required boron concentration is equal to referenceshutdown boron concentration.

UNSAT1358 (+/-5) ppmB - 0 ppmB = 1358 (+1-5) ppmB

step 2.3 steps 2.4.7 or 2.4.6 pos or zero

COMMENTS:


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 SSFOperability, using the Minimum Xenon from the effective time period:

Minimum RCS Boron for SSF operability =

_______ppmB

STANDARD: SAT

The student should determine that the Minimum RCS Boron for SSFoperability is 1071 PPM (+1-10).

UNSATCOMMENTS:

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 =

_______ppmB

SATSTANDARD:

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

COMMENTS:UNSAT

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 °FUNSAT

COMMENTS:


STEP 9: Step 2.6.2

Subtract the required Boron concentration in 2.5.1 from the actual Boron CRITICAL TASK

concentration in 2.6.1, the result should be positive unless a 1% \k/k

shutdown margin has r been established:

_______ppmB

-

_______ppmB

=

_______ppmB

SATstep 2.6.1 step 2.5.1 should be pos

STANDARD:The student should subtract the (1405) from the actual of 1600 and

obtain a net result of (195) ppmB (positive). UNSAT

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

Calculate the actual shutdown margin by multiplying 2.6.2 times the CRITICAL TASK

Differential Boron Worth from Enclosure 13.8, Differential Boron Worth

vs. Burnup and subtracting 1%tkIk:

( ppmB x

______%k/kIppmB)

- 1%lXkik=

______%1kJk

step 2.6.2 negative should be neg

End 13.8SAT

STANDARD:242 (+1-5> ppmB x -0.01055 (+1- 0.00005) %k/k/ppmB) - 1%tkIk= -3.553 %k/k

step 2.6.2 negative should be neg

End 13.8UNSAT

Candidate determines SDM is greater than 1%tKIK and is between

-3.51 22 to -3.5935% AkIk.

COMMENTS:

END OF TASK

STOP TIME:


CRITICAL STEP EXPLANATIONS

STEP # Explanation

3 Necessary to produce an accurate SDM




10 It is critical to calculate shutdown margin accurately to verify the requirements of

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

Control Room supervisor directs you to perform the Original manual calculation of SDM using

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.

Continuous Use OXO02WBQ

PERFORMANCE I* * * * * * * * * * UNCONTROLLED FOR PRINT * * * * * * * * * *

(ISSUED) - PDF Format

PT/i/A/i 103/015Page 2 of 8

Reactivity Balance Procedure

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.

To provide nominal APSR position.

To provide the Minimum RCS Boron Concentration to maintain SSF Operability

1. Purpose

1.1

1.7

1.8

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 103/015Page 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 hour 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, thereforethis procedure affects core reactivity. (R.M.)

6.2 Appropriate corrections have been made per this procedure, or actual plant conditionsmust 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 thedesired 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 NOTinput 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 withdrawnprior 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:

Calculated in Enclosure 13.1, Shutdown Boron Concentration!Shutdown Margin

Calculation, or 13.2, Computerized Shutdown Margin Calculation.

The shutdown Boron concentration provides a greater than 1.0% AKIK shutdown margin

with the worst case stuck rod assumed to be out.

A reference shutdown Boron concentration is obtained based on the cycle bumup, rod

positions and RCS temperature. The reactivity worths of Xenon, Samarium, and the

inoperable rod penalty (if applicable) are converted into their equivalent Boron

concentrations. (Credit is taken only for the minimum Xenon worth occurring in a

specified time interval, which should not exceed 13 hours. The Shutdown Boron

concentration is valid iy during that time interval. Due to uncertanities in the Xenon

models, 0.8 times the Xenon and Samarium worth are used unless the RCS is below

450°F, in which case 0.5 times the Xenon and Samarium worths are used. Xenon and

Samarium worths may be assumed to be zero for conservatism.) These Boron

concentrations are then applied to the reference Boron concentration to provide the

required Boron concentration for a greater than 1.0% MKIK shutdown margin (i.e., the

shutdown Boron concentration).

9.2 Shutdown Margin Calculation while Shutdown:

Calculated in Enclosure 13.1, Shutdown Boron ConcentrationlShutdown Margin

Calculation or 13.2, Computerized Shutdown Margin Calculation.

The shutdown margin is the amount of reactivity by which the reactor is shutdown. The

worst case stuck rod is assumed to be out. If operating with a known inoperable rod, an

additional penalty is applied to account for that rod. This penalty need not be applied

when the reactor is shutdown if that rod can be confirmed to be fully inserted by

redundant indications. The shutdown Boron concentration must first be found per step

9.1. The actual Boron concentration is then subtracted from this concentration and the

result converted to % z\KiK. 1.0% z\KIK is then subtracted from this value to obtain the

shutdown margin, expressed in - % z\KIK. A separate check for SSF RC Makeup System

operability is performed, which takes credit for Xenon and requires the stuck rod penalty.

This limit is shown in Enclosure 13.20, Minimum RCS Boron Concentration to Maintain

SSF Operability.

PT/i/A/i 103/0 15

Page 5 of 8

Following a shutdown, Control Rod Position at the time of Shutdown may be used with

the Rod Position Limit curves (in COLR) to verify at least 1% z\KIK shutdown margin

for the first 3 hours following shutdown (provided RCS Temperature stays? 532°F and

boron does not decrease). This may be necessary for shutdowns with an inoperable rod,

since the more conservative calculation method (in Enclosure 13.1, Shutdown Boron

ConcentrationlShutdown Margin Calculation, and 13.2, Computerized Shutdown Margin

Calculation) may not show 1% zKIK shutdown margin immediately after shutdown.

Boration should begin immediately to be able to show 1% KJK shutdown margin using

the calculation method.

9.3 Shutdown Margin at Power:

Verified in Enclosure 13.18, Shutdown Margin Calculation at Power.

While at power, the available shutdown margin may be verified to be?: 1% AKIK by

using the Rod Position Limits curves (in COLR). Operation in the “Acceptable Region”

of these curves ensures that the shutdown margin following a reactor trip will be? 1%

zXKIK with the worst stuck rod out. There are curves for 3 and 4 RCP operation, and

curves for 0 and 1 inoperable rod. A dropped rod is considered inoperable for the

purposes of providing shutdown margin while at power.

9.4 Estimated Critical Rod Position:

Calculated in Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation.

The core excess reactivity is obtained based on the cycle burnup. The reactivity worths

associated with Boron, Xenon, temperature correction (if RCS temperature not at 53 2°F)

and Samarium are then obtained and summed with the core excess reactivity. The groups

5-7 positions are then determined for which the inserted rod worth when summed with all

the above, yields a total core reactivity of 0.0% AKJK. The upper and lower rod position

limits are then determined and the actual critical rod positions are recorded.

9.5 Estimated Critical Boron Concentration:

Calculated in Enclosure 13.5, Computerized Estimated Critical Boron Calculation.

The core excess reactivity is obtained based on the cycle bumup. The reactivity worth

associated with Xenon, temperature correction (if RCS temperature not at 532°F),

Samarium and the desired critical rod positions are summed with the core excess

reactivity. The Boron concentration is then determined for which its reactivity worth,

when summed with all the above, yields a total core reactivity of 0.0% AK/K.

PT/i/A/l 103/0 15Page 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 (C0) is recorded. During

control rod withdrawals, new counts (C) are recorded and used to calculate 1/M, or C0/C.

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:

Enclosure 13.1, “Shutdown Boron ConcentrationlShutdown Margin Calculation,”

orEnclosure 13.2 “Computerized Shutdown Margin Calculation”

Estimated Critical Rod Position:

Enclosure 13.4, “Computerized Estimated Critical Rod Position Calculation”

Estimated Critical Boron Concentration:

Enclosure 13.5, “Computerized Estimated Critical Boron Calculation”

Computerized Subcritical Multiplication (1/M) Measurement:

Enclosure 13.6, “Computerized Subcritical Multiplication (1/M) Measurement”

Refueling Outage Boron Concentrations:

Enclosure 13.13, “Refueling Outage Boron Concentrations”

Required Control Rod Group 8 Position:

Enclosure 13.14, “Required Group 8 Position and Designed Cycle Length”

Designed Cycle Length Information:

Enclosure 13.14, “Required Group 8 Position and Designed Cycle Length”

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:

Enclosure 13.20, “Minimum RCS Boron Concentration to Maintain SSF Operability”

RCS Boron Concentration for SSF Operability with SSF RCMU Letdown Flow Degraded:

Enclosure 13.21, “Minimum RCS Boron Concentration to Maintain SSF Operability with

SSF RCMU Letdown Flow Degraded 50% & SSF RCMU Bypass Open”

PT/i/A/I 103/0 15Page 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/A11103/015Shutdown 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. Circlewhether 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 hours. 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 RCSTemp of this calculation (2.2) from one of the following:

Enclosure 13.10, Shutdown Boron Concentration vs. Burnup (Group I @ 0% wd) if CRDGroups 1-7 are at 0%w/dEnclosure 13.11, Shutdown Boron Concentration vs. Burnup (Group 1 @ 50% wd) if CRDGrpl 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 5Margin 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:

______%AkJk

x

____________

negative

__________________

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:

rpositive

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#:_________ Ipositive

2.4.5 Sum 2.4.1 + 2.4.3 + 2.4.4 =______

2.4.6 Obtain boron concentration adjustment by dividing 2.4.5 by Differential

Boron Worth from Enclosure 13.8, Differential Boron Worth vs.

_______%zM<Jk

/

______

neg or posstep 2.4.5

0.8orO.5E %k/k

negative

Inoperable Rod Group#: Rod#:

[

_______%AkIk

neg or pos I%zkJkIppmB

negativeEnd 13.8

Enclosure 13.1 PT/1/A,1103/015

Shutdown Boron Concentration/Shutdown Page 3 of 5Margin 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:

_______ppmB

- 50 ppmB= I ppmB

neg or pos neg or pos

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):

_______ppmB

-

_______ppmB

=

_______ppmB

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 fromEnclosure 13.20, Minimum RCS Boron Concentration to Maintain SSFOperability, 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 theGREATERofstep2.5.1 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 shutdownmargin has NOT been established:

_______ppmB

-

_______ppmB

=

______ppmB

step 2.6.1 step 2.5.1 1.should be pos

Enclosure 13.1 PT/1/A/11o3/o15Shutdown Boron Concentration/Shutdown Page 4 of 5

Margin Calculation

2.6.3 Calculate the actual shutdown margin by multiplying 2.6.2 times theDifferential Boron Worth from Enclosure 13.8, Differential Boron Worth vs.Burnup and subtracting 1%zk/k:

_____ppmB

x

_____%Alk/ppmB)

- 1%Ak/kT

_____%AkJk

step 2.6.2 negative should be negEnd 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 reactorconditions, perform the following:

2.8.1 Verify that the shutdown margin (Step 2.6.3) is greater than 1%1M(JK (i.e.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 hours of shut down, verify Shutdown Margin using COLRcurve (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 concentrationin2.5.3.

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 greaterthan 1 %zXKIK shutdown margin for the above reference conditions must be greater thanthe 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 andturn the package over to the Control Room SRO. (N/A this step on the separateverification 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

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

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 - 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)

CAUTION: 1. IF the power history information from the last equilibrium Xe/Sm condition is

NOT input into the code, significant error may result.

2. IF Xenon credit is required the EFPD input into the code SHALL correspond to

the “beginning of the power history”, NOT the EFPD at the “effective time of

calculation”.

3. The RhoCalc code uses the EFPD that is input to the code to lookup the shutdown

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.

NOTE: IF a printer is not available, Enclosure 13.3, Computerized Shutdown Margin Calculation

Documentation, may be used to document this calculation.

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, performone 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 hours of shut down, verify Shutdown Margin using COLRcurve (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).

______________________________Control

Room SRO

2.8 Attach results of shutdown margin calculation to the procedure and turn the packageover 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 ShutdownMargins” folder located in the Reactor Engineering procedure cabinet. (N/A this step onthe separate verification calculation.)


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

Enclosure 13.3 PT/1/A!11o3/o15Computerized 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 ShutdownMargin 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

_______ppmB

Independent Verification:

Enclosure 13.4 PT/1/A/11o3/015Computerized 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 duringunit start up.

2. Procedure


2.1 This enclosure must be performed twice - the second is the separate verification. Circlewhether 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/Asteps 2.9-2.14 for Separate Verification)

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

_____

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

CAUTION: IF the power history information from the last equilibrium Xe/Sm condition is NOTinput 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 toperform the Xenon calculation from a source such as PT server, OAC Log, ROLog, etc.

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

2.4 Open RhoCalc.

Enclosure 13.4 PT/i/All 103/015Computerized 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 conditionssufficient time must be factored in to allow for changes to be made to the RCS andPZR Boron concentration, samples to be taken, the time required to pull Groups 1 - 4to 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 entrycould 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 beused.

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 stepsthat have an ECP prediction.


Computerized Estimated Critical Rod Position Page 3 of 4Calculation

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/A’ed 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 of’S <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

_______(date).

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

verification calculation).

______________________________Control

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.)


Computerized Estimated Critical Rod Position Page 4 of 4

Calculation


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 13.5PT/i/A/i 103/015

Computerized Estimated Critical Boron Page 1 of 2Calculation

1. Purpose

The purpose of this enclosure is to calculate an estimated critical boron concentration to be usedduring unit start up.

2. Procedure


2.1 This enclosure must be perfonned twice - the second is the separate verification. Circlewhether 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 steps2.8-2.10 for Separate Verification)

CAUTION: j the power history information from the last equilibrium Xe/Sm condition is NOTinput 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 toperform the Xenon calculation from a source such as P1 server, OAC Log, ROLog, etc.

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

2.3 Open RhoCaic.

Enclosure 13.5 PT/1/A/11o3/o15Computerized 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 initialcycle startup. This can be adjusted to plant conditions at the discretion of the SRO.IF deviating from this position significantly, model the power increase usingPT/0/A/l 103/020, Power Maneuvering Predictions, to ensure no problems will beencountered.

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 “CalculateECB”, and print.

NOTE: Enclosure 13.4, Computerized Estimated Critical Rod Position Calculation, does NOThave 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 Xenonconditions sufficient time must be factored in to allow for changes to be made to the RCSand PZR Boron concentration, samples to be taken, the time required to pull Groups 1 - 4to 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 theanticipated 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 separateverification calculation).

______________________________Control

Room SRO

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


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

Enclosure 13.6 PT/1/A/11o3/o15

Computerized Subcritical Multiplication (l/M) Page 1 of 4

Measurement

1. Purpose

The purpose of this enclosure is to perform 1/M measurements by spreadsheet during unit start

up other than the initial cycle startup. PT/0/A/071 1/00 1, Zero Power Physics Procedure, controls

the initial cycle startup.

2. Procedure

NOTE: • This procedure is performed by a Qualified Reactor Engineer. The Double

Verification performed in step 2.7.6 shall be by a Licensed Operator.

• Step 2.4 may be performed at any time and should be referenced at this time.

Calculation Performed By:________________ Date:___________ Time:_______________

CAUTION: The l/M plot should only be used as an operator aid for predicting premature

criticality and should NOT be relied upon for predicting critical rod position or as a

substitution for Control Room indications.

NOTE: A control copy of 1M.xls is located in the following locations:

• \\ONSFSOO\SYSCODES\Computer Support\l _M Spreadsheet\l_M.XLS

• Reactor Engineering Fireproof Cabinet

• SDQA 10135-ONS

2.1 Open spreadsheet i_M.xls.

2.2 Perform the following Steps on the NI-i TAB (user input cells are yellow).

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.

NOTE: Notify Lines can be selected or deselected at any time during this procedure at the user’s

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 hours prior to achieving criticality.

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

RCS conditions.


Computerized Subcritical Multiplication (1IM) Page 3 of 4Measurement

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/A’ed.

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 theT’Rhocalc 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.)


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) wdOPS QRE

____ ____

1 100%wdOPS QRE

____ ____

2 100%wdOPS QRE

____ ____

3 100%wdOPS QRE

____ ____

4 100%wdOPS QRE

____ ____

5 50%wdOPS QRE

____ ____

5 75%wd0P5 QRE

____ ____

6 25%wdOPS QRE

____ ____

6 50%wdOPS QRE

____ ____

6 75%wdOPS QRE

____ ____

7 25%wdOPS QRE

____ ____

7 50%wdOPS QRE

____ ____

7 75%wdOPS QRE

____ ____

7 100%wdOPS QRE

2.8 Ensure actual critical conditions are recorded on the ECP printout.

2.9 Print and attach the 1/M spreadsheet.

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Enclosure 13.12 PT/1/A/11o3/o15Inoperable Rod Penalty for Individual Page 1 of 1

Inoperable Rod01C26

Rod Rod Eighth Core PenaltyGroup 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 1Cycle 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 berepositioned to 30 - 40 %wd.

