ML20083H079

Abnormal Transient Operating Guidelines

ML20083H079
Person / Time
Site:	Three Mile Island
Issue date:	12/29/1983
From:	GENERAL PUBLIC UTILITIES CORP.
To:
Shared Package
ML20083H068	List: ML20083H061 ML20083H079
References
RTR-NUREG-0737, RTR-NUREG-737, TASK-1.C.1, TASK-TM GL-82-33, PROC-831229, NUDOCS 8401040417
Download: ML20083H079 (73)

Text

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. ATTACMIENT 1 A

k,_) USE OF ATCG GUIDELI:!ES c

CRGAIIZATIO:t The Abnormal Transient Operating Guidelines (ATOG) have been implemented as Abnormal Transient Procedures, ATP 1210 series. This series of procedures is used following any reactor trip or forced shutdown. These same procedures will also be used. if a transient occurs during a heatup, cooldown, or from a hot shutdown condition. The ATP's vill be used to control overall plant

.-eve ns e.

In some cases an EP (1202) or AEP (1203) may be in effect concurrently treating a specific condition. For example if. a station blackout has occurred EP 1202-2 vill

, be followed to protect equipment and . restore power but the ATP's vill be used to assure that the reactor is cooled.-

Following a reactor trip ATP 1210-1 Reactor / Turbine Trip procedure vill be entered. This procedure contains i= mediate actions that are required for any reactor trip. In addition systems that are required to control and monitor g the plant are verified. "he next step is a systematic check for ATOG sytrtems that may occur singly or i combination. If present, the ATOG sy=ptoms are treated in procedures that ma e thought of as " interim" procedures. These interim procedures treat the TOG symptoms before any effort is made to iden ify the specific event that is causing the condition. This approach provides specific

-(') corrective action that assures core cooling for single or multiple events and for events that are not readily identified.

The conditions are prioritized to provide for treating the most rapid or the most severe condition first. The priorities are selected with two main objectives in mind. The objectives are:

. 1. Cooling the core.

2. Minimizing radioactive releases.

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PRIORITY OF ATOG SY"PTOM TREATMENT The fouYAT'0G symptoms that are addressed by the procedures are:

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1. Loss of Subcooled Margin.

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2. , Excessive primary to secondary heat transfer.

3. Lack of primary to secondary heat transfer.

. h. OTSG Tube Rupture.

,,,,____, _ Loss of subcooled marrin is the highest priority symptom. Subcooled margin is very significant for a certain range of RCS break sizes. Action is required within two minutes to prevent possible development of inadequate core cooling later in the transient.

O 8401040417 831229 PDR ADOCK 05000289 P PDR

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Excessive heat transfer is the next priority because rapid response -is

-required if excessive heat transfer is present. One potential cause (excessive IEW) has already been checked. MFW should be rechecked along with other potential causes such as steamline break. Other reasons that overcooling is

- high priority are tensile stresses in the steam generator and radioactive releases-if an OTSG tube rupture occurs with a steam leak. ,

Lack of heat transfer must be treated to attain long term stability.

Fritary to secondary heat transfer is especially important for an OTSG tube rupture because of the importance of cooling down and naintaining =inimum subcooled margin. Lack of heat transfer follows excessive heat transfer because more time is available to ' correct this condition before conditions degrade.

OTSG tube runture is the last priority in the sequence even though it results in a radioactive release to the environment. This condition is treated after any other conditions that are present because difficulty in treating the tube rupture vill occur if any of the other conditions are present. The long term radioactive release is minimized by assuring that ECS conditions i are stable and that the core is being cooled.

- Sueerheat is another high priority condition that has not been discussed.

Superheat conditions in the RCS always demand immediate attention. Superheat

.A was not discussed. in the above sequence for two reasons: (1) It vill not occur

(_) unless multiple failures or improper actions are present and (2) It will not a~

occur ic=ediately following a trip (unless trip was delayed). Superheat cannot occur unless subcooled margin is lost and if the appropriate actions are taken then superheat will not occur.

The sequence above was developed to provide guidance that vould apply for single or multiple events. DO NOT KEY ON ANY ONE CONDITION. If symptoms are not obvious, do not wait for them to develop. Check for other sy=ptoms and treat those present and come back and recheck for other symptoms. The sequence is not as important as treating all the conditions. Post trip stability may be achieved only to be.followed by a transient due to subsequent equipment failure.

An important concept is to always be checking for these ATOG synptoms and taking the appropriate corrective action. This concept applies even after an event has been identified and is being treated by a specific procedure. Re-ch ecking vill prevent adverse effects of misdiagnosis of the plant status.

EVENT-COOLDOWN PROCEDURES After the initial ATOG symptoms have been treated the reactor should be in a stable post trip condition. The follovup actions in ATP 1210-1 are taken and a decision nade on whether to cooldown or restart.

