ML18087A743

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Rev 1 to Hot Standby to Min Load.
ML18087A743
Person / Time
Site: Salem  PSEG icon.png
Issue date: 03/08/1983
From: Connor B
Public Service Enterprise Group
To:
Shared Package
ML18087A720 List:
References
IOP-3, NUDOCS 8303160603
Download: ML18087A743 (30)
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Text

-

SALEM GENERATING STATION

Title:

OPERATIONS DEPARTMENT DOCUMENT APPROVAL COVER SHEET Hot Standbv To.Minimum Load No.: IOP-3 Unit: 1 Rev.: -**.**-* 1 Remarks: 17 pages of text, 1 figure, 2 Check Off Sheets.

Rev. 1 replaces Rev. 0. Changes *made; Step 4.5 was rewritten due to -implementation of AD-16. Added step 5.11.2, 5.15.1 Last OTSC P-6.

Safety Related Review (Ref. AD-13) : S/R yes x no A

Author's Checklist Completed: yes x Author4~ e7~ Date 3/,/<('?

I

  • Ops. Eng.

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- Date Date c~ \0"1 \~

3fa/-63 SOS+ N\A <<... Date Ops. Mgr. I~ :y !Vjf Date 3k/r?'3 .

QA

, J! b Wu,,,,.~ r.M fi Date ;;?4-53 SORC

~uJ1tl ..

Date. :3/?'

F /

,/f3 General Manager

,!!:)~~i~ Date-3/'P~.J I /

  • required for Sl?M documents only

+ required for EOP validation acceptance only

    • required for safety related documents and fire protection documents MaSTFR -ii
  • Salem Unit 1/2 03160603 830314 ~*

I I

I AD-1-B-l MASTER il\6" ..

Rev. 4 ADOCK 05000272

. --- .........-... *--~~,---*--

PDR.

.......... -.. .,, __ --~ ---** . -* -** ,,,_

I I

INTEGRATED OPERATIHG PROCEDURE

  • IOP-3 HOT STANDBY TO MINIMUM LOAD DATE TERMINATION TIME DATE BY COMPLETION TIME DATE BY

-------- --------~

1.0 PURPOSE 1.1 This instruction outlines the sequence in which systems are placed in service for a plant startup from Hot Standby (Mode 3) to Power Operation (Mode 1). Specific operating details and valve lineups are found in referenced instructions.

  • 2.0 PRECAUTIONS 2.1 ADMINISTRATIVE 2.1.1 In the event plant conditions require a delay during some part of this procedure, the Senior Shift Supervisor/Shift Supervisor shall retain this instruction until the*procedure is continued or terminated. ~

2.1~2 If this instructton is terminated prior to completion, the Senior Shift Supervisor/Shift Supervisor shall note the reason, time and. date of termination on this instruction. The last completed IOP will be maintained in the Control Room file.

2. 1. 3 Criticality must be anticipated any time the.

Control Rods are being withdrawn or boron dilution operations are in progress.

2.1.4 An Inverse Count Rate Ratio (ICRR) Plot shall be maintained during Control Rod withdrawal on a reactor startup when the estimated critical configuration differs from a known critical configuration by more than 650 PCM differential due to rods or a 1000 PCM differential due to Xenon.

2.1.5 Do not exceed a stable start up rate of one decade per minute .

  • Salem Unit 1 1 MASlER Rev.

IOP-3

In Modes 1 and 2, the Group Step Counters and Rod Position Indicators for that bank must be within

+/-12.steps as specified by Technical Specification 3.1.3.2.

2.1.8 Refer to Emergency Plan Procedure, EP-r~o Part 4 for the appropriate event classification and reporting requirements.

2.2 EQUIPMENT 2.2.~ When changing the RCS boron concentration, pressur~zer sprays should be utilized to minimize the differential between pressurizer and loop boron concentration to less than 50 ppm by placing heaters in MANUAL-ON and leaving spray control in AUTO.

2.2.2 The pressurizer spray must not be used if the temperature between the pressurizer and the spray fluid is greater than 320F .