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

435 EFPD

Prior to APSR pull During APSR pull After APSR pullRequired Group 8 Required Group 8 Required Group8

Condition Position (% wd) Position (% wd) Position (%wd)*

Approach toCriticality 30 - 40 30 - 40 100

Steady StateOperation 30 -40 35 - 100 100

ReactorShutdown 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.

Enc

losu

re13

.15

-3

-2.5 -2

U

-1.5

U U 0 0.

—1

-0.5 0

Pow

erD

efec

tvs

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eact

or

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erG

rou

p8

@35%

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T@

3%

wd

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FP

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1C26

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ll10

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Enclosure 13.16 PT/1/A/1103/o15Shutdown 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/1103/015Control Rod Group Worths for Control Rod Page 1 of 1

Drop Time Testing01C26

NOTE: Interpolate for intermediate temperatures.

Control Rod Group Worths for BOC CRDTTT, HZP, No OverlapGroup8 @35% wd, NOXE

CRGP 1 performed with CRGP2-7 in,CRGP2 performed with CRGP1,3-7 in, etc.

RodGroup 300F 532F

1 1.188 1.5572 1.985 2.1923 - 1.104 1.8124 0.709 0.8525 2.238 2.6296 0.642 0.9057 1.824 2.0421-4 4.5945-7 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 BOCHZP, No Overlap, 525-557°F

Group8@35%wdCRGP 1 performed with CRGP2-7 in,

CRGP2 performed with CRGP1, 3-7 in, etc.

Rod 4 250 500Group EFPD EFPD EFPD

1 1.638 1.755 1.8392 2.288 2.310 2.4903 2.034 2.152 2.2634 0.983 1.069 1.2735 2.725 2.802 2.9556 0.980 1.044 1.1127 2.119 2.090 2.226

Enclosure 13.18 PT/1/A/11o3/o15Shutdown 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 atpower.

2. Procedure

Performed By:

_____________________

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

_____

2.1 IF any groups are NOT at 100% withdrawn (other than Group 7 and the APSRs) due toCRD 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. Therod position used should be the position of the controlling group (if the dropped/stuck rodis in the controlling group, the rod positions of remaining rods in that group should beused, 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 the5V 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 andInoperable rods in the COLR.

OR

_____ _____

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

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0.8

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Admin-112 FSPage 1 of 8


ADMIN-1 12

Calculate Requirements to Makeup to the BWST

CANDIDATE

EXAMINER

Admin-112 FSPage2of8


Task:

Calculate requirements to makeup to the BWST

Alternate Path:

No

Facility JPM #:

Bank

KIA Rating(s):

System: GENK/A: 2.1.25Rating: 3.9/4.2

Task Standard:

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


Simulator

______

In-Plant

______


______

References:EOP Enclosure 5.4, Makeup to the BWSTOP/O/N1108/OO1, Curves and General InformationCOLR

Validation Time: 13 minutes Time Critical: NO

Candidate:

_________________________________________

Time Start:

_________

NAME Time Finish:

_______


______


________

Examiner:INAME SIGNATURE DATE

COMMENTS



NONE

Admin-112 ESPage4of8ToolslEguipmentlProcedures 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


I will explain the initial conditions, and state the task to be performed. All control roomsteps shall be performed for this JPM, including any required communications. I willprovide initiating cues and reports on other actions when directed by you. Ensure youindicate to me when you understand your assigned task. To indicate that you havecompleted your assigned task return the handout sheet I provided you.

INITIAL CONDITIONS

• QAC is not available

• Unit 1 shutdown and cool down in progress due to a tube rupture 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 (Makeup to the BWST) to determinethe 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 inchesand match the current BWST Boron concentration.

Admin-112 FSPage 5of8

START TIME:

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

SAT• QAC graphic CSO1• BHUT Volume vs. Level Curve (End. 4.1) in OP/OIA/11081001

(Curves and General Information)

UNSATSTANDARD: Refer to Enclosure 4.1 BHUT Volume vs. Level Curve inOP/0/AJ1 108/001 (Curves and General Information) and determine thatthe 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 2CRITICAL STEPDetermine volume of CBAST required per the following to yield a volumein 1A BHUT of 81,000 gals at 2,500 ppm: SAT

(BHUTvfX BHUTci) ( BHUTvI X BHUT1) = # gallons of CBAST neededUNSATCBAST,

(80,750 x 2,500) - (13,500 x 240) = 15,889 gal of CBAST needed12,501

(81,250 x2,500) -(14,000 x 240) = 15,980 gal of CBAST needed12,501

STANDARD: Candidate calculates the required volumes from CBAST between:15,889 and 15,980 gallons.

BHUTvf= Final BHUT volume (gal) 80,750 to 81,250 galsBHUTv1= Initial BHUT volume (gal) 13,500 to 14,000 galsBHUTcf= Final BHUT conc (ppmb) 2,500 ppmbBHUTc = Initial BHUT conc (ppmb) 240 ppmbCBASTc CBAST conc (ppmb) 12,501 ppmb

Note: Instructions are to fill IA BHUT to 180” which correlates to —81,000 gal.COMMENTS:


CRITICAL STEPSTEP 3: Step 3

Determine volume of DW required per the following to yield a volume in — SAT1A BHUT of 80,750 to 81,250 gals at 2500 ppm:

UNSATBHUTvf - BHUTvI - # gallons CBAST needed # gallons of DW needed

81,250 — 13,500 — 15,889 = 51,861 gallons of OW needed

80,750—14,000 — 15,980 = 50,770 gallons of DW needed

STANDARD: Candidate calculates the required volumes from DW between:50,770 arid 51,861 gallons

COMMENTS

END OF TASK

STOP TIME:

Admin-112 ESPage7of8


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 COMPLETION OF TASK)

INITIAL CONDITIONS

• OAC is not available

• Unit 1 shutdown and cool down in progress due to a tube rupture 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 determinethe required volumes of CBAST and DW to begin makeup to the BWST from IA BHUT.

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

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Enclosure 5.4EPI1/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 BHUTusing gy of the following:

OAC graphic CSO1BHUT Volume vs Level Curve inOP/0/AI1 108/00 1 (Curves and GeneralInformation).

2. Determine volume of CBAST and DWrequired per the following to yield avolume in 1 A BHUT of 80,000 to82,000 gals at a concentration thatcomplies with COLR requirements forthe BWST:Where:

BHUTf = Final BHUT volume (gal)BHUT1 = Initial BHUT volume (gal)BHUTf = Final BHUT conc (ppmb)BHUT1 = Initial BHUT conc (ppmb)CBAST = CBAST conc (ppmb)

(BHUTVf x BHUTCf) - (BHuT1 x BHUT)

_________________________________________

= # gallons of CBAST neededCBAST

(____

___)-( ______

)# gallons of CBAST needed

BHUTvf - BHUTvi - # gallons CBAST needed # gallons of DW needed

# gallons of DW needed

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

Enclosure 5.4EP,/1/A!l800/ool


[ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

4. — Verify quantity of boron needed for GO TO Step 6.transfer to 1A BHUT is available in theCBAST without going below minimumSLC 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” viaDW-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 HEATERswitch in AUTO (A-2, 1&2 ChemAdd Panel).

D. WHEN Unit 1&2 BAMTtemperature is 127°F,THEN notify Primary Chemistry toadd chemicals.

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

9. Open ICS-62.

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

A. — Close CA-38 (Unit 1/2 HP BoricAcid 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 Pumpused for transfer of BAMT to CBAST. (A-2, 1&2 Chem Add Panel).

2._ GOTOStep14.

Enclosure 5.4EP/1/A11800/OOi


ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

12. Locally open CA-li (AIB LP BAMTPumps Disch Tie) (A-i, l&2 BAMTR).

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

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

15. — Inform Units 1 and 2 to monitor forreactivity effects due to possible leakageof l&2 BAMT into LDST.

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

A. — Place Unit 1&2 BAMT HEATERswitch in OFF.

B. — Stop Unit 1&2 BAMT AGITATOR.

17. — WHEN transfer is complete,THEN locally stop the selected LP BoricAcid Pump (A-2, 1 &2 Chem AddPanel).

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

A. — Close CA-4 (Unit 1/2 BAMTOutlet).

B. — Open DW-1 19 (Boric Acid MixPumps Suction Hdr Flush).

19. — Locally start previously running LPBoric Acid Pump (A-2, 1&2 Chem AddPanel).

20. — WHEN LP Boric Acid Pump has run for5 minutes,THEN locally stop LP Boric Acid Pump(A-2, 1&2 Chem Add Panel).

Enclosure 5.4EP/1/AJl800/ooi



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


DW- 119 (Boric Acid Mix PumpsSuction 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 BAMTPumps Disch Tie)(A-i, 1&2 BAMT Rm).

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

26. — Verify quantity of boron needed for 1. — Notify Primary Chemist of volumetransfer to 1 A BHUT is available in the removed from Unit 1 &2 BAMT.CBAST without going below minimum 2 GO TO Step 7SLC required for CBAST.

—

27. 1CS-64.

28. — Start 1A CBAST PUMP.

29. — Inform all units to monitor for reactivityeffects due to possible leakage ofCBAST 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 isdesired,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 5.4EP/l/AIl800Iool



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/Osheet:

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 GasTanks.

48. open 1DW-174 (Bleed HoldupTank Supply) (A-i, hallway S of freightelevator).

49. — Locally throttle 1CT-87 (Condensate ToBHUT 1A) as necessary to control flowand minimize vent header pressure (A-i,hallway).

Enclosure 5.4 EP/1/A11800/OO1Makeup to the BWST {25} Page 13 of 37


50. — Monitor the following for unexpectedlevel changes:

. 1BBHUT

. Unit 1 CBAST

51. Notify Unit 2 to monitor the followingfor 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 HoldupTank Supply)(A-i, hallway S of freight elevator).

54. — Determine and correct cause ofunexpected level change.

55. — GO TO Step 46.

56. WHEN DW addition to 1A BHUT iscomplete,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 fori/2 hour,

THEN notify Primary Chemistry toobtain 1A BHUT boron sample.

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

Enclosure 5.4 EP/1!AJi800!oolMakeup to the BWST {25} Page 11 of 37


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/Osheet:

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 GasTanks.

48. — Locally open 1DW-174 (Bleed HoldupTank Supply) (A-i, hallway S of freightelevator).

49. — Locally throttle 1CT-87 (Condensate ToBHUT 1A) as necessary to control flowand minimize vent header pressure (A-i,hallway).

Enclosure 5.4 EP/1/A/l800/ooiMakeup to the BWST {25} Page 13 of 37


50. — Monitor the following for unexpectedlevel changes:

. 1BBHUT

• Unit 1 CBAST

51. — Notify Unit 2 to monitor the followingfor 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 HoldupTank Supply)(A-i, hallway S of freight elevator).

54. — Determine and correct cause ofunexpected level change.

55. TO Step 46.

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


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 for1/2 hour,

THEN notify Primary Chemistry toobtain 1 A BHUT boron sample.

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

Enclosure 5.4 EP/1/A/1800/OO1Makeup to the BWST {25} Page 15 of 37


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 toBWST

Makeup to BWST required

THEN perform Steps 63 - 71.

63. Close 1HP-16.

64. Perform the following:

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

B. ?IDo not operate 1HP-16” onTIO sheet.

65. Notify RP to perform the following:

Perform surveys around BWST duringtransfer.

Adjust BWST radiological boundaries asnecessary.

66. Ensure NONE of the following are inrecirc:

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 AddPump)

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 TransferPumps Disch Tie) (A-i, RC BleedTransfer Pump Rm).

Enclosure 5.4 EP/1/All800/oolMakeup 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 toBWST from 1A BHUT)

Enclosure 5.4 EP/1/A!1800/001


[ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

70. 1CS-46.

71. Locally throttle SF-47 (SF Filter OutletTo Unit 1 BWST) based on thefollowing (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 conditionsexist:

BWST makeup NO longer required

1ABHUT1eve1 15”

1A BLEED TRANSFER PUMPstopped due to low level in 1ABHUT


73. — Stop 1A BLEED TRANSFER PUMP.

74. Close 1CS-46.



LWD-156 (SF IX Sluice)(Rm 218, SF CoolerRm)

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

NOTE

At this point, repeated batches from 1A BHUT can be used to makeup to the BWST or lB BHUTcan 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/oolMakeup to the BWST {25} Page 18 of 37

IF AT ANY TIME:


(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/oolMakeup to the BWST {25} Page 19 of 37


NOTE

Preparations for mixing another batch in 1A BHUT can be made while 1A BHUT is beingtransferred to the BWST. If another batch will be necessary, returning to Step 1 will direct actionsto mix a boron batch in the BAMT for transfer to CBAST if the CBAST does NOT containsufficient volume for boron addition to 1A BHUT. This should minimize the time between batchesfrom 1A BHUT to the BWST.

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

78. — WHEN makeup operations to theBWST are complete,THEN notify RP of completion.

79. Perform the following:

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

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

80. — EXIT this enclosure.

•..END...

Enclosure 5.4 EPI1/Ail800/oolMakeup to the BWST {25} Page 20 of 37

IF AT ANY TIME:






Enclosure 5.4EP/1/A11800/ool



Unit Status

Alternating batches from 1A and lB BHUTs to the BWST is desired.

81. Determine current volume in lB BHUTusing py of the following:— OAC graphic CSOI— BHUT Volume vs Level Curve in

OP/0/A11 108/00 1 (Curves and GeneralInfonnation).

82. — Determine volume of CBAST and DWrequired per the following to yield avolume in lB BHUT of 80,000 to82,000 gals at a concentration thatcomplies with COLR requirements forthe BWST:

Where:

BHUTf Final BHUT volume (gal)

BHUT1 = hiitial BHUT volume (gal)

BHUTf Final BHUT conc (ppmb)

BHUT1 Initial BHUT conc (ppmb)

CBAST = CBAST conc (ppmb)

(BHUTVf x BHUTCf) - (BHUT1 x BHUT1)

_________________________________________

= # gallons of CBAST neededCBAST

(____

___)..( ___ ___

)# gallons of CBAST needed

BHUTf - BHUT1 - # gallons CBAST needed = # gallons of DW needed

# gallons of DW needed

Enclosure 5.4 EP/1/All800/’oolMakeup to the BWST {25} Page 22 of 37

IF AT ANY TIME:


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




Enclosure 5.4 EP/1/A1i800/00iMakeup to the BWST {25} Page 23 of 37


83. quantity of boron needed for — GO TO Step 85.transfer to lB BHUT is available in theCBAST without going below minimumSLC 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” viaDW-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 HEATERswitch in AUTO (A-2, 1 &2 ChemAdd Panel).

D. WHEN Unit 1&2 BAMTtemperature is 127°F,THEN notify Primary Chemistry toadd chemicals.

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

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

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

B. Open the following:

CA-4 (Unit 1/2 BAMT Outlet)


89. 1CS-62.

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

2._ GOTO Step 93.

Enclosure 5.4 EP/1/AJl800/oolMakeup to the BWST (25} Page 24 of 37

IF AT ANY TIME:


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


• 1 A BHUT level 15”


Enclosure 5.4 EP/1/A11800/oolMakeup to the BWST {25} Page 25 of 37


91. — Locally open CA-il (AJB LP BAMTPumps Disch Tie) (A-i, l&2 BAMTRni).

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

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

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

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

A. — Place Unit 1 &2 BAMT HEATERswitch in OFF.

B. — Stop Unit l&2 BAMT AGITATOR.

96. — WHEN transfer is complete,THEN locally stop the selected LP BoricAcid Pump (A-2, 1&2 Chem AddPanel).

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

A. — Close CA-4 (Unit 1/2 BAMTOutlet).

B. — Open DW-1 19 (Boric Acid MixPumps Suction Hdr Flush).

98. — Locally start previously running LPBoric Acid Pump (A-2, 1 &2 Chem AddPanel).