If failures are present, the cooldown procedure OF 1102-11 may not provide sufficient guidance. There are four events for which cooldown instructions have been provided:

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g m- _ _ . . __ _ . _ .

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L Small' break LOCA.

'l.

', 2. Large break LOCA.

3. HPI cooling.

k. Tube Rupture.

Thes.e procedures along with the " interim" procedures cover the analyzed accidents.~ '

Sedll Break LOCA is indicated by inability to restore subcooled margin

.with heat transfer present. Large break LOCA and Tube Rapture must not be present.

Large Break LOCA entry condition is emptying of the Core Flood Tanks.

For-Iarge Break ECCS actuation and containment isolauion and cooling are the emphasis.

HPI Coolirs is required for sustained Lack of Heat Transfer. Conditions that would natural circulation. lead to lack of heat transfer are total loss of feedvater or interrupted *'

' "'he 0TSG Tube Runture procedure provide both the initial response and cool-down instructions.

Even after an event has been identified it is important to continue to lock for, and treat,- other ATOG symptoms with a few exceptions. Cne exception is lack of heat transfer during a large break LOCA. Even though symptoms vill exist, primary.to secondary heat transfer is not necessary for core cooling during

~

a,large break - LOCA. The procedures identify some but not all of these situations. The operator vill have to determine appropriate actions for multiple failures to meet the objectives of cooling the core and limiting radioactive release.

SUMMARY

The Abnormal Transient Operating Guidelines do not change the actions for coping with an event. ATOG identifies symptoms that indicate degrading plant conditions and establishes a priority for treating those conditiens.

Treating the appropriate symptoms before event identification allows the plant to' stabilize permitting more accurate diagnosis. It also provides a i mere efficient means of proceduralising response to multiple events. For example,

. actions to restore feedvater are currently in 6 or more emergency procedures.

Since this is covered in an " interim" precedure it does not need to be repeated j in each event procedure.

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O REACTOR Forced ATP 10-1 ""

OTSG Tube Leak l

Loss of Excessive Lack of Heat Subcooled CooRng Transfer Margin <

ATP 1210-2 ATP 1210-3, ATP 1210-4

'O

RCS Superheated ATP 1210-8 I

Sma5 Break Large Break HPl Cooling OTSG Tube LOCA LOCA Solid OPS i Leak / Rupture ATP' 1210-6 ATP 1210-7 ATP 1210-9 ATP 1210-5 RX' Trip Followup jO Normai i

, Cooldown 1

i TRAINING CONTENT RECORD j Lesson Course Title - (N/A) Number - N/A)

Lesson Plan

Title:

AT0G Procedure Use Number - (N/A) j OBJECTIVES:

A. At the end of the presentation the student will be able to discuss in general terms:

1. ATOG integration with existing EP's, AP's and Alarm Responses.

2. Prioritiza'uion of AT0G Symptoms.

3. "Roadmap" concept as it refers to the ATP's.

4. The five (5) fundamental AT0G Control Concepts:

a. Reactivity

b. RCS inventory

c. Heat Transfer Control

d. Subcooling Margin

e. Radioactive Releases

5. Concept of Rules vs Guidelines.

l

6. Human Factor concepts incorporated into ATP's Format.

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RESPONSIBILITY , SIGNATURE TITLE DATE 0058-- e M Te IL. IA/7/M3 ORIGINATOR d f M_ o;. m$irew ddd-h /L/f/fra, REVIEh/ APPROVED Y Mgr. Plant Operatiens /A!f/ff REVIEW /APPROVEDd% % Ops, Training Manager n-y-s3

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LESSON PLAN

SUMMARY

q A. INTRODUCTION k/

1. AT0G History and Regulatory Requirement Nt! REG 0737 Supplement.

2. June 1981 Simulator Introduction to TMI-I Operations and -

Training - Training Documents.

3. Phase I of AT0G Implementation - Committee Representation.

4. ATOG Simulator Experience with Plant Engineering, Tech.

Functions, Plant Operations Personnel.

5. Phase II of ATOG Implementation - Connittee Representation.

6. NRC Acceptance of Oconee ATOG as basis with qualifications and additional concerns to be addressed prior to site specific AT0G acceptance.