2.2.3 Reactor Coolant Pumps

a. With less than 4 RCP's in service; be in Hot Standby within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
b. Power operation above P-7 is not permitted with less than 4 RCP's in service. '
c. The reactor should not be brought critical with less than 4 RCP's in service.

2.2.4 Stearn Generator pH must be maintained between 8.5 and 9.2. Steam Generator Blowdown after the ion exchange conductivity must be less than .8 rnicrornhos. If unable to achieve chemistry specifications, refer to EI-I-4.21, "Condenser Tube Leak," Table 1.

3.0 ATTACHMENTS LIST 3.1 Figures 3 .1. 1 Figure 1 - Feedwater Differential Pressure vs.

Total Feedwater Flow

  • Salem Unit 1 2 *r~ASTER Rev.

IOP-3

  • 3.2 3.3 Tables None Check Off Sheets 3.3.l Check Off Sheet 1 - Requirements to Enter Mode 2 3.3.2 Check Off Sheet 2 - Requirements to Enter Mode 1 4.0 PREREQUISITES NOTE Initial each step after completion 4.1 The plant is in the Hot Standby Mode IAW IOP-2 "Cold Shutdown to Hot Standby."

4.2 The Full Length Control Rods are inserted; the.Shutdown Banks are fully withdrawn.

4.3 Final inspection and closure of the containment has been made and signed off IAW SP(0)4.5.2(c),

I ECCS Subsystems and SP(0)4.6.1.3(a),

Con~ainment Systems - Air Locks.

I I

4.4 Containment integrity is established.

4.5 Permission has been granted to take the Reactor Critical, in accordance with AD-16 "Post Reactor Trip/

Safety Injection Review and Unit Startup Approval Requirements" section 4.0 - Approval Requirements for Reactor Startup.

  • 4.6
  • The estimated critical boron concentration for the desired critical control rod bank position has been determined, IAW Reactor Engineering Manual, Part I .
  • Salem Unit 1 3 MASTER Rev.

IOP-3

  • 4.7 Check Off Sheet 1, Requirements to Enter Mode 2 has been reviewed and signed by the Senior Shift Supervisor.

IF st:artup is being made to recover from a reactor trip and:

1. Control Rod withdrawal is started within *24 hours of the trip AND
2. RCS temperature has not decreased below 500°F since the trip occurred
    • 3.

AND The cause of the trip is known and corr.ected.

Then Check Off Sheet is not required.

4.7.1 PERFORM SP(0)4.3.l.l.l Instrumentation-Reactor Trip Breakers if not done in last 7 days (satisfies item 1 of STS Table 4.3-1) 4.7.2 VERIFY IC Department Weekly Surveillances are current to satisfy item 5; 6, 18 and 21 of Tech Spec Surv 4.3.1.1.1 Table 4.3-1 (COSl-2 IC Sign Off) .

  • Salem Unit 1 4 Rev. J

IOP-3

  • 4.8 4.9-All RCP's are in service.

Both Source Range Channels are operable.

Tech Spec 3.4.1.1 Tech Spec

3. 3. 1 4.10 Prior to starting the Main If the plant is Feedwater System, permission being restarted must be obtained from the within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Chemistry Department to feed after last the Stearn Generator from the shutdown, due Condenser hotwells. to either a reactor trip or a controlled shutdown, and the plant "chemistry was within specifications at the time of the shutdown, Chemistry Department permission is not required .

5.0 PROCEDURE NOTE Initial the indicated steps after completion.

5.1 ADJUST the RCS boron concentration to the Estimated Critical Boron Concentratioh IAWi OI II-3.3.6 Boron Concentration Control.

5.2 DEFEAT the Source Range HIGH Block switches FLUX AT SHUTDOWN ALARM and are on NIS verify the .SR HIGH FLUX AT rack.

SHUTDOWN BLOCKED annunciator alarm energizes.

5.3 With 15 minutes prior to Tech Spec withdrawal of any Control Rod 4.l.3.4(a)

Bank, DETERMINE that each Shutdown Rod is fully withdrawn .

  • Salem Unit 1 I

5

~1ASTER Rev.

IOP-3

  • 5.4 MAKE the following announcement twice on the plant PA-System.

"ATTENTION ALL PERSONNEL",

Commencing Unit #1 Reactor Startup.