99. WHEN LP Boric Acid Pump has run for5 minutes,THEN locally stop LP Boric Acid Pump(A-2, i&2 Chem Add Panel).

Enclosure 5.4EP/1!AJ8OO!oO


IF AT ANY TIME:





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

Enclosure 5.4 EP/1./A11800/ooiMakeup to the BWST {25} Page 27 of 37


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


DW- 119 (Boric Acid Mix PumpsSuction 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 BAMTPumps Disch Tie) (A-i, 1&2 BAMTRm).

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

105._ Verify quantity of boron needed for 1. Notify Primary Chemist of volumetransfer to lB BHUT is available in the removed from Unit 1&2 BAMT.CBAST without going below minimum 2 GO TO Step 86SLC required for CBAST.

106._Open 1CS-64.

107. Start 1A CBAST PUMP.

1 08._ Inform Jj units to monitor for reactivityeffects due to possible leakage ofCBAST 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 isdesired,THEN close 1CS-56.

111._Close 1CS-51.

Enclosure 5.4EP/1/AIl800/ool


IF AT ANY TIME:






Enclosure 5.4EP/1/A!1800/ooi



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

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

B. — Open 1CS-58 (Bleed Tank lBRecirculation).

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

1 13. Locally open 1CS-66 (CBAST Tie ToBleed 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 unexpectedlevel 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 ofunexpected level change.

120._GO TO Step 81.

121._WHEN CBAST addition to lB BHUT iscomplete,THEN stop lB BLEED TRANSFERPUMP.

Enclosure 5.4EP/1/AIl800/ool

Makeup to the BWST (25} Page 30 of 37

IF AT ANY TIME:


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




Enclosure 5.4EP/1!A/l800/ool



1 22._ Locally close 1 CS-66 (CBAST Tie ToBleed 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 PumplB Suction Tie).

B. — Open 1CS-149 (Bleed Tank lBOutlet Block).

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

required.

125._ Ensure space is available in Waste GasTanks.

126._Locally open 1DW-174 (Bleed HoldupTank Supply) (A-i, hallway S of freightelevator).

127._Locally throttle 1CT-88 (lB BHUTCondensate Supply) as necessary tocontrol flow and minimize vent headerpressure (A-i, N wall of Unit 1 BTPRm).

128._ Monitor the following for unexpectedlevel changes:

. 1ABHUT

• Unit I CBAST

129. Notify Unit 2 to monitor the followingfor unexpected level changes:

. 2ABHUT

. 2B BHUT

• Unit 2 CBAST

Enclosure 5.4EP/1IA!18001001


IF AT ANY TIME:






Enclosure 5.4EP/1/A11800/001



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 HoldupTank Supply) (A-i, hallway S of freightelevator).

132. Determine and correct cause ofunexpected level change.

133. GO TO Step 124.

134._WHEN DW addition to lB BHUT iscomplete,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 90-110psig discharge pressure on lB BLEEDTRANSFER PUMP (A-i, BleedTransfer Pump Rm).

138. WHEN lB BHUT has been in recirc for1/2 hour,

THEN notify Primary Chemistry toobtain lB BHUT boron sample.

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

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

limits for BWST boron requirements.

Enclosure 5.4EP/11A11800/OOl


IF AT ANY TIME:






Enclosure 5.4 EP/1/A/l800/oolMakeup to the BWST {25} Page 35 of 37


141._IAAT the following conditions exist: — GO TO Step 147.

1A BHUT NOT being transferred toBWST

Makeup to BWST required


142.Ensure NONE of the following are inrecirc:

Unit I BWST

Unit 2 BWST

1&2 SFP

143.Locally open the following:


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 OutletTo Unit I BWST) based on thefollowing (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 conditionsexist:

BWST makeup NO longer required

lB BHUT level 15”

lB BLEED TRANSFER PUMPstopped due to low level in lBBHUT


Enclosure 5.4EP/1/A/l800!ool


IF AT ANY TIME:




• IA BHUT level 15”


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

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


• lB BHUT level 15”

• lB BLEED TRANSFER PUMP stopped due to low level in lB BHUT...(stop makeup)

Enclosure 5.4EP/1/A11800/ool

Makeup to the BWST 25} Page 37 of 37

ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED I148. 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 AddPump)

LWD-156 (SF IX Sluice)(Rm 218, SF Cooler Rm)

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

NOTEPreparations for mixing another batch in 1A BHUT can be made while 1A BHUT is beingtransferred to the BWST. If another batch will be necessary, returning to Step 1 will direct actionsto mix a boron batch in the BAMT for transfer to CBAST if the CBAST does NOT containsufficient volume for boron addition to 1 A BHUT. This should minimize the time between batchesfrom 1A BHUT to the BWST.

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

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

153.Perform the following:

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

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

154. EXIT this enclosure.

.. . END...


ADMIN-1 24

Determine Minimum Shift Staffing

Admin-124 ESPage 1 of 9

CANDIDATE

EXAMINER



Task:

Determine MINIMUM staffing requirements for the shift for NED’s, RD’s and SRO’s.

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 staffingrequirements for the shift.


Simulator

______

In-Plant

______


_____

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:

_______


______

UNSAT

______

Performance Time

________

Examiner:

________________________________

/NAME SIGNATURE DATE

Comments

NONE




ToolsIEg ui pmentlProcedu res Needed:SLC 16.13.1-1Technical Specification

READ TO OPERATOR

DIRECTIONS TO STUDENT

I will explain the initial conditions, and state the task to be performed. All control roomsteps shall be performed for this JPM, including any required communications. I willprovide initiating cues and reports on other actions when directed by you. Ensure youindicate to me when you understand your assigned task. To indicate that you havecompleted 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 firebrigade members

INITIATING CUE

What are the MINIMUM staffing requirements using the MINIMUM number of licensedpersonnel for the shift?

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

Position Minimum Number

OSM

STA

SRO*

RO

NLO

*Numr does not include OSM and STA positions

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 roombased 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 1-4controlled from one control room

STANDARD: 1 OSM, 1 STA, 4 SRO, 5 RO, and 8 NEO

COMMENTS:UNSAT


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 — SATas the fire brigade leader.

CUE: If asked, inform the candidate the NEO will be assigned as the fire brigadeleader.

— 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 asfire brigade leader: — SAT

1 OSM, 1 STA,3SRO,5R0,and9NEO

COMMENTS:— UNSAT

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 applyingSAT

1 OSM, 1 STA, 3 SRO, 6 RC, and 9 NEC —

COMM ENTS:— UNSAT

STEP 8:

STANDARD:

COMMENTS:

STEP 9:

STAN DARD:

COMMENTS:

STEP 10:

STANDARD:

Adjust NEO staffing numbers per Step 6

Add 2 NEOs based on TS 3.5.2.B applying1 OSM, 1 STA, 3 SRO, 6 RO, and 11 NEC

Evaluate SRO requirement during fuel handling

Conclude the RB SRO supervising core alterations in the RB is includedin the SRO requirement of table 16.13.1-1.1 OSM, 1 STA, 3 SRO, 6 RO, 11 NEC

Determine total staffing requirements

I OSM, I STA, 3 SRO, 6 RO, 11 NLO


OSM I

STA I

SRO 3

RO 6

NLO II

Admin-124 ESPaqe7of9

SAT

UNSAT

SAT

UNSAT

CRITICAL STEP

SAT

UN SAT

COMMENTS:

TIME STOP:

_______

END OF TASK


STEP # Explanation

10 Determine staffing requirements




INITIAL CONDITIONS

• Unit 1 = 100% power

• Unit2 = 73%> 2A HPI Pump tagged out for the last 4 days

• Unit3 = REQCore 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 licensedpersonnel for the shift?

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


OSM

STA

SRO*

RO

NLO

*Numr does not include OSM and STA positions

Minimum Station Staffing Requirements16.13.1

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 andshall meet the following additional requirements:

1. At least one RO per unit shall be present in the control room whenfuel 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 controlroom.

2. At least one licensed operator shall be in the reactor buildingwhen fuel handling operations in the reactor building are inprogress. In addition, during CORE ALTERATIONS including fuelloading and transfer, an SRO or an SRO limited to fuel handlingshall be present to directly supervise the activity and, during thistime, shall not be assigned to other licensed activities

3. If the computer for a reactor is inoperable for more than eighthours, an operator, in addition to those specified in ITS 5.2.2.band 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 hoursminimum 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


Table 16.13.1-1

MINIMUM STATION STAFFING REQUIREMENTS

THREE UNITS TWO UNITS IN TWO UNITS IN ONE UNIT IN THREE UNITSIN MODES 1-4 MODES 1-4 MODES 1-4 MODES 1 -4 IN MODES 5 OR

CONTROLLED CONTROLLED 6 OR NO MODEFROM iWO FROM ONECONTROL CONTROLROOMS ROOM

OSM 1 1 1 1 1

STA 1 1 1 1 1

SRO1 5 5 4 4 3

RO3 6 5 5 4 3

NLO12 8 8 8 8 7

SPOC 7 7 7 7 6

Chemistry1 1 1 1 1Technician

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 NLOnumber 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


BASES

Some of the requirement(s) of this SLC section were relocated from TS 6.1.1.9 and TS Table6.1-1 during the conversion to ITS. These requirements were initially relocated to SLC16.13.5, “Additiona’ Operating Shift Requirements,” dated 3/27/97.

The requirements of this SLC consolidate ONS station staffing requirements into onedocument. This SLC includes the shift manning requirements of ITS 5.2.2, 10 CFR 50Appendix R Section IILH, 10 CFR 50.54.m, Operations Management Procedures (OMPs), NSD112, 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 dated3/27/99. The numbers for each position per shift are additive. For example, Table 16.13.1-1requires a total of 5 SROs per shift (3 SROs required by 10 CFR 50.54(m)(2)(i) plus 1additional SRO for the Fire Brigade and 1 additional for the ERO). The bases for the numbersin 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 byOMP).

1 STA (active or inactive SRO) Required by ITS 5.2.2.g which indicates theindividual fulfilling the STA position is the ShiftWork Manager (implemented by OMP). Revision50 to OMP 2-1 renamed the person fulfilling thisposition an STA. Note that pre-conversion TSTable 6.1-1, which implemented NUREG-0737requirements, did not require an STA on shift whenno units were in MODES 1-4. The SLC Table ismore restrictive in that it requires an STA on shift atall times.

3 SRO’s (active SRO) Required by 10 CFR 50.54(m)(2)(i). Per ITS5.2.2.b and 10 CFR 50.54(m)(2)(iii) at least 2SRO’s 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 qualifiedto be a fire brigade leader. Per OMP this individualfunctions as fire brigade leader and is not availablefor control room activities when directing the firebrigade. Appendix R does not specify that thebrigade leader be an SRO, it only specifies that thefire brigade leader have sufficient training in orknowledge of plant safety-related systems tounderstand the effects of fire and fire suppressionsystems on safe shutdown capability. When an

16.13.1-3 05/13/04


NLO is serving as the fire brigade leader, the SROnumber for each column in Table 16.13.1-1 may bereduced by one.

1 SRO (licensed or previously Required by Volume A, Section B, Figure B-2 oflicensed) - ERO the Emergency Plan. Implemented by OMP. SRO

serves as the offsite communicator and the NRCcommunicator in the CR/TSC. This is permissiblesince the offsite communicator role is completedprior to the NRC communicator role starting.

5 RO’s 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 tooperate the SSF will be exclusive of the fire brigadeand the minimum operating shift that is required tobe present in the Control Room. ITS 5.2.2.b andlOCFR 50.54(m)(2)(iii) require 3 of the 5 RO’srequired by 10 CFR 50.54(m)(2)(i) to be present inthe control room when fuel is in the reactor. Whenall three units are in MODES 1-3, one RO per unitmust be available to be dispatched to the SSF.Since 3 RO’s must be present in the Control Roomonly two are available to dispatch to the SSF.Therefore, one additional RO, beyond what isrequired by 10 CFR 50.54(m)(2)(i), is required.

1 RO - ADV Amendment 314, 314, 314 requires that staffinglevel be increased by an additional RO beyondwhat is required in Table 16.13.1-1 when inCondition B of ITS 3.5.2. The additional RO isdesignated to respond to an event requiringactivation of the SSF for the unit operating underITS 3.5.2 Condition B. The additional RO role maybe fulfilled by an SRO as long as the SRO is notbeing counted towards the number of requiredSROs listed in Table 16.13.1-1 and is qualified totasks involving operation of the SSF systems.When all three units are in MODES 1-4, a total ofseven ROs are required; five per 10 CFR50.54(m)(2)(l), one per ITS 5.2.2.h, and one perITS 3.5.2 Condition B.

8 NLO’s Required by 10 CFR 50 Appendix R Part lll.H, ITS5.2.2.a, Volume A, Appendix 8, Spill Prevention

16.13.1-4 05/13/04


and Control and Counter Measures Plan, Revision98-04, 10/98 of the Emergency Plan, and VolumeA, Section B, Figure B-8 of the Emergency Plan.Implemented by OMP. (Four for fire brigade, oneNLO per Unit to complete critical AP and EOPactions and 1 for SSF equipment verification for thedesign basis Appendix R fire.) When an NLO isserving as the fire brigade leader, the NLO numberfor each column in Table 16.13.1-1 must beincreased by one or one fire brigade member mustbe supplied from another organization.

The number of NLOs that are fire brigade qualifiedmay be reduced provided that a like number of firebrigade qualified personnel are provided from otherorganizations. This does not change the totalnumber of NLOs required; only the numberrequired to be fire brigade qualified.

2 NLO’s — ADV License Amendment 314, 314, 314 requires thatstaffing levels be increased by an additional twoNLO’s beyond those required in Table 16.13.1-1when in Condition B of ITS 3.5.2. The additionalNLO’s are designated for the purpose of operatingthe Atmospheric Dump Valves (ADVs) for the unitunder ITS 3.5.2 Condition B. In addition, the NLO’swith the responsibility for operating the ADVs willbe designated to respond to the control room withinfive minutes and will not be given duties that willprevent this from happening.

7 SPOC Required by Volume A, Section B, Figure B-8 ofthe Emergency Plan and the Fire Plan (Volume A,Appendix 8, Spill Prevention and Control andCounter Measures Plan, Revision 98-04, 10/98).Implemented by OMP 1-7 and NSD 112. Consistsof two I&E technicians ERO qualified andknowledgeable of IP/0/A0050/003 (Power SSFSubmersible Pump), two MM technicians EROqualified and knowledgeable of MP/0/AI1 300/059(Install SSF Submersible Pump), one supervisor ortemporary supervisor qualified to establish theOSC and perform the OSC MaintenanceSupervisor functions, and one additional person tohelp with pump installation as directed by SPOCsupplied by one of the following groups in the order

16.13.1-5 05/13/04


listed: SPOC, other maintenance personnel onsite,C&F, Chemistry, RP and Maintenance Overtimeresources. Security will automatically supply oneSecurity Guard to open doors and gates who willalso assist with any maintenance activities to beperformed. The Security Guard is counted as oneof a total of 6 people needed to install thesubmersible pump. One other person is needed toestablish the OSC for a total of 7. In the event of afire, SPOC will respond to the fire until directed toinstall the submersible pump. A total of 5 SPOCpersonnel are assigned to the fire brigade. Per PIP4-099-2987 problem evaluation, it is acceptable toconsider these additional 5 Fire Brigade membersto be available for other duties, such as installationof the SSF pump. This is based on Oconee FireBrigade Guide #2, which contains guidance thatallows fire brigade members to be released fromthe brigade for operational needs at the discretionof the OSCITSC.

The number of SPOC personnel qualified as firebrigade members may be reduced, provided thatthe qualified fire brigade members from otherorganizations are increased by a like number. Thisdoes not change the total number of SPOCpersonnel required, only the number required to befire brigade qualified.

1 Chemistry Technician - ERO Required by Volume A, Section B, Figure B-8 ofthe Emergency Plan. Implemented by OMP andStation Chemistry Manual 2.6. A ChemistryTechnician who is fire brigade qualified may becredited toward fulfilling the ERO requirement andthe fire brigade requirement. In the event of a fire,the Chemistry technician will respond to the fireuntil directed otherwise.

3 RP Technicians Three are required by Volume A, Section B, FigureB-8 of the Emergency Plan. One is required byITS 5.2.2.d and may be counted towards fulfillingthe ERO requirement. Implemented byHPIOIBI1000IO54. RP technicians who are firebrigade qualified may be credited toward fulfillingthe ERO and TS requirements and the fire brigaderequirement. In the event of a fire, the RP

16.13.1-6 05/13/04


technician will respond to the fire until directedotherwise.