7. Phase III of AT0G Implementation - Committee Representation.

B. ATOG PHILOSOPHY

1. Organization

2. ATOG Symptoms

3. Etent Cooldown Procedures C. ATP REVIEW

1. ATP 1210-1 Reactor / Turbine Trip

2. ATP 1210-2 Loss of Subcooled Margin -

3. ATP 1210-3 Excessive Cooling

4. ATP 1210-4 Lack of Heat Transfer

5. ATP 1210-5 OTSG Tube Leak / Rupture

6. ATP 1210-6 Small Break LOCA t

7. ATP 1210-7 Large Break LOCA *

8. ATP 1210-8 RCS Superheat

9. ATP 1210-9 Recovery from HPI Cooling - Solid Operations.

10. ATP 1210-10 Abnormal Transients Rules, Guides and Graphs.

D. QUESTIONS / COMMENTS O

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b O REACTOR 1

Forced -

ATP 1210-1 Shutdown OTSG Tube Leak Loss of Excessive Subcooled Lack of Heat Cooling Transfer 1

Margin -

ATP 1210-2 ATP 1210-3

~

ATP 1210-4 O

RCS Superheated ATP 1210-8 Sma5 Break Large Break HPI Cooling LOCA OTSG Tube LOCA Solid OPS i Leak / Rupture ATP 1210-6 ATP 1210-7 ;

ATP 1210-9 ATP 1210-5 m

RX Trip Followup O Nonnal Cooldown

ATOG integration to existing EP's, AP's and Alarm Responses will cancel the following procedures:

bs Emergency Procedure 1202-3 Turbine Trip Emergency Procedure 1202-4 Reactor Trip ,

Emergency Procedure 1202-5 OTSG Tube Leak / Rupture Emergency Procedure 1202-6A Loss of Reactor Coolant / Reactor Coolant Pressure Within Capability of Makeup System (RC Pressure above ESAS Setpoint).

Emergency Procedure 1202-6B Loss of Reactor Coolant / Reactor Coolant Pressure (Small Break LOCA)

Causing Automatic High Pressure Injection.

Emergency Procedure 1202-6C Loss of Reactor Coolant / Reactor Coolant Pressure Causing automatic High Pressure Injection, Core Flood and Low Pressure Injection.

[] Emergency Procedure 1202-26A Loss of Steam Generator Feed to Both OTSG's.

Emergency Procedure 1202-39 Inadequate Core Cooling (N0 LOCA)

A V ,

ATP 1210-1 REACTOR / TURBINE TRIP e ENTRY CONDITION - Control Rod Drive Mechanisms have received an Automatic or i

Manual trip signal.

NOTE The following sequence represents a prioritization of immediate -

actions. Although some or all steps may be performed in parallel it is essential that all innediate actions be performed at least once and within several minutes.

- IMMEDIATE ACTION - (Vital System Action, Status Verification, and Remedial Action).

1. Manually trip Reactor.

Verify less than 10% power.

IF power is not less THEN initiate HPI, Ilian 10% power; maximize letdown, trip 1G-02 and 1L-02 (panel PR), and maintain primary to secondary heat transfer.

Verify Groups 1-7 rod bottom lights.

IF one or more rods are THEN emergency borate.

O stuck out.

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2. Manually trip Turbine.

Verify T/G stop valves closed.

Verify Generator Breakers open.

IF_F T/G stop valves are THEN trip EHC-P-1A/B.

_ ___ _ _ _ not closed; IF generator breakers THEN manually trip GB1-12, remain closed; EBT 02 and locally trip field breaker.

3. Decrease Main Feedwater Flow.

I i

Verify ICS automatically is running back MFW flow.

IF ICS is not controlling THEN take Hand control MFW flow; of the MFW regulating valves and run MFW back to control OTSG level.

E MFW flow is still THEN trip both MFW pumps.

excessive; O

1.0 Draft 0

4. Varify ICS/NNI Power On (PCL)

E all subfeed power lights THEN trip MFW pumps, - - -

^ are off; establish Primary to U Secondary heat-transfer using backup manual loader stations for EFW and TBY.

Refer to EP-1202-40. .

IF any subfeed power light THEN refer to EP 1202-40/

Emains off; ~4T7T2.

5. Verify 4160 volt buses 1 A,1B,1C,1D and 1E energized (CR and PR)

IF loss of offsite power THEN verify or manually start lias occurred; and load at-least one D/G.-

- Restore Make-up, seal injection and EFW.

_I_F F both D/G fail to start; THEN refer to EP 1202-2A.

6. Start 2nd Make-up Pump.

Verify pressurizer level is greater than 100 inches.

IF unable to maintain THEN open MU-V-217 as pFessurizer level; necessary.

IF MU Tank is less than THEN open MU-V-14A or B T!P'; as necessary to maintain -

pd MU Tank level greater than 55".

IF unable to maintain THEN initiate HPI.

pFessurizer level greater than 20 inches;

7. Verify Safety System Status. _

Yerify RCS greater than 1600 psig and RB less than 4 psig.

Z ESAS 1600 psig/or 4 psig THEN verify HPI/LPI -

l actuation has occurred; components started and RB isolation.

E RB greater than 30 psig; THEN verify RB spray.

Verify OTSG greater than 600 psig.

-IF SLRDS has actuated; THEN verify affected 0TSG-MTisolation.