5.5 Within 15 minutes prior to Tech Spec Criticality, VERIFY RCS 4.1.1.5(a)

Tavg to be greater than or equal to 541°F.

5.6 SELECT both Source Range Channels The licensed on the recorder for the Nuclear operator making Instrumentation System until the startup the Intermediate Range is mav at his approached. At this time one discretion, use pen must be switched to an the NR-45 Intermediate Range Channel. recorder differently, as required by the situation.

5.7 OBTAIN APPROVAL of the Senior

  • Shift Supervisor and withdraw the Control Rod Banks in Manual and begin the approach to Criticality.

5.7.1 MONITOR Nuclear Instrumentation and expect Criticality at any time.

5.8 STOP Rod Withdrawal at every 50 steps and check for proper Rod Alignment (individual rod position indicators versus step counters) and overlap.

5.8.1 If an ICRR is required, PLOT the Count Rate versus rod position at every 50 step stop point .

  • Salem Unit 1 6 Rev. J

IOP-3

  • 5.9 *IF any of the following conditions occur while trying to achieve criticality, PROCEED as specified.

A detailed description should be entered in Operations Log #1 and all copies of the ECP shall be retained. The Operations Manager or Operating Engineer should be notified and an Incident Report should be in,itiated.

5.9.1 The Cont~ol Bank height at Criticality is below the Rod Insertion Limit for zero power.

  • a. NOTIFY the Senior Shift Supervisor/Shift Supervisor.
b. INSERT all control rod banks.
c. CALCULATE a Shutdown 'I'ech Spe.c margin 3.1.1.l
d. RECALCULATE the ECP
e. DETERMINE AND CORRECT the error 5.9.2 The Control Bank height at Criticality is 500 PCM belo~

the ECP but above the Rod Insertion limit.

a. NOTIFY the Senior Shift Supervisor/Shift Supervisor.
b. INSERT all Control Rod Banks .
  • Salem Unit 1 7 MASTER. Rev. 1

IOP-3

  • c. RECALCULATE the ECP
d. DETERMINE AND CORRECT the error 5.9.3 Criticality has not been achieved with the rods withdrawn to an equivalent of 500 PCM past the ECP.
a. NOTIFY the Senior Shift Supervisor/Shift Supervisor.
b. INSERT control banks to-the position for 500 PCM below criticality
c. RECALCULATE the ECP
d. DETERMINE AND CORRECT MarkN/A the the error. If no error steps not was *found, required.
1. REQUEST confirming boron sample
2. NOTIFY Reactor Engineering
3. FULLY INSERT all control rod banks
4. PULL rods for criticality using an ICCR plot 5.10 When the P-6 (Source Range Permissive) light is energized, BLOCK the Source Range High Flux Trip by depressing both ~he BLOCK SOURCE RANGE "A" and BLOCK SOURCE RANGE "B" pushbuttons on the console.

5.10.1 VERIFY the Source Range Trains A&B TRIP BLOCKED light on RP4 and the SR Detector Voltage Trouble Overhead Annunciator alarm are energized .

  • Salem Unit 1 8 MASTER Rev. J

IOP-3

  • 5. 10. 2
  • When P-6 is exceeded and the Source Range Channels are ~locked, the Becond Pen should be switched to the other Intermedi~te Range Channel.

5.11 LEVEL off the Reactor Neutron

\

level at lXl0-8 amps in the Intermediate Range.

5~11.1 VERIFY Critical Rod Position is not less than the limits of Tech Spec 3.1.3.5 and Figur~

14 of the Reactor Engineering Manual within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of achieving criticality.

5.11.2 UPDATE TRIS; change from Mode 3 to Mode 2.

5.12 COMPLEJTE the ECP FORM.

5.13 INCREASE Reactor Power to 1% to 2% and complete the following:

  • 5.13.1 COMPLETE warmup of the Main Steam System by performing the following:
a. Check Off Sheet 4.1 OI Irr-2.3.1 Main Steam
b. Check Off Sheet 4.2 or rrr-2.3.1 Reheat Steam
c. Check Off Sheet 4.3 or rrr-2.3.l Reheat Drains
d. OPEN OR CYCLE the Warm Up Valves, ll-14MS18, to maintain RCS temperature constant.
1. During warmup of Steam System, FEED the steam generators as necessary to maintain their normal no load level .
  • Salem Unit 1 9 MA STEP

~

  • I
  • t 'it Rev. 1

IOP-3

  • e. OPEN the following:

1.