Minimum Station Staffing numbers for the SRO and RO positions in Table 16.13.1-1 change asa function of the number of units in MODES 1-4 and whether the operating Units are controlledfrom one or two Control Rooms. The number for the remaining positions in Table 16.13.1-1 isnot 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 controlledfrom two Control Rooms, 2 SROs when two units are in MODES 1-4 and controlled from acommon control room, 2 SROs when one unit is MODES 1-4 and 1 SRO when no units areMODES 1-4. Thus considering fire brigade and ERO requirements, this results in therequirement for 5 SROs when two units are in MODES 1-4 and controlled from two ControlRooms, 4 SROs when two units are in MODES 1-4 and controlled from a common controlroom, 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 controlledfrom two Control Rooms, 4 ROs when two units are in MODES 1-4 and controlled from acommon control room, 4 ROs when one unit is MODES 1-4 and 3 ROs when no units areMODES 1-4. OMPs require 2 ROs to man the SSF when two units are in MODES 1-3 and1 RO when one unit is MODES 1-3. None are required when no units are in MODES 1-3.Therefore, no additional RO’s are required beyond what is required by 10 CFR50.54(m)(2)(i) when less than three units are in MODES 1-3 with one exception. When twounits are in MODES 1-3 and controlled from one Control Room one additional RO isrequired since 10 CFR 50.54(m)(2)(i) only requires 4 RO’s when the two operating units(Units 1 and 2) are controlled from one control room. Since one RO (or SRO) must bepresent in the Control Room when fuel is in the reactor vessel, the two RO’s required toman the SSF for the operating units are exclusive of the one RO required for each unit.Therefore, a total of 5 RO’s are required for this configuration.

The minimum staffing number for the SPOC and NLO positions is reduced by one when allthree units are in MODE 4 or below. This reduction is allowed since the SSF is not required tobe OPERABLE in these MODES. Therefore, there is no need for SPOC to provide a qualifiedindividual 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 control room when fuel isin the reactor and one SRO to be present in the control room while in MODES 1-4. Thisrequirement is based on 10 CFR 50.54(m)(2)(iii) and ITS 5.2.2.b. The first part of SLC16.13.1 .a.2, which requires at least one licensed operator to be in the reactor building when fuelhandling operations in the reactor building were in progress, was relocated during the ITSconversion from TS Table 6.1-1, Additional Requirement 3. This requirement has existed sincethe 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 directlysupervise CORE ALTERATIONS including fuel loading or transfer and be assigned no otherduties, 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


addition to those specified in ITS 5.2.2.b to supplement the control room staff if the computerfor a reactor is inoperable for more than eight hours, was relocated during the ITS conversionfrom TS Table 6.1-1, Additional Requirement 6. This requirement has also existed since theinitial issuance of Oconee Technical Specifications. SLC 16.13.1.b, which specifies the STAshall 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 andconsequences of postulated fires. Despite designed active and passive Fire ProtectionSystems installed throughout the plant, a properly trained and equipped Fire Brigadeorganization of at least ten (Reference 8) members is needed to provide immediate response tofires that may occur at the site. This number is the result of a corrective action from Reference10. This Fire Brigade requirement is normally met by using one SRO (or NLO qualified to be afire brigade leader), 4 NLOs, and 5 SPOC personnel. However, this requirement can also bemet by using personnel from other organizations (e.g., Chemistry, Radiation Protection, andSecurity).

Fire Brigade equipment and training conform to Oconee’s commitments to Appendix A toBranch Technical Position 9.5-I and supplemental NRC Staff guidelines including Nuclear PlantFunctional Responsibilities, Administrative Controls and Quality Assurance.

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

The following requirement was relocated from the TS 6.1.1.8 during the conversion to ITS. Atraining program for the fire brigade shall meet or exceed the requirements of Section 27 of theNFPA 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 staffing levelsshall be restored within 2 hours. The 2 hour Completion Time is consistent with ITS 5.2.2.c andd which allows 2 hours to accommodate unexpected absence of on-duty shift crew membersprovided that immediate action is taken to restore the shift crew composition to within theminimum 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


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-21 2DETERMINE LTOP REQUIREMENTS

ADMIN 212 FSPage 1 of 12

CANDIDATE

EXAM IN ER

ADMIN 212 ESPage 2 of 12


Task:

Determine LTOP Requirements

Alternate Path:

No

Facility JPM #:

MODIFIED

K/A Rating(s):

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

Task Standard:

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


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:


______


Examiner: /NAME SIGNATURE DATE

COMMENTS

NONE



ADMIN 212 ESPage 4 of 12ToolslEguipmentlProcedures Needed:

Unit 1 Conditions For Determining LTOP Requirements (Last page of JPM)OP/I/A/i 104/049OP/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


I will explain the initial conditions, and state the task to be performed. All control room stepsshall be performed for this JPM, including any required communications. I will provideinitiating cues and reports on other actions when directed by you. Ensure you indicate tome when you understand your assigned task. To indicate that you have completed yourassigned task return the handout sheet provided.

INITIAL CONDITIONS

Unit 1 controlling procedure for unit shutdown and cooldown is in progress for entering a refuelingoutage. Plant conditions are as described in the attachment provided.

INITIATING CUES

Based on the conditions described above and by using any associated plant procedures, verifythat LTOP requirements are being met per the provided End. 4.13 (LTOP Requirements LogicDiagram) of OP/I /A/1104/049 (Low Temperature Overpressure Protection).

If being met, then all the LTOP requirements that ULTIMATELY result in LTOP not beingmet. If any requirements are being met, THEN document by listing on the provided copy of“LTOP Requirements Logic Diagram” End. 4.13 of OP/I/Ni 104/049, LTOP.


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 andUNSATdetermines that HPI is deactivated.

COMMENTS:

CRITICAL STEPSTEP 2:LTOP (CFT) Verify each CFT isolated per OP/i/Ni 104/049 (LTOP) when

— SATGET pressure 373 psig.

STANDARD: Determines from attachment that Core Flood Tanks (CFTs) are NOT UNSATisolated 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) SATVerify Pzr level within LTOP limits per heatup/cooldown curves inOP/0/Ni 108/001 (Curves And General Information).

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

COMMENTS:


STEP 4:LTOP (Pressurizer Heater Bank 3 or 4)Verify Pressurizer Heater Bank 3 OR 4 white tagged open perOP/i IN1 104/049 (Low Pressure Overpressure Protection (LTOP). SAT

STANDARD: Determines from attachment that Bank 4 Heaters are white tagged open.UNSATEither Bank 3 or 4 heaters being deactivated meets requirements.

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 operableUNSAT

COMMENTS:

STEP 6:LTOP (1RC-4)Verify 1 RC-4 open when the following conditions are met:

• PORV removedSAT• 1 RC-4 installed

• 1 RC-4 part of LTOP vent path

UNSATSTANDARD: Verifies 1 RC-4 is open; but none of the above conditions require 1 RC-4to be open

COMMENTS:


STEP 7:LTOP (RC Pressure)

— SATVerify RCS <525 psig when RCS > 220°F and 325°F.OR

Verify RCS <375 psig when RCS 220°F.

UNSATSTANDARD: 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) SATor HPI Pumps NOT capable of starting and injection into RCS via 1HP-120.

STANDARD: 1HP-120 Travel Stop operableUNSAT

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. UNSATIF 01 L31 53 in alarm, evaluate LTOP input points valid by using LTOP OACScreen.Refer to OP/1/A/1104/049 (Low Temperature Overpressure Protection(LTOP).

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

COMMENTS:


STEP 10: SR 3.4.12.6LTOP (OAC Alarms) (260” Pressurizer Level Computer alarm.)

Verify the following:SAT1 SA-2/C-3 “RC Pressurizer Level High/Low” Statalarm card NOT Pulled.

f Either iSA/i 8/A-3 OR iSA/i 8/A-4 is in alarm OR card pulled, THEN verifythe following Computer Point status:— UNSAT• 01X2256

Quality = GOODValue = FALSE

• O1X2274Quality GOODValue = FALSE

• O1X2285Quality = GOODValue FALSE

STANDARD: Per attachment, SA Cards are not pulled and not in alarm

COMMENTS:

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

Verify 1 SA-2/C-4 “RC Pressurizer Level Emerg High/Low” Statalarm card SATNOT Pulled.

UNSATSTANDARD: Determines per attachment, SA card is IS PULLED

COMMENTS:


STEP 12: SR 3.4.12.6 CRITICAL STEPLTOP (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 STEPVerify LTOP requirements met per Enclosure ‘LTOP Requirements LogicDiagram’ of OP/i/Ni 104/049 (LTOP).

SATSTANDARD: 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 psi9 (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 ventpath) is NOT established

Candidate may list items such as the following that are LTOP gyrequirements not surveillance requirements. These shall not be countedas part of the required answers and are annotated as such on theprovided End. 4.13:

• Tc325°F

• RV Head Off / or SG Primary Manway Off / or Pzr Manway OffNOTE: Incorrectly listing a reason(s) that satisfies LTOP requirements or does

NOT ultimately result in requirements not being met will be countedtowards overall unsatisfactory completion of the task.

COMMENTS:

END OF TASK

STOP TIME:



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 installed with noHIGH 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 NOTestablished


INITIAL CONDITIONS

Unit 1 controlling procedure for unit shutdown and cooldown is in progress for entering a refuelingoutage. Plant conditions are as described in the attachment provided.

INITIATING CUES

Based on the conditions described above and by using any associated plant procedures, verifythat LTOP requirements are being met per the provided End. 4.13 (LTOP Requirements LogicDiagram) 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 beingmet. 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 Requirements(TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)Procedures in progress:

OP/I/Ni 102/010, Controlling Procedure for Unit Shutdown• 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 describedbelow can be assumed to be in the desired position/condition to support Unit l’s currentplant 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 tagged• I HP-26 and I HP-27 are closed; handwheels tagged; breakers tagged open• IHP-409 and -410 switches in CR have been tagged 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 pulled 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 breaker white tagged• No dedicated LTOP Operator assigned• An LTOP Vent path ( 3.6 square inches) is not established• I RC-4 is open

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Oconee Nuclear StationoP1l1A111o41049

LOW TEMPERATURE OVERPRESSURE Revision No.PROTECTION (LTOP) 045


Continuous Use OX002VM4

PERFORMANCE* * * * * * * * * * UNCONTROLLED FOR PRINT* * * * * * * * * *


OP/i/A/i 104/049Page 2 of 5

Low Temperature Overpressure Protection (LTOP)

1. Purpose

This procedure provides guidance to comply with Technical Specification (TS) 3.4.i2 andSLC 16.5.2 as well as provide protection from a low temperature overpressure (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 limitingLTOP event is NOT open

2.2 Conditions for which a dedicated LTOP Operator can compensate are shown graphicallyin Enclosure 4.13 (LTOP Requirements Logic Diagram).

NOTE: For purpose of performance of HPI Full Flow testing, LTOP controls are met by havingboth OTSG handholes removed.

2.3 The LTOP requirement of deactivating HPI can be considered met during HPI Systemtesting when a LTOP vent path 3.6 square inches is open. Refer toEnclosure 4.5 (LTOP Vent Paths) for vent path flow area sizes.

2.4 Refer to Enclosure 4.8 (LTOP Pressure Instruments) for detailed information concerningacceptable 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 3.4.12Condition F to monitor for an initiation of an LTOP event. Entry into this Condition isrequired any time a dedicated LTOP Operator is established.

2.7 Removing an ICCM Train from service renders the associated Pressurizer level(s) forthat ICCM train inoperable, and therefore the 260 inch audible Pressurizer level alarminoperable. A dedicated LTOP Operator will be required if the RCS < 325°F and a ventpath is NOT established.

OP/i/AR 104/049Page 3 of 5

2.8 A dedicated LTOP Operator is required when RCS 325°F and any of the followingadministrative controls CANNOT be implemented:

2.8.1 RCS closed (no LTOP vent path established),

AND HPI pump operating and capable of injecting into RCSvia 1HP-120 (RC VOLUME CONTROL),

AND 1HP-120 travel stop is inoperable.

2.8.2 RCS closed,

AND RCS has deviated from pressure, temperature, or level limits.2.8.3 RCS closed,

AND controls on use of high pressure Nitrogen NOT established.2.8.4 RCS closed,

AND number of available Pressurizer Heater 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 pressure alarms inoperable.2.9 When 1HP-120 travel stop is installed, available makeup flow is limited. RCS cooldownrate should be monitored and controlled.

2.10 At least one HPI train shall be available as a makeup source from the BWST whenever aRCS vent equivalent to two SG primary handholes one SG primary manway is NOTestablished. {3}

OP/i/A/i 104/049Page 4 of 5

2.11 OAC computer points:

2.11.1 When Computer Points are credited for LTOP, the Computer Pomts MUST beused from a Computer Display that indicates the Quality of the Computer Point.The point Value must represent actual plant conditions and the point QualityMUST indicate one of the following:• GOOD• INHB• LALM• HALM• LOLO• HIHI• ALM• DALM

2.11.2 Computer points 01 L3 154 (LTOP-RCS Pressure High (Channel 1)) andO1L3 156 (LTOP-Pzr Lvi High (Channel 1)) are non-credited backup LTOPalarms fed from the RC LR PRESS TRAIN ‘A’ instrument. Inoperability ofthese alarms requires no action.

2.11.3 Computer points 01L3 169 (LTOP-RCS Pressure High (Channel 2)) and01L3 168 (LTOP-Pzr Lvi High (Channel 2)) are the RCS high pressureand 225 inch Pzr level alarms that are credited in the LTOP analysis. Thesealarms receive pressure input from the RC LR PRESS TRAiN B instrumentwhich does NOT control the PORV. If either of these computer points isinoperable, entry into TS 3.4.12 Condition F is required.

2.12 Enclosure 4.13 (LTOP Requirements Logic Diagram) aids in determining if LTOPrequirements are satisfied. This diagram should be used as a reference when planning3 performing activities that may affect LTOP.

2.12.1 Enclosure 4.13 (LTOP Requirements Logic Diagram) should be verified asfollows:

• Applicable plant/equipment configuration status should be circled.

• Logic diagram path should be traced out to verify LTOP requirements aresatisfied.

2.13 Enclosure 4.15 (Swapping LTOP Components) is available for swapping to alternateconfiguration for LTOP components after LTOP has been set, if needed.

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

OP/i/A/l 104/049Page 5 of 5

Enclosure 4.1OP/i/A/i 104/049

Unit Startup Page 1 of 111. Initial Conditions

1.1 Review Limits and Precautions.

2. Procedure

NOTE: Enclosure 4.8 (LTOP Pressure Instruments) contains detailed information on acceptablepressure instruments to be used during LTOP conditions.

2.1 Prior to RxV Head installation perform Section 3 (LTOP Requirements For RxV HeadInstallation).

2.2 Prior to closing RCS (no LTOP vent paths available), perform Section 4 (LTOPRequirements For Closing RCS (No LTOP Vent Paths Available)).

2.3 Prior to HPI System Startup Or RCS> 100 psig, perform Section 5 (LTOP RequirementsFor 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).


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:


_____

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:


_____

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.



_____

3.4 Ensure a minimum of two CETCs are available and in service. {8}

______

3.5 Return to Section 2 (Procedure).


Unit Startup Page 4 of 114. 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. {3}SRO

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 forconvenience. LTOP Administrative Controls shall be established unless theassociated 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 perEnclosure 4.4 (Dedicated LTOP Operator Guidelines).



NOTE: • Control of the following breakers may be temporarily transferred toIP/0/B/0200/05 1 B (Reactor Coolant Narrow Range Functional Test) while this IP isin progress.

• White Tagging open Pressurizer Heater Bank 3 is preferred to maximize Pzr heatercapacity to establish a Pressurizer steam bubble. (Bank 3 has less heating capacitythan Bank 4) {1i}

• A dedicated LTOP Operator may NOT be used as a compensatory measure forconvenience. LTOP Administrative Controls shall be established unless theassociated condition CANNOT be met.


A. Perform one of the following to tag a Pressurizer Heater Bank:

1. IF desired to tag Pressurizer Heater Bank 3, perform 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)


• 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: A dedicated LTOP Operator may NOT be used as a compensatory measure forconvenience. LTOP Administrative Controls shall be established unless the associatedcondition CANNOT be met.


A. Verifi 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.


A. Verify NOT in alarm computer point O1L3 153 (ONE OR MOREINPUTS TO LTOP iNVALID).

_____


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) causingINVALID alarm.