8. Announce Reactor Trip over plant page.

9. Verify subcooled margin greater than or equal to 250F.

l . IF subcooled margin is less THEN trip all RCP's, i

Wan 250F; TiiiTiate full HPI, initiate

! EFW, raise OTSG 1evel to 90-957, and go to ATP 1210-2.

2.0 Draft 0 l

10. Verify RCS temperature / pressure and 0TSG pressure approaching post trip temperatures and pressures within 2 minutes.

(q) IF Primary / Secondary Heat Transfer is excessive; THEN throttle MFW/EFW Ts'5 Tate steam leak, increase RCS make-up as necessary and

- ~ ~ ~ ~

absent other priority symptoms go to ATP 1210-3. -

IF Primary / Secondary Heat THEN absent other priority Transfer is inadequate; symptoms verify MFW/EFW and go to ATP 1210-4.

- 71. Verify RM-A-5 (or equivalent if RM-A-5 is 00S) noma 1.

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IF an OTSG Tube Leak / THEN absent other priority lliipture has occurred; symptoms go to ATP 1210-5.

FOLLOW-UP ACTION OBJECTIVE The objective of this procedure is to place the balance of plant components in a stable configuration and maintain RCS conditions stable until restart or cooldown direction is decided.

1. Close the following extraction valves:

(V' EX-V-1A EX-V-5C EX-Y-1B EX-V-5D EX-V-4A EX-Y-6A EX-Y-4B EX-Y-6B EX-V-5A EX-V-6C EX-V-5B EX-V-6D

2. Verify OTSG 1evel is being maintained at proper level.

3. Verify that turbine bypass valves (or, if vacuum is lost, atmospheric relief valves) are controlling at desired pressure.

4. Verify RCS pressure stabilizes within nomal pressure limits. -

5. E 1G-02 and 1L-02 were opened to trip the reactor, THEN:

a. Dispatch an operator to 338' elevation (3rd floor)

Control Tower to trip main (Unit 10) and Secondary (Unit 11) AC CRDM Supply Breakers.

b. Once Unit 10 and 11 Supply Breakers are open, then~

reclose 1G-02 and 1L-02 on Control Room Panel (PR).

c. Restart previously running equipment fed from:

1. Pretreatment MCC O 2.

3.

i^ ned este acc lA Reactor Plant MCC

4. 1B Radwaste MCC

5. 1B Reactor Plant MCC

6. A.C. Dist. Panel D-9 3.0 Draft 0

4

6. V:rify the following T/G support pumps are operating:

a. AC Motor Suction Pump

b. Turning Gear Oil Pump

.O c- searias 'ift eumPs

7. Reduce pressurizer level controller setpoint to 100 inches (25%).

8. IF a turbine rotatina component THEN declare an Unusual Event Hilure occurs causing the (carry out EPIP 1004.1).

Reactor Trip;

9. IF a turbine failure occurs THEN declare an Alert (carry fesulting in casing penetration out EPIP 1004.2).

10. IF the Reactor trip is coincident THEN declare an Unusual Event Eth a total loss of forced (carry out EPIP 1004.1).

reactor coolant flow;

11. IF the Reactor trip is coincident THEN declare an Unusual Event Wth a total loss of the ability (car'ry out EPIP 1004.1)..

4 to feed the OTSGs;

12. IF the Reactor trip is coincident THEN declare an Alert Wth either reactor coolant Tcirry out EPIP 1004.2).

outlet temperature greater than

or equal to 620eF;

13. IF the Reactor trip is coincident THEN declare an Alert Wth a reactor building pressure (carry out EPIP 1004.2).

O sreater thaa or equai to 4 Psis:

14. IF more than one control rod is THEN declare an Alert Euck out of the core following (carry out EPIP 1004.2).

a Reactor trip;

15. IF an unplanned ESAS actuation THEN declare an Unusual Event Ecurs following Reactor Trip; (carry out EPIP 1004.1).

15. Verify the following Reactor trip RB isolation valves closed:

RB Sump WDL-V-534 WDL-V-535 RC Drain Tank WDG-V-3 WDL-Y-303 WDG-V-4 WDL-Y-304 RCS Sample CA-V-1 CA-V-3 CA-V-2 CA-Y-13 RB Purge 4.0 Draft 0

AH-Y-1A AH-V-lC AH-V-1B AH-V-1D

~~

Core Flood Tank O CF-Y-2A CF-Y-2B CF-Y-19A CF-V-19B CF-V-20A CF-V-20A - -

Demin Water CA-Y-189 OTSG Sample CA-Y-4A CA-V-5A CA-Y-4B CA-Y-58 Letdown Cooler MU-Y-3

17. Reduce the running balance of plant equipment to that which is required to maintain plant conditions (i.e. one FW-P-1, one CO-P-2, No HD-P-1).