2.

Drain valves11-14MS7 Drain valves 11&12MS26

f. When less than 50 PSID between steam generator and lines downstream of stop valves, OPEN steam generator stop valves, ll-14MS167. .
g. VERIFY 11-14MS18's are Tech Spec open, then VERIFY 4.7.1.5 ll-14MS167's valve closure times are less than 5 seconds. PERFORM SP(0)4.7.1.5 if not performed in last 9.2 days.
h. CLOSE the following:
  • 1.

2.

Warmup Valves ll-14MS18 Drain Valves11-14MS7

3. Drain Valves 11&12MS26
i. PERFORM SP(0)4.0.5-V-MISC Check Off Sheet 4.1 Page 3 of 3 if not performed in the previous 92 days.
j. SECURE Condensate System Recirc Flow IAW OI III-9.3.4 Placing Condensate System in Recirc for Cleanup .
  • Salem Unit 1 10 MASTER Rev. 1

IOP-3

  • k. OBTAIN PERMISSION from Chemistry Department to feed Steam Generators from the Condenser hotwells.

If the plant is being restarted within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of the last shutdown, due to either a reactor trip or a controlled shutdown and the plant chemistry was within specifications at the time of shutdown, Chemistry Department permission is not required.

1. BEGIN Feed Pump Turbine Warmup IAW OI III-9.3.2 Feed Pump Operation *
m. CHANGE Sealing Steam over to #1 or #2 Unit Main Steam IAW OI III-4.3.1. Turbine Gland Sealing Steam Normal Operation.
n. ESTABLISH S/G Blowdown Chemistry IAW OI III-13.3.2 Department Steam Generator shall specify Blowdown Normal the amount of Operation. blowdown.
o. OPEN 11-14 MS167 5.14 Prior to exceeding 5% Power, Check Off Sheet ENSURE Check Off Sheet 2 2 is not Requirements to Enter Mode 1 required when has been completed and signed the Startup is off by the Senior Shift being made to Supervisor. recover from a reactor trip and:
  • Salem Unit 1 11 Rev. 1

IOP-3

    • 1. Control Rod Withdrawal is started within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of the trip AND
2. RCS __

temperature has not dropped below 500°F, since the trip AND

3. The cause of the trip is known and corrected.

5.15 INCREASE Reactor power to 8% Remain below P-10 for turbine roll.

5~15.1 When Reactor power is greater than 5% power UPDATE TRIS; change from Mode 2 to Mode 1.

5.16 MAINTAIN Steam Generator water At this point level with the Auxiliary Feed Steam Generator System. Level Control becomes very critical sudden increases or decreases in feedwater or steam flow are to be avoided.

5.16.1 COORDINATE all changes in feed water or steam flow with the reactor while rod control is in manual .

  • Salem Unit 1 12 MASTER Rev. 1

_ _-_*._*-*_._,._-,__.:-**_*- - *-~:-r:--~-- **--* -* ----.-.-- -*---. - --~**_:_* _ _ ____:____:..:...._-'-__:__ _ _ _ _ _.......;_.;___ _ _.;...__ _ _ _ _ _ _ _ _ _ _ __

IOP-3 5.17 PLACE Main Feed System in service IAW OI III-9.3.2 Feed Pump Operation.

5.18 Once Steam Generator Feedwater Control Valves are in automatic and controlling S/G level adequately, ALIGN the AFWS for power operation as follows:

5.18.1 OPEN OR CHECK OPEN ll-14AF11 SG AF level control valves Update TRIS 5.18.2 VERIFY that the Auxiliary Feed System Controls are adjusted to conform to the standby conditions IAW OI III-10.3.1, Auxiliary Feedwater System Operation.