B. Evaluate invalid LTOP computer points with LTOP points listed inEnclosure 4.7 (LTOP Computer Points) to determine which point(s) areNOT operable. {i0}

C. Take actions as necessary to return any inoperable points to service.


Unit Startup Page 7 of ii


4.3.6 1 SA- 1 8/A-3 “RVLIS/ICCM/RG 1.97 Train A Troublet’card pulled OR inalarm, 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

______


4.3.7 IF 1SA-18/A-4 “RVLIS/ICCM/RG 1.97 Train B Trouble” card pulled 2j inalarm, perform one of the following:

A. Verify the following Computer Point status: {7}


U Verify Quality GOOD

U Verify Value = FALSE

_____



______ ______

A. Verify RCS pressure/temperature is within limits of applicable LowRange Heatup curve.

_____






A. Verify Pzr level is within limits of Low Range Heatup curve.

_____



A. Verify 1SA-2/C-3 “RC Pressurizer Level HighlLow” Statalarm card NOTpulled AND NOT in alarm “HIGH”. {7}

_____


4.3.11 Perform pç of the following:

A. Verify 1 SA-2/C-4 “RC Pressurizer Level Emerg HighlLow” Statalarmcard NOT pulled AND NOT in alarm “HIGH”. {7}

______



Unit Startup Page 9 of 114.4 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 thefollowing:

_____

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 thefollowing:

_____

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 IHP-410 (1HP-26 BYPASS)4.7 Return to Section 2 (Procedure).


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 automaticallyoperable 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 InstrumentCalibration)

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 perOP/i/A/i 104/002 (HPI System).

5.2 Ensure established a dedicated LTOP operator per Enclosure 4.4 (Dedicated LTOPOperator Guidelines” due to 1HP-120 Travel Stop NOT being set.


Enciosure 4.1OP/i/A/i 104/049

Unit Startup Page 11 of 116. LTOP Verification After HPI System Startup


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 (DedicatedLTOP Operator Guidelines).


Enclosure 4.2 oP/i/All 104/049Unit Shutdown Page 1 of 8

1. Initial Conditions


NOTE: Enclosure 4.8 (LTOP Pressure Instruments) contains detailed information on acceptablepressure 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 unitshutdown.

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 perIP/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 4.2oP/i/A/i 104/049

Unit Shutdown Page 2 of 82.1.4 Tag the following in preparation for establishing LTOP Administrative

Controls:

A. White Tag closed 1N-121 (Pzr High Pressure Supply). (R-3G East Sideat stairs)


• White Tagging open Pressurizer Heater Bank 3 is preferred. (Bank 3 has less heatingcapacity than Bank 4) { 11 }

B. Perform one of the following:




_____ _____





• White Tag open MCC 1XH-4A (PZR Htr. Group H Bkr)


Unit Shutdown Page 3 of 82.2 After RCS < 800 psig, complete CF Tank deactivation by performing the following:

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 following:

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 Of1HP-120 Travel Stop).


Unit Shutdown Page 4 of 82.5 WHEN RCS 345-325°F, perform the following.

NOTE: • A dedicated LTOP Operator may NOT be used as a compensatory measure forconvenience. LTOP Administrative Controls shall be established unless theassociated 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 HighPressure Supply). (R-3G, East side at stairs)

2. Ensure established a dedicated LTOP Operator perEnclosure 4.4 (Dedicated LTOP Operator Guidelines).


• White Tagging open Pressurizer Heater Bank 3 is preferred. (Bank 3 has less heatingcapacity 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

_____



Unit Shutdown Page 5 of 8NOTE: A dedicated LTOP Operator may NOT be used as a compensatory measure forconvenience. LTOP Administrative Controls shall be established unless the associatedcondition CANNOT be met.

C. Perform one of the following:

1. Verify OAC operable.



D. Perform ç of the following:

1. Verify NOT in alarm computer point 01 L3 153 (ONE OR MOREINPUTS TO LTOP INVALID).

______


E. jj computer point 01L3 153 (ONE OR MORE INPUTS TO LTOPiNVALID) is in alarm, perform the following:

_____

1. Bring up the LTOP OAC screen and view computer point(s) causingINVALID alarm.

__________

2. Evaluate invalid LTOP computer points with LTOP points listed inEnclosure 4.7 (LTOP Computer Points) to determine which point(s)are NOT operable. {10}

3. Take actions as necessary to return any inoperable points to service.

Enclosure 4.2OP/i/All 104/049

Unit Shutdown Page 6 of 8


F. IF 1SA-18/A-3 “RVLIS/ICCM/RG 1.97 Train A Troubl&’ card pulledOR in alarm, perform one of the following:

1. Verify the following Computer Point status: {7}


LI Verify Quality = GOOD

LI Verify Value = FALSE

• Computer Point O1X2274 (PZR LEVEL 2 HI)


LI Verify Value FALSE

______


G. 1SA-18/A-4 “RVLIS/ICCM/RG 1.97 Train B Troub1e card pulledOR in alarm, perform one of the following:

1. Verify the following Computer Point status: {7}



LI Verify Value = FALSE

_____


H. Perform one of the following:

1. Verify RCS pressure/temperature is within limits of applicable LowRange CooldownlHeatup curve.

______



Unit Shutdown Page 7 of 8


I. Perform one of the following:

______ ______

1. Verify Pzr level is within limits of applicable Low RangeCooldownlHeatup curve.

_____


J. Perform ç of the following:

______ ______

1. Verify 1 SA-2/C-3 ‘RC Pressurizer Level HighJLow Statalarm cardNOT pulled AND NOT in alarm “HIGH”. {7}

______


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}

_____


L. Perform one of the following:

1. Ensure PT/1/A/0202/014 (Setup Of 1HP-120 Travel Stop) complete.

_____



Unit Shutdown Page 8 of 82.6 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 “LOW”.

_____

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 UnitShutdown).

2.9 j Unit shutdown is for refueling:

_____

2.9.1 Contact OWPG Coordinator as to whether equipment White Tagged for LTOPpurposes 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 OfLTOP White Tags).


Securing From LTOP Prior to 350°F Page 1 of 21. Initial Conditions


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-Equip 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-Equip Rm)

_____

• 1XP-F5C (1CF-2 Bkr (lB CFT Disch Isol)) (T-3-Equip Rm)

_____

• 1HP-409 (1HP-27 BYPASS) switch


(CONTINUED ON NEXT PAGE)


Securing From LTOP Prior to 350°F Page 2 of 22.2 IF required, remove LTOP White Tags AND close the following Pressurizer Heaterbreakers:

____

• 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 Prior To Mode 2).

Enclosure 4.4OP/i/A/i 104/049Dedicated LTOP Operator Guidelines Page 1 of 6


NOTE: • The OATC may fulfill the duties of the LTOP Operator.

• Enclosure 4.8 (LTOP Pressure Instruments) contains detailed information onacceptable pressure instruments to be used during LTOP conditions.

• A dedicated LTOP Operator may NOT be used as a compensatory measure forconvenience.

_____

1.1 Verif,’ one or more of the conditions in Enclosure 4.16 (Establishing LTOPSRO Administrative Controls) CANNOT be met.

2. Procedure

NOTE: The following step is intended as an Operator aid to track conditions NOT met thatrequire establishing LTOP Operator. Conditions may be added/deleted by one-lining asnecessary.

2.1 IF desired, list conditions that require establishing of LTOP Operator (may useEnclosure/Step number if applicable):

2.2 Perform the following:

_____

2.2.1 Designate an RO or SRO as dedicated LTOP Operator.

_____

2.2.2 LTOP Operator review Limits and Precautions.

_____

2.2.3 LTOP Operator review Section 3 of this enclosure.

____

2.3 EnterTS3.4.l2ConditionF. {5}

2.4 LTOP Operator performs surveillance as required by Section 4.

2.5 WHEN LTOP Operator is no longer required, exit TS 3.4.12 Condition F.


Dedicated LTOP Operator Guidelines Page 2 of 63. 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 procedure prior to turning over LTOPresponsibility.

Enclosure 4.4OP/i/A/l 104/049

Dedicated LTOP Operator Guidelines Page 3 of 64. 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 toRCS pressure or RCS pressure instruments. {2}

Prior to relaxing Dedicated LTOP Operator requirements, computer points01A2004 (RC LR PRESS (TRAIN A)) and O1A2235 (RC LR PRESS TRAIN B))must be operable as defined by Limits And Precautions Step 2.10. {10}

4.2 IF available, trend LR Cooldown RCS Pressure points O1A2004 and O1A2235 to verifythe points track together.

4.3 IF either RC LR PRESS TRAIN A/B is unavailable, trend the operable computer pointand one of the RCS Wide Range pressure points (01A1416, 01A1417, or O1A1418) toverify the points track together.

4.4 Monitor the following indications to detect excessive makeup flow due to 1HP-120(RC VOLUME CONTROL) failing open:

• RCS Pressure.

• RCSMakeupFlow.

• Pzr Level.


Dedicated LTOP Operator Guidelines Page 4 of 64.5 excessive RCS makeup flow is indicated due to failing open of 1HP-120

(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 HPIPumps, as required, to prevent exceeding IRC-66 (PORV) setpoint and RCSP/T Limits.

_____

4.5.6 Refer to the following, as applicable:

• AP/1/A/1700/014 (Loss of Normal HPI Makeup And/Or RCP SealInjection)

• 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).


Dedicated LTOP Operator Guidelines Page 5 of 6

CAUTION: If the restrictions for RCS pressure or Pzr level are exceeded, the heatup/cooldownwill be stopped and acceptable RCS pressure and/or pzr level established within onehour.

NOTE: 1. Low Range Heatup/Cooldown curves are located in OP/0/AI1 108/001 (Curves andGeneral 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.


Dedicated LTOP Operator Guidelines Page 6 of 6


4.9 IF computer point 01L3 153 (ONE OR MORE INPUTS TO LTOP iNVALID) is inalarm, perfonu the following:

4.9.1 Bring up the LTOP OAC screen and view computer point(s) causingINVALID alarm.

4.9.2 Evaluate invalid LTOP computer points with LTOP points listed inEnclosure 4.7 (LTOP Computer Points) to detenuine which point(s) are NOToperable. {i0}

4.9.3 Take actions as necessary to return any inoperable points to service.

Enclosure 4.5

LTOP Vent Paths

Relief flow paths, other than those listed below, may be used.

Alternate paths must be analyzed by Safety Analysis Group prj.Qr to use.

NOTE: •

.



2. Procedure

2.1 If any of the following conditions exist, LTOP restrictions 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 benecessary 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) perstandpipe (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) perstandpipe 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)


OP/i/A/i 104/049Page 1 of2


LTOP Vent Paths Page 2 of 22.4 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)


Enclosure 4.6oP/i/Au 104/049

1HP-120 Travel Stop Removal Page 1 of 11. Initial Conditions


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 ofLTOP travel stop in the set and disengaged positions, and for wrench size needed.

2.2 Adjust 1HP-120 (RC VOLUME CONTROL) demand to verify 1HP-120actuator/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 theactuator base.

2.5 Adjust lower two hex nuts until travel stop plate contacts the upper hex nuts.

2.6 Tighten the lower hex nuts.

NOTE: Too rapid stroke of 1HP-120 will cause start of standby HPI Pump due to low RCPseal injection flow.

2.7 Perform a full stroke of 1HP-120 (RC VOLUME CONTROL) to verify travel stopis disengaged.

2.8 Set letdown flow as required per OP/i/A/i 103/04 (Soluble Poison Control).

2.9 Delete note from Unit 1 Turnover Sheet regarding 1HP-120 travel stop.


LTOP Computer Points Page 1 of 2NOTE: To be considered OPERABLE, a computer point’s Value must represent actual plantconditions and the point Quality MUST indicate one of the following:

• GOOD•INHB• LALM• HALM• LOLO• HIHI•ALM• DALM

Points Associated With LTOP Train 1LI 01A2004 - RC LR PRESS (TRAIN A) {10}LI O1D2605 - RC LR PRESS TRANS POWER LOSS (TRAIN A)Points Associated With LTOP Train 2

LI O1A2235 - RC LR PRESS (TRAIN B)LI O1D2979 - RC LR PRESS TRANS POWER LOSS (TRAIN B)LI O1D2125 —HPI PUMP 1ALI O1D2127 - HPI PUMP lBLI 01D2129-HPIPUMP 1CLI 01E2046 - RC COLD LEG Al WR TEMPLI O1E2044 - RC COLD LEG A2 WR TEMPLI O1E2017-RCCOLDLEGB1 WRTEMPLI 01E2040 - RC COLD LEG B2 WR TEMPLI O1E2275 - RC PZR LEVEL 1 TEMP CORRECTEDLI 01E2276 - RC PZR LEVEL 2 TEMP CORRECTEDLI O1E2277 - RC PZR LEVEL 3 TEMP CORRECTEDLI O1L3 154 - LTOP-RCS PRESSURE HIGH (CHANNEL 1)LI O1L3 169 - LTOP-RCS PRESSURE HIGH (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 RCO6 110 ERROR


LTOP Computer Points Page 2 of 2Points Associated With Both LTOP Trains

El 01D2978 - RC LR PRESS ENABLE SWITCHEl 01L3 155 - LTOP SYSTEM DISABLEDEl 01L3 153- ONE OR MORE INPUTS TO LTOP INVALID


LTOP Pressure Instruments {2} Page 1 of 1General Information

1. LTOP computer point 01 L3 153 (One Or More Inputs To LTOP Invalid) continuouslymonitors all computer points that have input to various LTOP control and alarmfunctions. If this alarm is received, steps shall be taken immediately to determine impacton LTOP System operability and compensatory 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 setpointand to the LTOP alarm logic. These alarms (OAC computer points 0 1L3 154 and01L3 156) are non-credited backup RCS high pressure and Pzr level alarms.

• IF RC LR PRESS TRAIN ‘A’ becomes inoperable, the PORV will beinoperable 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 availablefor operator action to mitigate an LTOP event. These alarms (OAC computer points01 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 153(One Or More Inputs To LTOP Invalid) should come into alarm, indicating thispath is unavailable on Enclosure 4.13 (LTOP Requirements Logic Diagram). Adedicated LTOP operator shall be established per Condition F of TS 3.4.12unless a LTOP vent is established.

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_________________________________________________________________

1l-I

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pute

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not

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Enclosure 4.14

LTOP Travel Stop Schematic

Note: L View rotated 90 degrees for clarity.2. 1-1/4 open end wrench needed to adjust travel stop.

OP/i/A/i 104/049Page 1 of I

Actuator Base

Upper Hex Nuts

Travel Stop Plate

Lower Hex Nuts

Actuator Stem

Actuator/ValveCoupling

Valve Stem

TT

L

LEfH

TRAVEL STOP DISENGAGED TRAVEL STOP SET

HPl2Olock Rev. 3.TCW3/7/02 rtr

Enclosure 4.15oP/i/AR 104/049

Swapping LTOP Components Page 1 of 51. Initial Conditions


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”


Swapping LTOP Components Page 2 of 53. lAilPiTrain

3.1 Deactivate 1A HPI Train by performing Step 3.1.1 or Step 3.1.2:


_____

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-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.


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:


_____

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)


_____ _____


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.


Swapping LTOP Components Page 4 of 55. 1ACFT

5.1 Deactivate 1A CFT by perfonuing Step 5.1.1 Step 5.1.2:


_____

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-Bunder IA CFT)

_____ _____

C. White Tag open 1XO-F5C (1CF-1 Bkr (IA CFT Disch)). (T-3-Equip Rm)

_____ _____

5.1.2 Ensure 1A CFT <373 psig


EncLosure 4.15OP/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:


_____

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.


Enclosure 4.16 OP/i/A/i 104/049Establishing LTOP Administrative Controls Page 1 of 2



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, requiringentry into TS 3.4.12.

2.1.2 Verify NOT in alarm computer point 01L3 153 (ONE OR MORE INPUTS TOLTOP INVALID).

2.1.3 IF 1SA-18/A-3 “RVLIS/ICCM/RG 1.97 Train A Troubl&’ card pulledOR in alarm, verify the following Computer Point status: {7}



D Verify Value FALSE



U Verify Value = FALSE

2.1.4 IF ISA-18!A-4 “RVLIS/ICCMJRG 1.97 Train B Trouble’ card pulledOR in alarm, verify the following Computer Point status: {7}


U Verify Quality = GOOD

U Verify Value FALSE

2.1.5 Verify RCS pressure/temperature is within limits of applicable Low RangeCooldownlHeatup curve.

Enclosure 4.16 OP/i/A/i 104/049Establishing LTOP Administrative Controls Page 2 of 2

2.1.6 Verify Pzr level is within limits of applicable Low Range Cooldown/Heatupcurve.

2.1.7 Verify I SA-2/C-3 “RC Pressurizer Level HighlLow” Statalarm card NOT pulledAND NOT in alarm “HIGH”. {7}

2.1.8 Verify 1 SA-2/C-4 “RC Pressurizer Level Emerg HighlLow” Statalarm card NOTpulled 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 heatingcapacity 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)

_____ _____


_____ _____


_____ _____


B. IF desired, Pressurizer Heater Bank 4: (A-4-452)

_____ _____


_____ _____


____ ____

• 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 HPIpumps are secured.