18. To open Containment Isolation Valves (CIV's) automatically closed refer to ATP 1210-10.

19. Determine shutdown margin per OP 1103-15, Reactivity Balance Calculation.

O' 20. Take hand control of TBV, reset the reactor trip and maintain hot shutdown conditions until decision on direction of plant movement is obtained.

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21 . Determine and evaluate cause of Reactor trip per Attachment I.

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5.0 Draft 0

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ATTACHNENT ( --

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THREE MILE ISLAND UNIT 1 REACTOR TRIP REPORT

1. Reactor Trip No.: (Yr. - Trip No.)

2. Date: (Month - Day - Year) Time

3. Cause of Reactor Trip: -

4. Plant Conditions prior to trip: -

Reactor Power Level

~

. Tave . .

RCS Pressure . RCP Combination .

hu Tank Level . Pressurizer Level .

RCS Boron . EFPD .

CRDM Percent withdrawn:

Group 1  % Group 3  % Group 5  % Group 7  %

Group 2  % Group 4  % Group 6  % Group 8  %

hu Pump Operating .

5. ICS Stations in Hand: .

6. Evolutions in progress prior to trip (include major ccmponents unavailable prior to trip). ,

I 7. Description of Transient (include any abnomal systems responses).

1

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l 8. haxircum RCS pressure during transient . Did PORY actuate 1 (Yes/No) .

9. Minimum pressurizer level during transient .

l Were additional MU pumps started (Yes/No - Tag No.) .

10. Record the reset pressure at which the last main steam relief valve closea.-

(Use observation of steam reliefs or chart recorder for this infomation).

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FOR USE IN UNIT I ONLY gag i 1

, ATTACHMENT t (Cont'd) - --

11. Did RPS/ESAS/EFW systems appear to auto function at the required setpoint and-in - - -

the appropriate time frame? (Indicate N/A if setpoints not reached). - -

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12. Were any Technical Specification L.C.0's violated? ( Yes/No-- -

Specify) (Submit 1044 as necessary). ,

13. Corrective Action taken to prevent future re-occurrence.

14. Radiological Impact of Transient (describe any abnomal readings from RhS).

15. Was the Emergency Plan Actuated? (Yes/No).

What level? .

16. Review Transient Cycle Log Book and record component cycles as necessary. List affected components:

17. Notify the Operations and Maintenance Director or designee to make the B and W trip notification using the " Notepad" Systems and Format. Person Notified: . - - - - - - -

18. Attach copies of the Bailey 855 sequence of events and any pertinent MOD Ccmp.

Transient Monitor graphs. - - - - - - - - - -

19. Time and Date of next Reactor Criticality .

20. Completed by: .

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21. Reviewed by Shift Supervisor: .

-s-

22. Reviewed by Manager Plant Operations: .

cc: Chaiman - Plant Review Gro'up

Director - Systems Engineering (Parsippany)

Director - Operations and Maintenance Vice President - TML Unit 1 -

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ATP 1210-2 LOSS OF SUBC00 LED MARGIN IMMEDIATE ACTIONS

1. Trip all RCPs.

2. Initiate HPI. (2 pumps full flow) ',

3. Verify EFW has auto started.

4. Raise OTSG level to 90%-95%.

FOLLOW-UP ACTIONS

1. IF a valid plant saturation THEN declare a Site Emergency.

Endition occurrs; (carry out EPIP 1004.3).

2. E excessive heat transfer exists; THEN go to ATP 1210-3

3. Isolate possible sources of leakage.

RC-Y-2 (PORY Block)

RC-V-3 (Spray Block)

MU-V-3 (Letdown Block)

4. IF subcooled margin has been THEN verify natural cir-Etablished; culation and go to step 10

5. IF incore themocouples indicate THEN go to ATP 1210-8 (bs superheat;

6. E core flood tanks are emptying; THEN go to ATP 1210-7

7. E there is lack of primary to THEN go to ATP 1210-4 secondary heat transfer;

8. IF there is indication of a SGTR; THEN go to ATP 1210-5 l

9. IF there is priitary to secondary THEN go to ATP 1210-6 Eat transfer and subcooled margin is not being recovered;

10. Restart RCPs, if possible, and establish pressurizer spray as follows:

10.1 Start one RCP per loop.

10.2 Monitor RCS pressure while opening RC-V-3 to detect failed open spray valve or spray line leak.

10.3 Throttle HPI. (Refer to ATP 1210-10 for Throttling Criteria).

11. IF there is lack of primary THEN go to ATP 1210-4 to secondary heat transfer; 1.0 l

Draf t 0

12. JfF,thereisindicationofaSGTR; THEN go to ATP 1210-5

13. -IF RCS is solid; THEN go to ATP 1210-9 to O- either draw a steam bubble or do a solid RCS cooldown.