5.19 PLACE the Turbine Generator on the line IAW OI III-1.3.1 Turbine Generator Operation.

5.20 INCREASE Turbine load until the steam dump valves have fully closed.

5.21 NOTIFY the .Load Dispatcher that the unit has been synchronized.

5.22 CONTINUE INCREASING Turbine Load while maintaining TAVE at the programmed value ..

5.23 VERIFY that permissive P-10 signals 2/4 Power Range have*actuated (P-10 light energized) greater than then _perform the following: 10.%

5.23.1 MANUALLY BLOCK Intermediate Range A&B low power trips by depressing both BLOCK IR "A" and BLOCK IR "B" pushbuttons on the console.

Salem Unit 1 13 MASTER Rev. 1

IOP-3 5.23.2. MANUALLY BLOCK Power Range "A" and Power Range "B" Low Power trips by depressing both BLOCK PWR RANGE "A" and BLOCK PWR RANGE "B" pushbuttons on the console.

5.24 VERIFY that Permissive Signal This makes the P-7 has actuated (below P-7 following light de-energized) . *reactor trips operable.

A. Pressurizer Low Pressure B. Pressurizer High Water Level

c. Loss of Flow-Two Lpop Logic D. Turbine Trip
  • p-7 Setpoint greater than 10% Power Reactor Power (2/ 4) or TURB PWR ( 1 / 2) 5.25 If manual MSR control is to be used, BEGIN WARMUP of the MSR's I.AW OI III-2.3.3, Moisture Separator Reheaters Manual Operation.

5.26 When the P-2 Interlock has been Turbine Power actuated, ADJUST TAVE to within greater- than

+/- 1°F of TREF and PLACE Rod Control 15%

System in AUTO.

Salem Unit 1 l 4a ASTER Rev. 1

IOP-3 5.27 ALIGN Steam Dump Valves for Power Operations as follows:

5.27.1 ENSURE the Loss of Load Interlock is reset by pushing the Reset Load Rejection pushbutton and observing the Turbine Impulse Chamber Pressure Permissive light on the Status Panel is out.

5.27.2 PLACE the Steam Dump.Valve Controller in Average Temp.

Cont. Mode.

5.27.3 VERIFY that the Block Cooldown and the* Block Non-Cooldown lights are On.

5.28 PERFORM the following to place the Steam Generator Feed Pump Speed Controls to Automatic.

5.28.1 MANUALLY ADJUST the Master 0-100% of the Controller Speed Demand to Master match the speed of .the pump Controller is equal to 1100-5550 RPM on the individual pump controller.

5.28.2 PLACE the Feed Pump Individual Controller in AUTO.

5.28.3 ADJUST the Speed Demand of the Master.Controller to maintain proper dp shown on Figure No. 1.

5.28.4 PLACE the Master Controller in AUTO.

Salem Unit 1 *15 MASTER Rev. 1

IOP-3 5.29 At approximately 20% power~ VERIFY the steam generator pH between 8.5-9.2 and steam generator blowdown after the ion exchanger conductivity

\

\ is less than .8 micromhos.

\

\ a. If recorders indicate an out of specification condition, NOTIFY the Chemistry Department to verify by analysis.

b. If an out of specification condition is verified, REFER to EI-I-4.21 Condenser Tube Leak.
c. If* analysis .indicates faulty control room indication, ENSURE analysis is performed every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

5.3Q SELECT IMP in Mode on the E/H Control Panel.

5.31 RESET Auxiliary Power Reset Transformer Isolation Trip_. pushbutton on console.

5.32 TRANSFER the Group Buses from the Station Power Transformer to the Auxiliary Power Transformer by selecting on the Mimic Panel

  • and closing the following breakers:

5.32.1 lAHGD CLOSED 5.32.2 lAEGD CLOSED 5.32.3 lBFGD CLOSED 5.32.4 lBGGD CLOSED 5.33 VERIFY the Station Power Breaker open. UPDATE TRIS for steps 5.32 and 5.33 5.34 NOTIFY the Load Dispatcher that the unit is ready for additional load. -*- - -

Salem Unit 1 16 Rev. 1

IOP-3 6.0 FINAL CONDITIONS 6.1 The 4KV Group Buses are being supplied by the Auxiliary Power Transformer.