2.1.11 IF an HPI pump is operating aligned to RCS via 1HP-120 (RC VOLUMECONTROL), 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 LogicDiagram).

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



1.2 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)

_____


_____


______

• 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



1.2 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))


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 ofLTOP. Compensatory measures have been taken to establish a second train of OAC alarms using aconverted RCS NR pressure instrument. This instrument has been recalibrated to the same range asthe RCS LR pressure instrument.

3. PIP 0-98-02532: Shutdown Protection Plan (Station Directive 1.3.5) requires an HPI pump to beavailable before closing the RCS where a vent equivalent to two SG handholes or one primarymanway 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 (UnitShutdown) 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 pointsoperable.

11. PIP 0-09-1897 CA #5: White Tagging Pressurizer Heater Bank 3 is preferred for LTOP. (Bank 3has less heating capacity than Bank 4)


Admin-21 5

Determine Tech Spec requirementsfor inoperable Pzr Heaters


CANDIDATE

EXAMINER



Task:

Determine Tech Spec requirements for inoperable Pzr HeatersAlternate Path:

No

Facility JPM #:

NEW

KIA Rating(s):

System: GENK/A: 2.2.40Rating: 3.4/4.7

Task Standard:

Determine that minimum number of Pzr heaters for SSF operability are NOT operable and as a result TS 3.10.1Condition A must be entered. The Required Action and Completion Time is to restore Station ASW system toOperable within 7 days.

Preferred Evaluation Location:Preferred Evaluation Method:

Simulator In-Plant Classroom X Perform X SimulateReferences:

Technical Specifications

Validation Time: 15 minutesTime Critical: NO

Candidate:

_______________________________________

Time Start:NAME

Time Finish:Performance Rating: SAT

______

UNSATPerformance Time:

Examiner:

NAMESIGNATURE DATE

COMMENTS

None

Admin-215 FS

SIMULATOR OPERATOR INSTRUCTIONS:Page 3 of 7

Admin-215 FSPage4of7Tools/Equipment/Procedures Needed:

Technical Specifications

READ TO OPERATORDIRECTION TO TRAINEE:

I will explain the initial conditions, and state the task to be performed. All control roomsteps shall be performed for this JPM, including any required communications. I willprovide initiating cues and reports on other actions when directed by you. Ensure youindicate to me when you understand your assigned task. To indicate that you havecompleted your assigned task return the handout sheet I provided you.INITIAL CONDITIONS:

Unit 2 is operating at 100% power.

Pressurizer Steam Space Leakage 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 Pressurizer heaters are operable.2. As a result of your evaluation above, document all applicable Conditions, RequiredActions, and Completion Times (if any) below.


START TIME:

STEP 1: Candidate will evaluate Tech Spec requirements. CRITICAL STEP• Evaluate TS B 3.10.1 for Unit 2

SATSTANDARD: Determine that:

• For Unit 2 the maximum allowed Pzr Steam Space Leakage with 16Pzr heaters available is 0.10 gpm.— UNSAT

• As a result the minimum number of Pzr heaters for SSF operabilityare NOT operable.

COMMENTS:

STEP 2: Candidate will evaluate the Table on Page B 3.10.1-4. CRITICAL STEP

STANDARD: Determine that the SSF ASW system inoperable,SAT• TS 3.10.1 Condition A should be entered.

• Required Action and Completion Time is to restore Station ASW UNSATsystem to Operable within 7 days

Note: Although normally the SSF ASW System being inoperable would render ALLof the SSF inoperable. However in this case due to a note at the bottom of the tablethat is not true. If the SSF ASW System is inoperable due to Pzr heaters the other5SF systems are NOT inoperable.

COMMENTS:

END TASK

STOP TIME:


CRITICAL STEP EXPLANATIONS:

STEP #Exp’anation

I This step is required to determine if required SSF Pzr heaters are operab’e2 This step is required to ensure compliance with TS’s


DIRECTION TO TRAINEE:

I will explain the initial conditions, and state the task to be performed. All control roomsteps shall be performed for this JPM, including any required communications. I willprovide initiating cues and reports on other actions when directed by you. Ensure youindicate to me when you understand your assigned task. To indicate that you havecompleted your assigned task return the handout sheet I provided you.INITIAL CONDITIONS:

Unit 2 is operating at 100% power.

Pressurizer Steam Space Leakage = 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 Pressurizer heaters are operable.2. As a result of your evaluation above, document all applicable Conditions, RequiredActions, and Completion Times (if any) below.

3.10 STANDBY SHUTDOWN FACILITY

3.10.1 Standby Shutdown Facility (SSF)

LCO 3.10.1

APPLICABILITY:

ACTIONS

The SSF Instrumentation and the following SSF Systems shall beOPERABLE:

a. SSF Auxiliary Service Water System;

b. SSF Portable Pumping System;

c. SSF Reactor Coolant Makeup System; and

d. SSF Power System.

MODES 1, 2, and 3.

LCO 3.0.4 is not applicable.


A. SSF Auxiliary Service A.1 Restore SSF Auxiliary 7 daysWater System Service Water Systeminoperable, to OPERABLE status.

B. SSF Portable Pumping B.1 Restore SSF Portable 7 daysSystem inoperable. Pumping System toOPERABLE status.

(continued)

OCONEE UNITS 1,2, & 3 3.10.1-1 Amendment Nos. 300, 300, & 300

SSF3.10.1

ACTIONS (continued)

SSF3.10.1


C. SSF Reactor Coolant C.1 Restore SSF Reactor 7 daysMakeup System Coolant Makeupinoperable. System to OPERABLEstatus.

D. SSF Power System D.1 Restore SSF Power 7 daysinoperable. System to OPERABLEstatus.

E. SSF Instrumentation E.1 Restore SSF 7 daysinoperable. Instrumentation toOPERABLE status.

F. Required Action and F.1 Restore to OPERABLE NOTEassociated Completion status. Not to exceed 45 daysTime of Condition A, B,cumulative per calendarC, D, or E not metyearwhen SSF Systems or

Instrumentation areinoperable due to

45 days from discoverymaintenance,of initial inoperability

G. Required Action and G.1 Be in MODE 3. 12 hoursassociated CompletionTime of Condition F not ANDmet.

G.2 Be in MODE 4. 84 hoursOR

Required Action andassociated CompletionTime of Condition A, B,C, D, or E not met forreasons other thanCondition F.


SURVEILLANCE REQUIREMENTS

SSF3.10.1

SURVEILLANCE FREQUENCY

SR 3.10.1.1 NOTENot applicable to RCS temperature instrumentchannels.

Perform CHANNEL CHECK for each required 7 daysSSF instrument channel.

SR 3.10.1.2 Verify required SSF battery terminal voltage is 7 days125 VDC on float charge.

SR 3.10.1.3 Verify the day tank contains 200 gallons of 31 daysfuel.

SR 3.10.1.4 Verify the underground oil storage tank 31 dayscontains 25,000 gallons of fuel.

SR 3.10.1.5 NOTEAll DG starts may be preceded by an engineprelube period followed by a warmup periodprior to loading.

Verify the DG starts from standby conditions 31 daysand achieves steady state voltage andfrequency.

SR 3.10.1.6 Verify DG required air start receiver pressure 31 daysis 150 psig.

(continued)


SSF3.10.1

SURVEILLANCE REQUIREMENTS (continued)SURVEILLANCE FREQUENCY

SR 3.10.1.7 Verify the fuel oil transfer system operates to 92 daysautomatically transfer fuel oil from the storagetank to the day tank.

SR 3.10.1.8 Verify the fuel oil properties of the fuel oil 92 daysstored in the day tank and undergroundstorage tank are tested in accordance with,and maintained within the limits of the DieselFuel Oil Testing Program.

SR 3.10.1.9 NOTES1. DG loadings may include gradual

loading as recommended by themanufacturer.

2. Momentary transients outside the loadrange do not invalidate this test.

3. All DG starts may be preceded by anengine prelube period followed by awarmup period prior to loading.

Verify the SSF DG is synchronized and 92 daysloaded and operated for 60 minutes at aload 3280 kW.

SR 3.10.1.10 Verify for required SSF battery that the cells, 12 monthscell plates and racks show no visual indicationof physical damage or abnormal deteriorationthat could degrade battery performance.

(continued)

OCONEE UNITS 1,2, & 3 3.10.1-4 Amendment Nos. 331, 331, & 332 I

SURVEILLANCE REQUIREMENTS (continued)SURVEILLANCE

FREQUENCY

SR 3.10.1.1 1 Verify for required SSF battery that the cell to 12 monthscell and terminal connections are clean, tightand coated with anti-corrosion material.

SR 3.10.1.12 Verify battery capacity of required battery is 12 monthsadequate to supply, and maintain inOPERABLE status, the required maximumloads for the design duty cycle whensubjected to a battery service test.

SR 3.10.1.13 Perform CHANNEL CALIBRATION for each 18 monthsrequired SSF instrument channel.

SR 3.10.1.14 Verify OPERABILITY OF SSF valves in In accordance with theaccordance with the Inservice Testing Inservice TestingProgram.Program

SR 3.10.1.15 NOTENot applicable to the SSF submersible pump.

Verify the developed head of each required In accordance with theSSF pump at the flow test point is greater Inservice Testingthan or equal to the required developed head. Program

SR 3.10.1.16 Verify the developed head of the SSF 2 yearssubmersible pump at the flow test point isgreater than or equal to the requireddeveloped head.

SSF3.10.1

OCONEE UNITS 1,2, & 3 3.10.1-5 Amendment Nos. 328, 328 & 329 I

SSF3.10.1B 3.10 STANDBY SHUTDOWN FACILITY

B 3.10.1 Standby Shutdown Facility (SSF)

BASES

BACKGROUND The Standby Shutdown Facility (SSF) is designed as a standby systemfor use under certain emergency conditions. The system providesadditional “defense in-depth” protection for the health and safety of thepublic by serving as a backup to existing safety systems. The SSF isprovided as an alternate means to achieve and maintain the unit inMODE 3 with average RCS temperature 525°F (unless the initiatingevent causes the unit to be driven to a lower temperature) following 10CFR 50 Appendix R fire, sabotage, turbine building flood, station blackout(SBO) and tornado missile events, and is designed in accordance withcriteria associated with these events. In that the SSF is a backup toexisting safety systems, the single failure criterion is not required.Failures in the SSF systems will not cause failures or inadvertentoperations in other plant systems. The SSF requires manual activationand can be activated if emergency systems are not available.The SSF is designed to maintain the reactor in a safe shutdown conditionfor a period of 72 hours following 10 CFR 50 Appendix R fire, turbinebuilding flood, sabotage, SBO, or tornado missile events. This isaccomplished by re-establishing and maintaining Reactor Coolant PumpSeal cooling; assuring natural circulation and core cooling by maintainingthe primary coolant system filled to a sufficient level in the pressurizerwhile maintaining sufficient secondary side cooling water; andmaintaining the reactor subcritical by isolating all sources of ReactorCoolant System (RCS) addition except for the Reactor Coolant MakeupSystem which supplies makeup of a sufficient boron concentration.

The main components of the SSF are the SSF Auxiliary Service Water(ASW) System, SSF Portable Pumping System, SSF Reactor Coolant(RC) Makeup System, SSF Power System, and SSF Instrumentation.The SSF ASW System is a high head, high volume system designed toprovide sufficient steam generator (SG) inventory for adequate decayheat removal for three units during a loss of normal AC power inconjunction with the loss of the normal and emergency feedwatersystems. One motor driven SSF ASW pump, located in the SSF, servesall three units. The SSF ASW pump, two HVAC service water pumps,and the Diesel Service Water (DSW) pump share a common suctionsupply of lake water from the embedded Unit 2 condenser circulatingwater (CCW) piping. The SSF DSW pump and an HVAC pump must beoperable in order to satisfy the operability requirements for the PowerSystem. (Only one HVAC service water pump is required to be operableto satisfy the LCO.)

OCONEE UNITS 1, 2, & 3 B 3.10.1-1 BASES REVISION DATED 05/18/10

SSFB 3.10.1

BASES

BACKGROUND The SSF ASW System is used to provide adequate cooling to(continued) maintain single phase RCS natural circulation flow in MODE 3 with anaverage RCS temperature 525°F (unless the initiating event causes theunit to be driven to a lower temperature). In order to maintain singlephase RCS natural circulation flow, an adequate number of Bank 2,Group B and C pressurizer heaters must be OPERABLE. These heatersare needed to compensate for ambient heat loss from the pressurizer.As long as the temperature in the pressurizer is maintained, RCSpressure will also be maintained. This will preclude hot leg voiding andensure adequate natural circulation cooling.

The SSF Portable Pumping System, which includes a submersible pumpand a flow path capable of taking suction from the intake canal anddischarging into the Unit 2 CCW line, is designed to provide a backupsupply of water to the SSF in the event of loss of CCW and subsequentloss of CCW siphon flow. The SSF Portable Pumping System is installedmanually according to procedures.

The SSF RC Makeup System is designed to supply makeup to the RCSin the event that normal makeup systems are unavailable. An SSF RCMakeup Pump located in the Reactor Building of each unit suppliesmakeup to the RCS should the normal makeup system flow and sealcooling become unavailable. The system is designed to ensure thatsufficient borated water is provided from the spent fuel pools to allow theSSF to maintain all three units in MODE 3 with average RCS temperature525°F (unless the initiating event causes the unit to be driven to a lowertemperature) for approximately 72 hours. An SSF RC Makeup Pump iscapable of delivering borated water from the Spent Fuel Pool to the RCpump seal injection lines. A portion of this seal injection flow is used tomakeup for reactor coolant pump seal leakage while the remainder flowsinto the RCS to makeup for other RCS leakage (non LOCA).

The SSF Power System provides electrical isolation of SSF equipmentfrom non-SSF equipment. The SSF Power System includes 4160 VAC,600 VAC, 208 VAC, 120 VAC and 125 VDC power. It consists ofswitchgear, a load center, motor control centers, panelboards, remotestarters, batteries, battery chargers, inverters, a diesel generator (DG),relays, control devices, and interconnecting cable supplying theappropriate loads.

The AC power system consists of 4160 V switchgear OTS1; 600 V loadcenter OXSF; 600 V motor control centers XSF, 1XSF, 2XSF, 3XSF,PXSF; 208 V motor control centers 1XSF, 1XSF-1, 2XSF, 2XSF-1, 3XSF,3XSF-1; 120 V panelboards KSF, KSFC.

000NEE UNITS 1, 2, & 3 B 3.10.1-2 BASES REVISION DATED 05/18/10

SSFB 3.10.1

BASES

BACKGROUND The SSF 125 VDC Power System provides a reliable source of power for(continued) DC loads needed to black start the diesel. The DC power systemconsists of two 125 VDC batteries and associated chargers, two125 VDC distribution centers (DCSF, DCSF-1), and a DC powerpanelboard (DCSF). Only one battery and associated charger is requiredto be operable and connected to the 125 VDC distribution center tosupply the 125 VDC loads. In this alignment, which is normal, the batteryis floated on the distribution center and is available to assure powerwithout interruption upon loss of its associated battery charger or ACpower source. The other 125 VDC battery and its associated charger arein a standby mode and are not normally connected to the 125 VDCdistribution center. However, they are available via manual connection tothe 125 VDC distribution center to supply SSF loads, if required.The SSF Power System is provided with standby power from a dedicatedDG. The SSF DG and support systems consists of the diesel generator,fuel oil transfer system, air start system, diesel engine service watersystem, as well as associated controls and instrumentation. This SSFDG is rated for continuous operation at 3500 kW, 0.8 pf, and 4160 VAC.The SSF electrical design load does not exceed the continuous rating ofthe DG. The auxiliaries required to assure proper operation of the SSFDG are supplied entirely from the SSF Power System. The SSF DG isprovided with manual start capability from the SSF only. It uses acompressed air starting system with four air storage tanks. Anindependent fuel system, complete with a separate underground storagetank, duplex filter arrangement, a fuel oil transfer pump, and a day tank,is supplied for the DG.