14. Return to ATP 1210-1. .

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1 0 2.0 Oraft 0

I ATP 1210-3 EXCESSIVE COOLING IMEDIATE ACTIONS

1. ---IF HPI has not been initiated; THEN increase makeup to maintain pressurizer level on scale. -

2. IF_ OTSG 1evel greater than 95%; THEN trip the MFW pumps.

3. IF OTSG pressure is less than 600 THEN verify SLRDS has pi'ig; actuated.

4. Isolate the affected OTSGs (both if affected generator cannot be identified).

OTSG A OTSG B FW-Y-16A FW-V-16B FW-V-17A FW-V-17B FW-V-5A FW-V-5B FW-V-92A FW-V-928 MS-V-3D MS-V-3A MS-V-3E MS-V-38 MS-V-3F MS-V-3C MS-V-4A MS-V-4B MS-V-1A MS-V-lC MS-V-1B MS-V-lD

() 5. IF OTSG level and pressure did THEN close the following not stabilize; valves on affected 0TSG:

0TSG A OTSG B EF-V-30A EF-V-30B MS-V-10A MS-V-10B MS-Y-13A MS-V-138 FOLLOWUP ACTION

1. IF OTSG pressure and level stabilize THEN restor 1 main or

. on either generator; emergency feed to the good t

generator.

2. IF subcooled margin is less THEN go to ATP 1210-2 tEan 250F;

[ 3. IF Steam line break is not in the THEN E.D. may direct feeding Tntermediate Bldg; the affected 0TSG.

4. IF unable to restore primary to THEN initiate HPI cooling secondary heat transfer; and go to ATP 1210-9.

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( l.0 Draft 0 l

- =._ ____ -. - ---. - __ . . _. _ . - . - - . _ . - .

5. E OTSG tuba rupture is indicated; THEN go to ATP 1210-5

6. Feed one or both OTSGs to maintain level and control OTSG pressure and cold leg temperature.

7. Prevent RCS Heatup and repressurization. Evaluate for PTS per ATP 1210-10, Figure 1 and 1A.

, 8. Return to ATP 1210-1.

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't 2.0 Draft 0 1

I

I ATP 1210-4 LACK 0F HEAT TRANSFER O IMMEDIATE ACTIONS l

1. E RC pressure increases to the PORY THEN go to step 3.1 -

i setpoint;

2. Initiate FW.

2.1 Start EF-P1, EF-P2A, and EF-P28. Open EF-V-30A and B by either the Hand / Auto station or the Manual Loader.

2.2 E EFW is not available; THEN use Main FW.

2.3 IF neither WW nor EFW are available; THEN attempt to restore emergency feedwater per ATP 1210-10.

3. E neither MFW nor EFW can be established; THEN:

' 3.1 Initiate HPI (2 pumps full flow).

3.2 Open RC-V-2.

3.3 Open PORY (RC-RV2) 3.4 Run one RCP as long as subcooled margin exists.

3.5 Go to HPI cooling procedure ATP 1210-9.

FOLLOWUP ACTIONS

1. IF there is a total loss of MFW;

-- THEN declare an Unusual Event (carry out EPIP 1004.2).

2. Attain appropriate OTSG 1evel based on RCP operation and subcooled margin.

3. E CFT's have emptied, THEN go to ATP 1210-7.

4. IF while attempting to re-establish heat THEN open the PORY Transfer RCS pressure increases to the linU1 5 RCS decreases to PORY setpoint; . 100 psi above OTSG pressure.

5. Lower OTSG pressure until secondary Tsat is 40 to 60oF lower than incore T/C temperature. Maintain OTSG 1evel.,

6. IF primary to secondary heat transfer is THEN close the PORY (if re-established; open) control HPI per O '

Hel throttie criteria and return to ATP 1210-1.

1.0 Draft 0

7. -

IF RCP's are n3t available for bumps; THEN initiate HPI C55 Ting and go to ATP 1210-9 v 8. Use RCP bumps to induce heat transfer.

8.1 Bump either RCP in the loop with the highest OTSG 1evel.

8.0 Allow RCS pressure to stabilize and detennine whether heat transfer is established.

8.3 E heat transfer is established; THEN go to step 12 8.4 Continue " bumping" remaining operable RCP(s) at 15 minute intervals until either:

a. Heat transfer has been THEN'go step 12.

established;

b. All operable RCPs have been THEN go to step 9 "t"anped" and heat transfer has not been established.

9. Lower OTSG Pressure to induce heat transfer.

4 9.1 Decrease OTSG pressure until secondary Tsat is 90 to 1000F lower than incore T/C temperature. Maintain OTSG 1evel.

10. IF one hour has passed since reactor THEN start and run one Trip and a RCP is operable; E O

11. TF neat transfer has not been THEN initiate HPI rii-established; cooling and go to ATP 1210-9

12. Verify heat transfer is established and recover from HPI cooling, if initiated.

12.1 Close PORY (RC-RV-2).

12.2_IF the PORY does not close; THEN close RC-V2.