6.2 The generator is synchronized and is supplying the grid.

END OF PROCEDURE FINAL PAGE Salem Unit 1 17 AS'lER Rev. 1

IOP-3 FIGURE 1 FEEDWATER DIFFERENTIAL PRESSURE vs TOTAL FEEDWATER FLOW 200 175 150 125 FW Press

. vs 100 I S/G d/p (psi l 75 I

50 I

25 J

2 4 6 8 10 12 14 16 14.44=100% stm./feed flow TOTAL FEED FLOW (XlOE6 lbs/hr)

  • Salem Unit 1 IOP 3-FIG 1-1 Rev. 1

CHECK OFF SHEET 1 REQUIREMENTS TO ENTER MODE 2 1.0 TECHNICAL SPECIFICATIONS REFERENCE TECHNICAL SPECIFICATION DEPT OPS PROCEDURE FREQ COMPLETION DATE SIGNATURE 3.1.3.l Rod Control Assemblies OD SP(0)4.l.3.l.2 M 3.3.1.l Reactor Trip OD SP (0) 4. 3. 1.1. 1 w Instrumentation OD SP (0) 4. 3. 2.1. lA R Verify Control Console Prior Readings taken for Complete to Modes 1-4 OD Ops Log #3 Mode 2 3.3.1.l Reactr)r Trip Instr,1mentation Channel Calibration RE 3.3.1.l Reactor Trip Instrumentation Channel Calibration MD Channel Functional Test MD 3.6.4.2 Hydrogen Re combiners MD Salem Unit 1 IOP-3-COSl-l MASTER Rev. 1

1. 0 TECHNICAL SPECIFICATIONS REFERENCE TECHNICAL SPECIFICATION DEPT OPS PROCEDURE FREQ COMPLETION DATE SIGNATURE 3.3.1.l Reactor Trip Instrumentation Channel Calibration IC Channel Functional Test IC*

3.6.4.1 Hydrogen Analyzers CH

  • Items 5,6,18 and 21 of Tech. Spec. Surveillance*Requirement 4.3.1.1 (Table 4.3.1)

.must have been completed within seven days of the Reactor Startup.

  • lA. All design changes required to be completed prior to entry into Mode 2 have been completed.

Date Station Planning Engineer Reviewed By -=-~..--~-=---.-~--==---~~....--~~~~~

Senior Shift Supervisor MASTER Salem Unit 1 IOP-3-COSl-2 Rev. 1

2.0 Prior to changing modes:

2.1 Change TRIS Operating Mode to the next intended mode

{Menu 2-F2) 2.2 Generate a Components In Off-Normal Position Report (Menu 3-F2)

NOTE This report will indicate all *components not in the required position for the intended mode.

2.3 Position all components as required for the mode change.

2.4 Update TRIS using Change/Query Component Current Position {Menu 2-Fl) 2.5 I have *complied with steps 2.1-2.4, and all equipment required for changing modes is available.

DATE Shift Supervisor/Senior Shift Supervisor ----

  • 3.0 I have reviewed the Jumper Log in the Senior Shift Supervisor's office and all equipment and instrumentation required for changing modes is available.

DATE Shift Supervisor/Senior Shift Supervi9or DATE Maintenance Department DATE I&C Department 4.0 Generate "Equipment Unavailable List" from TRIS I have reviewed the Equipment Unavailable list from TRIS All equipment required for changing modes is available 3:

):D DATE

~ Shift Supervisor/Senior Shift Supervisor ----

--f

~

a
  • Salem Unit 1 IOP 3-COS 1-3 Rev. 1

CHECK OFF SHEET 2 REQUIREMENTS TO ENTER MODE 1 1.0 TECHNICAL SPECIFICATIONS

!REFERENCE TECHNICAL SPECIFICATION DEPT OPS PROCEDURE !FREQ* COMPLETION DATE SIGNATURE 3.7.1.5 Mn. Stm Stop Valves OD SP (0) 4. 7. 1. 5 S/U 4.0.5-V-MISC SHEET 4.1 PAGE 3 OD SP(0)4.0.5-V-MISC Q 3.1.3.1 Rod Control Assemblies OD *sP (O) 4.1. 3. i. 2 M 3.3.2.l Engineer Safety OD SP (O) 4. 3. 2. 1. lD R I