OCONEE UNITS 1, 2, & 3 B 3.10.1-3 BASES REVISION DATED 05/18/10 I

BASES

SSFB 3.10.1

BACKGROUND The following information will aid in determination of SSF Operability:(continued)

a)C.,

a)Cl)

E0

U--D

>0Ea)

EG)0

U)

U)U)

Associated Inoperable Systems

SSF SSF SSF SSF SSFASW Portable RCMU Power InstrumentsSystem Pumping System SystemSystem

SSF ASWSystem YES YES YES YES YESSSFPortable YES YES YES YES YESPumpingSSF RCMUSystem NO NO YES NO NOSSF PowerSystem YES YES YES YES YESSSF Instr.System NO NO NO NO YESSSF PZR.Heaters** YES NO NO NO NOSSF RCSIsolation NO NO YES NO NOValvesSSF HVACSystem YES YES YES YES YES

** When SSF pressurizer heaters are inoperable, the resultinginoperability of the SSF ASW System does NOT render other SSFsystems inoperable.

SSF ASW System

Provides motive force for SSF ASW suction pipe air ejector. The airejector is needed to maintain siphon flow to the SSF HVAC service waterpump, the SSF DSW pump, and the SSF ASW pump when the waterlevel in the U2 CCW supply pipe becomes too low. If the SSF DSWpump becomes inoperable, the SSF Power System will becomeinoperable. Since an inoperable SSF Power System causes all otherSSF subsystems to be inoperable, an inoperable SSF ASW System willalso cause other SSF Subsystems to be inoperable.

Provides adequate SG cooling to reduce & maintain RCS pressure belowthe pressure where the SSF RC makeup pump discharge relief valve,HP-404, begins to leak flow. Therefore, full SSF RC Makeup Systemseal injection flow will be provided to the RC pump seals in time toprevent seal degradation or failure.

000NEE UNITS 1, 2, & 3 B 3.10.1-4 BASES REVISION DATED 05/18/10 I

SSFB 3.10.1

BASES

BACKGROUND SSF ASW pump should be operated when the diesel is operated to(continued) provide a load for the diesel. This is not a requirement for operabilitysince the diesel could be operated to provide long term power to one ormore units RC makeup pumps without operating the SSF ASW pump aslong as a large load (SSF ASW pump ) is not added later (dieseldesouping concern).

SSF Portable Pumping

Supplies makeup water to the SSF ASW System, the SSF DSW System,and the SSF HVAC Service Water System after siphon flow I gravity flowand forced CCW flow are lost.

SSF Power System

Other SSF Systems cannot operate without receiving power from thediesel for SSF scenarios where power from U2 MFB is not available.SSF Pressurizer Heaters

Single phase RCS natural circulation flow cannot be maintained withoutthe pressurizer heaters. The number of SSF heaters utilized is based ontesting and calculations performed on a unit by unit basis to determinethe minimum number of required heaters needed to overcome actualpressurizer ambient losses. Since the heaters do not have their ownaction statement, the SSF ASW System is declared inoperable whenthe 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 action statement. When they areinoperable, their corresponding SSF RC makeup system is consideredinoperable.

SSF HVAC System

Portions of the SSF HVAC System, consisting of the SSF AirConditioning (AC) and Ventilation Systems support the SSF PowerSystem OPERABILITY. The SSF AC System, which includes the HVACservice water system and AC equipment (fan motors, compressors,condensers, and coils), must be operable to support SSF Power Systemoperability. Since an inoperable SSF Power System results in all otherSSF subsystems being inoperable, an SSF HVAC System operabilityproblem that makes the SSF Power System inoperable also results inother SSF Subsystems being inoperable.


SSFB 3.10.1

BASES

BACKGROUND The SSF AC System is designed to maintain the SSF Control Room,(continued) Computer Room, and Battery Rooms within their design temperaturerange. Elevated temperatures in the SSF Control Room and ComputerRoom could cause the SSF Power System to fail during an accidentwhich requires operation of the SSF. The SSF AC System consists of tworefrigeration circuits and an air handling unit. The requirements for therefrigeration circuits vary with outdoor air temperature. Depending onoutdoor air temperature and Air Conditioning System performance, thetwo refrigeration circuits may not be required to support SSF powersystem OPERABILITY. The air handling unit is required to circulate airregardless of the number of refrigeration circuits required. Since the SSFHVAC service water pumps perform a redundant function, only one of thetwo are required to be operable for the SSF HVAC service water systemto be considered operable. The SSF Ventilation System, which suppliesoutside air to the Switchgear, Pump, HVAC and Diesel GeneratorRooms, is composed of the following four subsystems: ConstantVentilation, Summer Ventilation, On-line Ventilation, and DieselGenerator Engine Ventilation. These ventilation systems work together toprovide cooling to the various rooms of the SSF under both standby andon-line modes. The Diesel Generator Engine Ventilation fan is requiredfor operability of the SSF Power System. The six fans associated with theother three ventilation systems may or may not be required for SSFoperability dependent upon outside air temperature. If the SSF ACSystem refrigeration circuits or one of the ventilation fans fail, anengineering evaluation must be performed to determine if any of the SSFSystems or instrumentation are inoperable.

SSF Instrumentation System

SSF Instrumentation is provided to monitor RCS pressure, RCS Loop Aand B temperature (hot leg and cold leg), pressurizer water level, and SGA and B water level. Indication is displayed on the SSF control panel.

APPLICABLE The SSF serves as a backup for existing safety systems toSAFETY ANALYSES provide an alternate and independent means to achieve and maintainone, two, or three Oconee units in MODE 3 with average RCStemperature 525°F (unless the initiating event causes the unit to bedriven to a lower temperature) for up to 72 hours following 10 CFR 50Appendix R fire, a turbine building flood, sabotage, SBO, or tornadomissile events (Refs. 1,6, 7, and 8).

The OPERABILITY of the SSF is consistent with the assumptions of theOconee Probabilistic Risk Assessment (Ref. 2). Therefore, the SSFsatisfies Criterion 4 of 10 CFR 50.36 (Ref. 3).


SSFB 3.10.1

BASES

LCO The SSF Instrumentation in Table B 3.10.1-1 and the following SSFSystems 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 pressurizer heaters capableof being powered from the SSF, and an SSF ASW pump, piping,instruments, and controls to ensure a flow path capable of taking suctionfrom the Unit 2 condenser circulating water (CCW) line and discharginginto the secondary side of each SG. The minimum number of pressurizerheaters capable of being powered from the SSF is based on maintainingRCS natural circulation flow. The number of SSF controlled pressurizerheaters needed to meet this requirement is dependent upon ambient heatloss from the pressurizer and the steam leakage rate from thepressurizer. The following table provides combination of SSF controlledpressurizer heaters versus steam space leakage rates that have beenpreviously determined to meet Operability requirements for the SSF.This is based on an Oconee calculation, with additional margin to preventfrequent revision. Engineering Input is needed to determine if othercombinations of pressurizer heaters versus steam space leakage rate areacceptable.

Unit 1Number of Bank 2, Group B & C Maximum Allowed PressurizerPressurizer Heaters Available Steam Space Leakage

17 0.50 GPM16 0.25 GPM15 0.10 GPM14 0.00 GPM

Unit2Number of Bank 2, Group B & C Maximum Allowed PressurizerPressurizer Heaters Available Steam Space Leakage

18 0.50 GPM17 0.25 GPM16 0.10 GPM15 0.00 GPM


SSFB 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 GPM16 0.25 GPM15 0.10 GPM14 0.00 GPM

An OPERABLE SSF Portable Pumping System includes an SSFsubmersible pump and a flow path capable of taking suction from theintake canal and discharging into the Unit 2 CCW line. An OPERABLEReactor Coolant Makeup System includes an SSF RC Makeup pump,piping, instruments, and controls to ensure a flow path capable of takingsuction from the spent fuel pool and discharging into the RCS. Thefollowing leakage limits are applicable for the SSF RC Makeup System tobe considered OPERABLE:

Maximum Allowed Total Combined RCS Leakage for SSF RC MakeupSystem Operability

The “maximum allowed total combined RCS leakage” is 24.7 GPM. AUnit’s “total combined RCS leakage” shall be 24.7 GPM for itscorresponding 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.” TotalRC Pump Seal Return Flow is determined by summing the seal returnflow rate for all four RC Pumps. If the seal return flow rate for a RCPump is not available, 3.35 GPM may be used as the seal return flowrate for the affected pump. This worst case seal leakage occurs whentwo seal stages are failed with the third seal stage leaking maximumoutflow to the leakage system.

An OPERABLE SSF Power System includes the SSF DG, diesel supportsystems, 4160 VAC, 600 VAC, 208 VAC, 120 VAC, and 125 VDCsystems. Only one 125 VDC SSF battery and its associated charger arerequired to be OPERABLE to support OPERABILITY of the 125 VDCsystem.


SSFB 3.10.1

BASES (continued)

APPLICABILITY The SSF System is required in MODES 1, 2, and 3 to provide analternate means to achieve and maintain the unit in MODE 3 withaverage RCS temperature 525°F (unless the initiating event causes theunit to be driven to a lower temperature) following 10 CFR 50 Appendix Rfire, turbine building flood, sabotage, SBO and tornado missile events.The safety function of the SSF is to achieve and maintain the unit inMODE 3 with average RCS temperature 525°F (unless the initiatingevent causes the unit to be driven to a lower temperature); therefore, thisLCO is not applicable in MODES 4, 5, or 6.

ACTIONS The exception for LCO 3.0.4, provided in the Note of the Actions, permitsentry into MODES 1, 2, and 3 with the SSF not OPERABLE. This isacceptable because the SSF is not required to support normal operationof the facility or to mitigate a design basis accident.

A.1, B.1, C.1, D.1, and E.1

With one or more of the SSF Systems inoperable or the required SSFinstrumentation of Table B 3.10.1-1 inoperable, the SSF is in a degradedcondition and the system(s) or instrumentation must be restored toOPERABLE status within 7 days. The 7 day Completion Time is basedon the low probability of an event occurring which would require the SSFto be utilized.

F. 1

If the Required Action and associated Completion Time of Condition A, B,C, D, or E are not met when SSF Systems or Instrumentation areinoperable due to maintenance, the unit may continue to operateprovided that the SSF is restored to OPERABLE status within 45 daysfrom discovery of initial inoperability.

This Completion Time is modified by a Note that indicates that the SSFshall not be in Condition F for more than a total of 45 days in a calendar


SSFB 3.10.1

BASES

ACTIONS F.1 (continued)

year. This includes the 7 day Completion Time that leads to entry intoCondition F. For example, if the SSF ASW System is inoperable for 10days, the 45 day special inoperability period is reduced to 35 days. If theSSF ASW System is inoperable for 6 days, Condition A applies and thereis no reduction in the 45 day allowance. The limit of 45 days per calendaryear minimizes the number and duration of extended outages associatedwith exceeding the 7 day Completion Time of a Condition.

G.1 and G.2

If the Required Action and associated Completion Time of Condition Fare not met or if the Required Action and associated Completion Time ofCondition 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 within12 hours and MODE 4 within 84 hours. The allowed Completion Timesare appropriate, to reach the required unit conditions from full powerconditions in an orderly manner and without challenging plant systems,considering a three unit shutdown may be required.

SURVEILLANCE SR 3.10.1.1REQUIREMENTS

Performance of the CHANNEL CHECK once every 7 days for eachrequired instrumentation channel ensures that a gross failure ofinstrumentation has not occurred. A CHANNEL CHECK is normally acomparison of the parameter indicated on one channel with a similarparameter on other channels. It is based on the assumption thatinstrument channels monitoring the same parameter should readapproximately the same value. Significant deviations between the twoinstrument channels could be an indication of excessive instrument driftin one of the channels or of something even more serious. A CHANNELCHECK will detect gross channel failure; therefore, it is key in verifyingthat the instrumentation continues to operate properly between eachCHANNEL CALIBRATION. This SR is modified by a Note to indicate thatit is not applicable to the SSF RCS temperature instrument channels,which are common to the RPS RCS temperature instrument channelsand are normally aligned through a transfer isolation device to each Unitcontrol room. The instrument string to the SSF control room is checkedand calibrated every 18 months

Agreement criteria are determined based on a combination of thechannel instrument uncertainties, including indication and readability. If a


SSFB 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 orthe signal processing equipment has drifted outside its limit. If thechannels are within the criteria, it is an indication that the channels areOPERABLE. If the channels are normally off scale during times whensurveillance is required, the CHANNEL CHECK will only verify that theyare off scale in the same direction. Off scale low current loop channelsare verified to be reading at the bottom of the range and not faileddownscale.

The Frequency is based on unit operating experience that demonstrateschannel failure is rare.

SR 3.10.1.2

Verifying battery terminal voltage while on float charge for the batterieshelps to ensure the effectiveness of the charging system and the ability ofthe batteries to perform their intended function. Float charge is thecondition in which the charger is supplying the continuous chargerequired to overcome the internal losses of a battery (or battery cell) andmaintain the battery (or a battery cell) in a fully charged state. Thevoltage requirements are based on the nominal design voltage of thebattery and are consistent with the initial voltages assumed in the batterysizing calculations. The 7 day Frequency is consistent with manufacturerrecommendations 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 isat or above the level at which fuel oil is automatically added. The level isexpressed as an equivalent volume in gallons. The day tank is sizedbased on the amount of fuel oil required to successfully start the DG andto allow for orderly shutdown of the DG upon loss of fuel oil from the mainstorage tank.

SR 3.10i.4 provides verification that there is an adequate inventory offuel oil in the storage tanks to support SSF DG operation for 72 hours atfull load. The 72 hour period is sufficient time to place the unit in a safeshutdown condition

The 31 day Frequency for these SRs is adequate to assure that asufficient supply of fuel oil is available, since low level alarms areprovided and unit operators would be aware of any large uses of fuel oilduring this period.

OCONEE UNITS 1,2, &3 B 3.10.1-11 BASES REVISION DATED 05/18/10 I

SSFB 3.10.1

BASES


(continued) The SR requires the DG to start (normal or emergency) from standbyconditions and achieve required voltage and frequency. Standbyconditions for a DG means that the diesel engine coolant and oil arebeing continuously circulated and temperature is being maintainedconsistent with manufacturer recommendations. This SR is modified by aNote to indicate that all DG starts for this Surveillance may be precededby an engine prelube period and followed by a warmup period prior toloading. This minimizes wear on moving parts that do not get lubricatedwhen 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 DGis available, without the aid of the refill compressor. The SSF DG air startsystem is equipped with four air storage tanks. Each set of two tanks willprovide sufficient air to start the SSF DG a minimum of three successivetimes without recharging. The pressure specified in this SR is intended toreflect 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 pumpautomatically starts and transfers fuel oil from the underground fuel oilstorage tank to the day tank. This is required to support continuousoperation of SSF DG. This Surveillance provides assurance that the fueloil transfer pump is OPERABLE, the fuel oil piping system is intact, thefuel delivery piping is not obstructed, and the controls and controlsystems for automatic fuel transfer systems are OPERABLE.

The 92 day Frequency is considered acceptable based on operatingexperience.


SSFB 3.10.1

BASES


(continued) A sample of fuel oil is required to be obtained from the SSF day tank andunderground fuel oil storage tank in accordance with the Diesel Fuel OilTesting Program in order to ensure that fuel oil viscosity, water, andsediment are within the limits of the Diesel Fuel Oil Testing Program.

The 92 day Frequency is considered acceptable based on operatingexperience related to diesel fuel oil quality.

SR 3.10.1.9

This Surveillance verifies that the SSF DG is capable of synchronizingwith the offsite electrical system and accepting loads greater than orequal to the equivalent of the maximum expected accident loads. Aminimum 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, theDG 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 anoperational limitation to ensure circulating currents are minimized. Theload band is provided to avoid routine overloading of the DG. Routineoverloading may result in more frequent teardown inspections inaccordance with vendor recommendations in order to maintain DGOPERABILITY.

The normal 92 day Frequency for this Surveillance is consistent withRegulatory Guide 1.9 (Ref. 5).