12.3 Throttle HPI, if permitted.

12.4 Restart RCP if restart criteria is met.

I

13. Control OTSG pressure to stabilize RC temperature.

14. ,I_FF OTSG tube rupture is indicated; THEN go to ATP 1210-5.

15. IF subcooled margin does not exist cooldown per ATP 1210-6.

l l

16. Return to ATP 1210-1.

l l

(o Oratt 0

ATP 1210-5 OTSG TUBE LEAK / RUPTURE O NOTE

1. OTSG tube leak: greater than 1 and less -- --

than 50 gpm.

2. OTSG rupture: greater than or equal to 50 9Pm.

IMMEDIATE ACTIONS

1. ---IF the reactor was not tripped; THEN close MU-V-3 and begin to reduce load at a rate specified by the Shift Supervisor to minimize the risk of a MS Safety Valve lif ting.

2. -

IF the reactor was tripped; THEN absent other untreated priority symptoms, proceed with plant cooldown per this procedure.

FOLLOW-UP ACTION O NOTE ,

Refer to Table 1 for Emergency Action level Declaration guidance, and OTSG isolation considerations for Emergency Director.

-1. - Continue to reduce power to less than 20 percent at the selected load reduction rate. Consult OP 1102-10, Plant shutdown for guidance.

4 NOTE When removing the first main feed pump (40 percent pwr), remove the feed pump that is being steam fed from the affected 0TSG if known. Remove the feed pump per OP 1102-10.

- - - - - - - - ' ~ ~ ~

2 By sampling OTSG's, surveying steam lines, observation of OTSG 1evels and feed rates, determine affected 0TSG.

O i.0 Oraft 0 l

l

l NOTE Most affected 0TSG should indicate higher i level, lower feed rate, and/or higher O seta-ca- . 8 . 3Na24,1.i33 and CS-ia7 sam,le results. . _ _

__ CAUTION When the turbine is tripped it may be necessary to take manual control of turbine bypass valves to maintain secondary pressure below the main steam safety valve setpoints.

3. At less than 15 percent PWR take the turbine to manual and unload to "0" MWE. Verify that the turbine bypass valves automatically control header pressure below safety valve setpoints. At "0" MWE trip the turbine while closely monitoring OTSG pressure. Observe turbine stop valves closed.

CAUTION The following power reduction and Rx Trip will cause a significant RCS shrinkage, insure sufficient make-up to maintain normal pressurizer level . Adhere to Pressurizer Level O ouide-

4. Place the Diamond in manual and continue reducing Rx Pwr to less than 5%. When less than 5% reactor power, take manual control of the turbine bypass valves and then trip the Reactor. Imediately adjust TBV closed to control the initial cool down following Reactor trip and control OTSG pressure to prevent safety valve operation.

5. If the OTSG level rule of 90-95% is in effect, raise the unaffected OTSG to 90-95% before raising the affected OTSG to 90-95%.

6. Steam both OTSG's to reduce RCS to less than 5400F.

7. Turn off PZR Heaters and start pressurizer spray to depressurize RCS which minimizes the subcooled margin. The Pressurizer Vent may be used to reduce RCS pressure. If the pressurizer vent is not sufficient, the PORY may also be used.

l O z.0 Oraft 0

NOTE Minimizing subcooling margins above 250F will- ~ -

O c'" "c5 **"a'ar*** * ' '"' '"*' a'"

compression curve (OP 1102-11). This is

, acceptable only during rupture emergencies, and requires Engineering Evaluation prior to next .

heat up. For other than tube rupture, fuel pin compression curves should not be violated.

8. When SCM has been minimized, control turbine bypass valves and commence plant cooldown at less than 1000F/HR (1.60F/ min). (Refer to OP 1102-11 for additional guidance on BOP equipment.)

9. Reduce RCP's to one per loop, when the additional spray is no longer required to control SCM. RCP's must be reduced to less than 4 RCP's before RCS temp is decreased below 5000F.

NOTE Keep RC-P-1A on for PZR spray.

10. Monitor tube to shell delta T and maintain it less than 700F using MFW. If this limit is approached while steaming, then reduc,e or secure the cooldown rate as necessary.

Q 11. Confinn affected 0TSG by sampling.

12. When RCS hotleg and incore thermocouples temperatures are less than 5400F, isolate the affected 0TSG when BWST level is less than 21 ft, or off-site dose projections approach 50 mr/hr whole body or 250 mr/hr thyroid.