Features OD SP (0) 4. 3. 2. 1. 3 *R Verify Control Console* Prior Readings taken for Modes OD Complete to 1-4 Ops Log #3 Mode 1 I

3.2.2 Hot Channel Factor Heat Flux STS 4.2.2.2 RE i

./ i STS 4.2.2.3 RE

. .;;}'

3.2.3 Hot Chanrlel Enthalpy , *'

i ,,,.,,,....,-...*

STS 4.2.3.1 RE ..-

STS 4.2.3.2 RE 3.2.5 D N B Parameters STS 4.2.5.2 RE Salem Unit 1 MASTER IOP 3-COS 2-1 Rev. 1

1.0 TECHNICAL SPECIFICATIONS REFERENCE TECHNICAL SPECIFICATION DEPT OPS PROCEDURE FREQ COMPLETION DATE SIGNATURE 3.3.1.1 Reactor Trip Instrumentation Channel Calibration MD' Channel Functional Test MD 3.3.1.1 Reactor Trip Instrumentation Channel Calbiration IC Channel Functional Test IC Reviewed By ...,,,-----,,..---~.,,,..,.-...,--,,,_...--=-~~-..~~~~~-

DATE Senior Shift Supervisor

  • lA All design changes required to be completed prior to entry into Mode 1, have been completed.

Date Station Planning Engineer MASTER Salem Unit 1

  • IOP 3-COS 2-2 L___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - * -
  • 2.0 Prior to changing modes:

2.1 Change TRIS Operating Mode to the next .intended mode (Menu 2-F2) 2.2 Generate a Components In Off-Normal Position Report (Menu 3-F2)

NOTE This report will indicate all components not in the required position for the intended mode.

2.3 Position all components as required for the mode change.

2.4 Update TRIS using Change/Query Component Current Position (Menu 2-Fl) 2.5 I have complied with steps 2.1-2.4, and all equipment required for changing modes is available.

DATE Shift Supervisor/Senior Shift Supervisor 3.0 I have reviewed the Jumper Log in the Senior Shift Supervisor's office and all equipment and instrumentation required for changing modes is available.

DATE

~---

Shift Supervisor/Senior Shift Supervisor DATE Maintenance Department ----

DATE I&C Dep.artment 4.0 Generate "Equipment Unavailable List" from TRIS I have reviewed the Equipment Unavailable List from TRIS All equipment required for changing modes is available DATE Shift Supervisor/Senior Shift Supervisor Salem Unit 1 IOP 3-COS 2-3 MASTtt\ Rev.

1

Appendix F Administrative Directives AD-13, Independent Review of Operations Department Documents AD-16, Post Reactor Trip/Safety Injection Review

. J~

'l

. ~- ... - "'*-- '* ~' *. , .

SALEM GENERATING STATION

Title:

OPERATIONS DEPARTMENT DOCUMENT APPROVAL COVER SHEET Independent Review of Operations Department Documents

...;;..______________________ ~

AD-13 1/2 No.:

Remarks: three pages Unit:

of text, no forms, revised page 3 - ODM Rev.:

4 table Safety Related Review (Ref. AD-13): S/R yes _ _ __ no_.....x_____

Author's Checklist Completed: yes_ __.x......__ no Author /)vU..--Yl.-5_~~-------- Date 11-~ 3 -¥2-SRO * ,,.sAf fJil j Date tt-;J...3-~t-Ops. Eng*-~~\: ..,.....__,..1-j,...___.__};J._~.........____ _ __ Date fl/Lr/if'!-

Ops. Mgr.