This SR is modified by three Notes. Note 1 indicates that diesel engineruns for this Surveillance may include gradual loading, as recommendedby the manufacturer, so that mechanical stress and wear on the dieselengine are minimized. Note 2 states that momentary transients becauseof changing bus loads do not invalidate this test. Similarly, momentarypower factor transients above the limit will not invalidate the test. Note 3indicates that all DG starts for this Surveillance may be preceded by anengine prelube period and followed by a warmup period prior to loading.This minimizes wear on moving parts that do not get lubricated.


SSFB 3.10.1

BASES


(continued) Visual inspection of the battery cells, cell plates, and battery racksprovides an indication of physical damage or abnormal deterioration thatcould potentially degrade battery performance.

The presence of physical damage or deterioration does not necessarilyrepresent a failure of this SR, provided an evaluation determines that thephysical damage or deterioration does not affect the OPERABILITY ofthe 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 rackintegrity on a yearly basis.

SR 3.10.1.11

Visual inspection of battery cell to cell and terminal connections providesan indication of physical damage that could potentially degrade batteryperformance. The anti-corrosion material is used to help ensure goodelectrical connections and to reduce terminal deterioration. The visualinspection for corrosion is not intended to require removal of andinspection under each terminal connection.

The limits established for this SR must be no more than 20% above theresistance as measured during installation or not above the ceiling valueestablished by the manufacturer.

The Surveillance Frequency for these inspections is 12 months. ThisFrequency is considered acceptable based on operating experiencerelated to detecting corrosion trends.

000NEE UNITS 1, 2, & 3 B 3.10.1-14 BASES REVISION DATED 05/18/10

SSFB 3.10.1

BASES


(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 electricalpower system. The discharge rate and test length correspond to thedesign duty cycle requirements. The design basis discharge time for theSSF battery is one hour.

The Surveillance Frequency for this test is 12 months. This Frequencyis 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 ameasured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account forinstrument drift to ensure that the instrument channel remains operationalbetween successive tests. CHANNEL CALIBRATION shall find thatmeasurement errors and bistable setpoint errors are within theassumptions of the setpoint analysis. CHANNEL CALIBRATIONS mustbe performed consistent with the assumptions of the setpoint analysis.This Frequency is justified by the assumption of an 18 month calibrationinterval to determine the magnitude of equipment drift in the setpointanalysis.

SR 3.10.1.14

Inservice Testing of the SSF valves demonstrates that the valves aremechanically OPERABLE and will operate when required. These valvesare required to operate to ensure the required flow path.

The specified Frequency is in accordance with the 1ST Programrequirements. Operating experience has shown that these componentsusually pass the SR when performed at the 1ST Frequency. Therefore,the Frequency was concluded to be acceptable from a reliabilitystandpoint.


SSFB 3.10.1

BASES


(continued) This SR requires the SSF pumps to be tested in accordance with the 1STProgram. The 1ST verifies the required flow rate at a discharge pressureto verify OPERABILITY. The SR is modified by a note indicating that it isnot applicable to the SSF submersible pump.

The specified Frequency is in accordance with the 1ST Programrequirements. Operating experience has shown that these componentsusually pass the SR when performed at the 1ST Frequency. Therefore,the Frequency was concluded to be acceptable from a reliabilitystandpoint.

SR 3.10.1.16

This SR requires the SSF submersible pump to be tested on a 2 yearFrequency and verifies the required flow rate at a discharge pressure toverify OPERABILITY.

The specified Frequency is based on the pump being not QA grade andon operating experience that has shown it usually passes the SR whenperformed 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 EvaluationReport on Effect of Tornado Missiles on Oconee EmergencyFeedwater System,” dated July 28, 1989.

7. NRC Letter from L. A. Wiens to J. W. Hampton, “Safety Evaluationfor Station Blackout (10 CFR 50.63) - Oconee Nuclear Station,Units 1,2, and 3,” dated March 10, 1992.


BASES

SSFB 3.10.1

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

SSFB 3.10.1

Table B 3.10.1-1 (page 1 of 1)SSF Instrumentation

FUNCTION REQUIREDCHANNELS 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




Admin-305

Calculate the Maximum Permissible Stay TimeWithin Emergency Dose Limits (EDL)

CANDIDATE

EXAMINER



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: Gen2.3.4Rating: 3.2/3.7

Task Standard:

Calculate the Maximum Permissible Stay Time Within the Emergency Dose Limits.


Simulator

_____

In-Plant

______


_____

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: INAME SIGNATURE DATE

COMMENTS

NONE




Tools/EguipmentlProcedures Needed:

CalculatorNote tablet

READ TO OPERATOR


I will explain the initial conditions, and state the task to be performed. All control room stepsshall be performed for this JPM, including any required communications. I will provide initiatingcues and reports on other actions when directed by you. Ensure you indicate to me when youunderstand your assigned task. To indicate that you have completed your assigned task returnthe handout sheet I provided you.

INITIAL CONDITIONS

1. Steam Generator Tube Rupture has occurred on Unit 32. 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:

# TASK TIME REQUIRED DOSE RATE1 Close 3C-573 11 mm 6.15 R/hr2 Open 3FDW-313 6 mm 18.25 R/hr3 Open all Unit 3’s 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 DoseLimits.


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

SATSTANDARD: Determine dose received while performing task 2.

18.25 RIhr X 1 hrI6O mm x 6 mm = 1.825 RUNSAT

(1.82 to 1.83 R)

COMMENTS:

STEP 3: Determine dose remaining from EDLs. CRITICAL STEP

SATSTANDARD: Determine dose remaining from EDLs.

5R — 1 .1275R — 1 .825R = 2.0475 RUNSAT

(2.04 to 2.06 R)

COMMENTS:


STEP 4: Determine time available for the NEC to complete task 3 without CRITICAL STEPexceeding EDL.

SATSTANDARD: Stay time is calculated to be:

Available Dose = 2.0475 R = .44 hr X 60 mm = 26.42 mmDose Rate 4.65 RJhr lhr UNSAT

(26 to 27 Minutes)

COMMENTS:

END OF TASK

STOP TIME:


STEP # Explanation

1 Required to calculate stay time.






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:

# 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 3’s 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 DoseLimits.


REGION IIINITIAL LICENSE EXAMINATION


ADMIN-409

Determine Emergency Classification and Protective

Action Recommendations

(Complete Emergency Notification Form)

CANDIDATE

EXAMINER


REGION II

INITIAL LICENSE EXAMINATION


Task:

Determine Emergency Classification and Protective Action Recommendations (Complete Emergency

Notification Form)

Alternate Path:

NO

Facility JPM #:

New

K/A Rating(s):

System: GenK/A: 2.4.38Rating: 2.4/4.4

Task Standard:

Appropriate classification is determined and associated Emergency Notification Form is completed with the time

critical criteria.


Simulator

______

In-Plant

_______

Classroom — X Perform X Simulate_____

References:

RP/0/B/1 000/0 1RP/0/B/1 000/02BASIS Document (Volume “A”, Section “D” of the Emergency Plan)

RPIOIB/1 000/0 1 5ANuclear Power Plant Emergency Notification Form for EAL 4.4.S.1

Validation Time: 20 mm. Time Critical: Yes

Candidate:Time Start:

NAME Time Finish:

Performance Rating: SAT UNSAT Performance Time:

Examiner:/

NAME SIGNATURE DATE

Comments

NONE


ADMIN-409 FSPage3of 11

ADMIN-409 ESPage4of 11

Tools/Equipment/Procedures Needed:

RP/0/B/1 000/01 / RP/0/B/1 000/02

READ TO OPERATOR


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: THIS IS A DRILL

TIME: 5 minutes agoUnit 1 operating at 45% powerUnits 2 & 3 operating at 100% powerUnit I is performing the Secondary System Protective Test

Turbine Trips while testing the Mechanical Overspeed Trip Circuit

Reactor Fails to TripManual 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 timeA NEO manually opens the CRD AC Breakers, this action results in all control rods inserting

into the core.No RIA’s are increasing or in alarmContainment is intactContainment pressure is 0 psig

INITIATING CUE:

Perform the required actions of the Emergency Coordinator:

1. Determine Emergency Classification

2. Complete appropriate Emergency Notification Form for current conditions

THIS IS A TIME CRITICAL JPM

Notify the examiner when the event is classified.

Note: Do not use Emergency Coordinator’s judgment while classifying the event. When

required, other operators will maintain the Emergency Coordinator’s Log and

perform the duties of the Control Room Offsite Communicator.

ADMIN-409 FSPage 5of 11

STARTTIME:

_____

(Actual time)

___________________

STEP 1: Classify the Event CRITICAL STEP

STANDARD: Refer to RPIO/BI1000/O1 (Emergency Classification) Enclosure 4.4 (Loss

of Shutdown Functions) SAT

Classify the event as a Site Area Emergency” due to the following:

A.1 Valid reactor trip signal received or required WITHOUT automatic UNSAT

scramANDA.2 DSS has NOT inserted Control Rods

ANDA.3 Manual trip from the Control Room was NOT

successful in reducing reactor power to less than 5% and decreasing

COMMENTS:

STEP 2: Commence the Off-Site Notification Form.

STANDARD: Go to RPIOIBI1000IOO2 (Control Room Emergency Coordinator SAT

Procedure) and initiate procedure by determining symptoms for entry

exist and check Step 1.1

COMMENTS:

UNSAT

STEP 3: Step2.1.

STANDARD: Determine step 2.1 does not apply SAT

COMMENTS:UNSAT


STEP 4: Step 2.2 TIME

Declare the appropriate Emergency Classification level. CRITICAL STEP

Classification SAE (UE, ALERT, SAE, GE)

Time Declared:

STANDARD: Declare a Site Area Emergency due to:SAT

“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 UNSAT

public safety.”

STOP TIME #1: Time SAE Declared

(Actual time) (SAT is <Start Time + 15 minutes)

COMMENTS:

STEP 5: Step 2.3 & 2.4

STANDARD: Determine Steps 2.3 and 2.4 do not apply — SAT

COMMENTS:

UNSAT

STEP 6: Step 2.5Appoint 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 FSPage 7of 11

STEP 7: Step 2.6IAAT Changing plant conditions require an emergency classification

upgrade, THEN Notify Offsite Communicator to complete the in-progress

notifications per RPIOIBI1000I15A, (Offsite Communications From The SAT

CR)AND Re-initiate a clean copy of this procedure for the upgraded

classification and stop this procedure. UNSAT

STANDARD: An Upgrade is not expected.

COMMENTS:

STEP 8: Step 2.7CRITICAL STEP

Obtain the appropriate Offsite Notification form from the Emergency Plan

cart.SAT

STANDARD: Initial Site Area Emergency form # 4.4.S.1 is selected and candidate

continues to fill-out form per the Step 2.7 substeps. UNSAT

COMMENTS:

ADMIN-409 ESPage 8of 11

STEP 9: Step 2.7 CRITICAL STEPS

Ensure EAL # as determined by RP/O/B/1000/0O1 matches Line 4. (4.4.Si) _Line I

(NC) Line 1 - Mark appropriate box “Drill” or “Actual Event (DRILL)IVIesae #)

(C) Line 1 - Enter Message # (#1)•Line 6

Line 7

(C) Line 2 - Mark Initial (INITIAL marked) _Ljne 10Line 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.

(C) Line 7 - If Line 6 Box B or C is marked, mark Box D. Otherwise mark UNSAT

Box A (‘A’ marked)

(NC) Line 8 - Mark “Stable” unless an upgrade or additional PARs are anticipated within

an hour.

• Refer to Enclosure 4.9, (Event Prognosis Definitions)

(C) Line 10 - Military time and date of declaration (Refer to date/time in Step 2.2)

(Insert time from STEP I and today’s date, military time is not critical as long

as time is specific and accurate.)

(NC) Line 11 - If more than one unit affected, mark All” (Unit I marked)

(C) Line 12- Mark affected unit(s) (reference Line 11) AND enter power level of

affected unit(s) or time/date of shutdown {14} (Unit 1 0% power,

Shutdown at 1405 with today’s date.)

(NC) Line 13 - If the OSM has no remarks, write ‘None” (Candidate may provide

relevant information as applicable)

If Condition “A” exists ensure following PARs are included Line 5.

A. Evacuate: Move residents living downstream of the Keowee

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)

STANDARD: Correctly fills out Emergency Notification Form in accordance with

Key.

COMMENTS:

ADMIN-409 ESPage9of 11

STEP 10: Step 2.7 Continued TIMECRITICAL STEP

(C) Line 17 - OSM signature, CURRENT Time/Date (MUST SIGN)

STANDARD: Correctly fills out Emergency Notification Form within 15 minutes of

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 FSPage lOof 11


STEP # Explanation

1 The candidate needs to be able to utilize the procedure and determine the conditions meet a

Site Area Emergency classification.

4 This is a time critical step. The candidate needs to declare the SAE within 15 minutes of

beginning the JPM. (The start of the JPM is the beginning of the assessment period)

8 The correct form that matches the EAL # is selected.

9 The emergency notification form is filled-out with each line entry identified as ‘critical’

complete and accurate.

10 This is a time critical step. The Candidate needs to complete the notification form within 15

minutes from the time the EAL was declared. (Declaration time is the time recorded in JPM

step 4)

CANDIDATE CUE SHEET

(TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

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• A NED manually opens the CRD AC Breakers, this action results in all control rods

inserting into the core.

• No RIA’s 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

2. Complete appropriate Emergency Notification Form for current conditions

THIS IS A TIME CRITICAL JPM

Notify the examiner when the event is classified.

Note: Do not use Emergency Coordinator’s judgment while classifying the event. When

required, other operators will maintain the Emergency Coordinator’s Log and

perform the duties of the Control Room Offsite Communicator.

,4i21/t1 tfD’7

NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM

ACTUAL EVENT

FOLLOW-UP NOTIFICATION: TIME

Oconee Nuclear Site

7. RELEASE SIGNIFICANCE:

8. EVENT PROGNOSIS:

9. METEOROLOGICAL DATA:

(* May not be available for Initial

Notifications)

1O. DECLARATION [] TERMINATION

11. AFFECTED UNIT(S): J J J12. Unit Status:

(Unattected Unit(s) status Not Required tor Initial

Notifications)

13. REMARKS: /t/L9A”l

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

MAGNITUDE: Noble Gases:

______________

lodines:

____________ ___________

FORM: Airborne Start Time: Date: I /

ØLiquid Start Time: Date: / I

15. PROJECTION PARAMETERS: Projection Period:

____________

Hours

Projection performed: Time Date

_______

I

______

/

_______

16. PROJECTED DOSE: DISTANCE TEDE (mrem) Adult Thyroid CDE (mrem)

Site boundary

__________________ _____________________

2 Miles

__________________ _____________________

5 Miles

__________________ _____________________

10 Miles

________________ ___________________

17. APPROVED BY:_________________________________ Title: Emergency Coordinator

__________

NOTIFIED BY:

1. DRILL

2. INITIAL

3. SITE:

MESSAGE#

DATE I I AUTHENTICATION#

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

J EVACUATE

J SHELTER

EJ CONSIDER THE USE OF KI (POTASSIUM IODIDE) IN ACCORDANCE WITH STATE PLANS AND POLICY.

EJ OTHER

6. EMERGENCY RELEASE: one Is Occurring Has Occurred

1ot applicable B Within normal operating limits Above normal operating limits ØUnder Evaluation

A Improving Stable C Degrading

Wind Direction* from

______________

degrees Wind Speed*

___________

mph

Precipitation*

______________

Stability Class* B EJ EJ ED [I] []Time

__________

Date £4/t

1,)DJ ‘

Ui A.?’ % Power Shutdown at: Time 1 h1 S— Date —

i:: U2 % Power Shutdown at: Time Date I I —

U3 % Power Shutdown at: Time Date — I I —

UNITS: ECi EDCi/sec EDPCi/sec

Particulates:

___________

Other:

____________

Stop Time: Date I I

Stop Time: Date I /

Estimated Release Duration: Hours

RECEIVE BY:

IE7

Fçqci’.r1

Time: ‘iTM’ Date: I I

_____

Time: Date: I I


Oconee Nuclear Station RP/O/B/1 000/001

Emergency Classification Revision No.

028


Reference Use 0X002w0s

PERFORMANCE* * * * * * * * * * UNCONTROLLED FOR PRINT * * * * * * * * * *


-L.)f,c P


Oconee Nuclear Station Rp/OIBI1000/002

Control Room Emergency Coordinator Procedure Revision No.

022


Reference UseOXOO2WOT

PERFORMANCE

* * * * * * * * * *IJNCONTROLLEDFQRPPJNT* * * * * * * * * *


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