~~ ......,____________________________ Date {jz,Cj(~

Date 1J<1-'3-<fr.1..-

SORC *

  • jt '1V4.5 Date 1i-;...~ **~

General Manager ~q;~~-i'J--~~5----------------------------

_J Date 11~:i.3-~

  • required for SPM documents only
    • required for safety related documents only I

Salem Unit 1/2 AD-1-B-l Rev. 2

..__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _...,.._...._ _ _..,,_,,;;;::*. *-=\

ADMINISTRATIVE DIRECTIVE - 13 INDEPENDENT REVIEW OF OPERATIONS DEPARTMENT DOCUMENTS Regulatory guides from various agencies have established a need to have an independent review performed of nuclear power plant procedures. This independent review has been established only for safety related procedures. Public Service Electric an.d Gas has committed to these guides in order to get a construction permit and later an operating license for Salem. These independent reviewers have been defined to be the Station Operations Review Committee (SORC) and the Station Quality Assurance Engineer {SQAE). The following depicts the regulatory sequence that has established the two groups as independent reviewers.

SORC ANSI 18.7 established and defined the need for and requiremen~

of an independent reviewer NRC Reg. Guide 1.33 defined safety related procedures FSAR section D.5-14 stated safety related procedures shall be reviewed by SORC Tech Spec section 6.5.1 further defined SORC requirements, very similar wording to ANSI 18.7 AP-4 Administrative Procedure established SORC requirements for station 10CFR50 App B & ANSI 45.2 established general criteria for QA program required for licenses MA Corporate QA Policy ~CiQnt of 1;SE&G

~ttft that lS I

Salem Unit 1/2 1 Rev. 4

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/ I AD-13

  • FSAR section D.5-14 required before licenses stated safety related procedures shall be reviewed by SQAE AP-17 (now deleted) and Quality Assurance Instructions (QAI's) established sta-tion QA program using Corporate QA as reference The following is a list of the Operations Department documents that have been determin~d~to be safety related and therefore, shall be sent to SORC and the SQAE for review prior to implementation. Any document not contained in this list shall be reviewed by the author to determine the safety related status, using Reg. Guide 1.33 as a reference. If ~he document is determined to be safety related it shall be added to this list.

UNIT 1 UNIT 2 Station Plant Manual (SPM)

VOLUME II ALL* ALL VOLUME III ALL ALL VOLUME IV. or III-1. 3.1 same as Unit 1 QI III-1. 3. 2 OI III-1. 3. 3 QI III-1. 3. 5 or III-1.3.7 OI III-2.3.1 or III-2.3.4 QI III-7.3.2 or III-9.3.1 OI III-9.3.2 OI III-9.3.3 QI III-10.3.1 or III-11. 3.1 OI III-11. 3. 2 QI III-13.3.1 QI III-13.3.2 or III-15.3.1 VOLUME V QI IV-1. 3 .1 same except delete:

or rv-3.3.1 'IV-4.3.6 I

Salem Unit 1/2 2 MASTER Rev. 4

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-~-~---

  • AD-13
  • or rv-4.3.1 OIIV-4.3.2 or IV-4.3.4 OI IV-4.3.6 or rv-s.3.1 IV-11. 3 .- 3 IV-12.3.1 V-5.3.2 V-13.3.1 V-15.3.2 or rv-s.3.2 or rv-s.3.3 Add: IV-4 ...3.5 OI IV-6.3.1 or rv-8.3.1 or rv-10.3.1 OI IV-11.3.1 OI IV-11. 3. 2 or rv-11. 3. 3 QI IV-12.3.1 or rv-12.3.2 OI IV-16.3.1 OI V-1. 3.1 or v-3.3.1 or v-3.3.2 QI V-3.3.3 i- or v-3.3.4 QI V-4.3.1 OI V-5.3.1 or v-s.3.2 or v-9.3.1 OI V-13.3.1 OI V-15.3.2 VOLUME VI Annunciator same A-K Console Back Panels Auxilary Annunciator Local Panels VOLUME VII ALL ALL OPERATIONS DEPARTMENT MANUAL (ODM)

OD-3 OD-29 OD-44 OD-8 OD-33 OD-45 OD-9 OD-36 OD-46 OD-10 OD-37 OD-47 OD-11 OD-38 oD-so*

OD-12 OD-40 OD-51 OD-13 OD-41 OD-52 OD-15 OD-42 OD-55 OD-18 OD-43 OD-62 OD-20 OD-28 END OF PROCEDURE Salem Unit 1/2 FINAL PAGE 3 MASTER Rev. 4 I

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