13. If required to isolate the affected OTSG, then close the following:

NOTE i

Assure MFP is being fed from unaffected 0TSG or Auxiliary Steam. Assure gland steam is from

the Aux. Boiler.

l l

l l MS-V-1 A and B or C and D FW-V-17 A or B FW-V-5 A or B FW-V-16 A or B O

3.0 Draft 0

---

g , - , -- .-~._,,,,n_

---

n ,n.-- - . - . , , - - . , _ , , , - . , - , - - - - -. -.. ,.------ - - , _ _ . . ,

FW-V-92-A or B FW-Y-85 A or B Q EF-V-30 A or B MS-V-92

~

MS-V-89 A and B or C and D MS-V-13 A or B (close manual hand wheel)

MS-V-10 A or B MS-V-3 D/E/F or A/B/C

14. If both OTSG's are required to be isolated and can no longer be used as a heat sink then go to ATP 1210-9.

NOTE If OTSG pressure cannot be maintained less than 1000 psig, protect against any challenge to the MS Safety Valves by opening the Turbine Bypass and/or Atmospheric Dump Valves.

Q 15. Affected OTSG must be steamed without exceeding the cooldown rate limits to maintain less than 95 percent on operate range and less than 70of tube to shell delta T, unless either the BWST is less than 21 Ft. or off-site dose projections approach 50 mr/hr whole body or 250 mr/hr thyroid.

NOTE Under emergency situations, blocking / pinning of MS hangers when flooding the applicable MS lines is not necessary. If the MS lines are filled without blocking / pinning of the MS hangers, an engineering evaluation of the structural integrity of the MS lines must be performed prior to resuming normal operations. ,

16. Maintain less than or equal to 1000F/hr. (1.60F/ min.) cooldown rate by steaming both OTSG's. If the cooldown rate is greater than 1000F/hr. (1.6oF/ min.) due to three pump HPI cooling, secure the non-ES selected MU pump and observe HPI throttling criteria for the two ES selected MU pumps.

17. If RCS pressure is being controlled and an adequate subcooling margin exists, then bypass ESAS at normal bypass pressure setpoints.

4.0 g,agg o

18. If subcooled margin exists, then isolate CF-V-1 A/B when RCS pressure is less than or equal to 700 psig.

19. Notify Radiological Controls of the shutdown due to OTSG tube leak and to continue to survey the Intermediate and Turbine Buildings to

({]) ~ determine the need for controlled areas. Initiate Emergency Plan _if

, required, as a result of the surveys.

20. Notify Unit II Control Room to isolate auxiliary steam cross connect by closing AS-V-23 and its bypass AS-V-209.

21 . For other than tube rupture, refer to NPSH curve in Figure 1 and 1 A of 1102-11. Refer to Figure 1 and l A of ATP 1210-10 for rupture emergency NPSH limits for one RCP in each loop operation.

NOTE The emergency NPSH and SCM limits are plotted on a composite graph but are verified using i different instruments. Use those instruments as noted on figure 1 and 1A.

22. Decay Heat Removal may be initiated at 3000F by first tripping all RCP's if the consequences of losing RCS loop forced flow are acceptable (i.e. hot leg steam bubble).

23. When on DH Removal, depressurize RCS to vent header pressure per OP 1104-4.

O 24. When time permits, initiate performance of condenser partition'~ ~

~ ~ ~ ~ ~ ~

factor Surveillance Test No. 1301-9.6.

25. If OTSG tube leakage exceeded the limits of Tech. Spec. 3.1.6.3, then an unscheduled inservice inspection of the affected 0TSG must be conducted prior to startup pursuant to Tech. , Spec. 4.19.3.,C.l ._ __ __ . _ _ _

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. TABLE  ;

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EMERGEG Y ACTION LEVEL DECLARATION

s.z-iw.3..

CRITERIA";E*y; ,g

- M':. #.

.- 1.j; .. ' . . -' -

.q. ..' : .. .:p'n8 Condition Unusual Event Alert Site 1./s.: . - General

. i:' - '

. ... c Tube Leak Alone igpm - 50 gpm > 50 gpm Any Tube Leak N/A and Saturation - -

< 250 Subcooled

' Steam' Generator Tube Leak N/A 1 gpa - > 50 gpa N/A Plus - Loss of Off-site Power 50 gpm Steam Generator Tube Leak N/A 1 gpm - > 50 gpm N/A Plus - Steam Line Break 50 gpm Steam Generator Tube Leak N/A 1 gpm - > 50 gpm N/A Plus - Loss of Condenser 50 gpm Steam Generato Tube Leak N/A N/A > 50 gpm N/A With 1*. Failed Fuel -

RMA-5 Low Range High Alarm ~

N/A N/A '- N/A - ~~ ~~

Offsite Dose Projection / Report Whole Body N/A > 10mr/hr > 50 mr/hr

_ > 1R/hr Thyroid N/A > 50mr/hr > 250 mr/hr

_ _ _.)SR/hr.___._

~~

l l

6.0 Draft 0

-~

_ STEAM GENERATOR ISOLATION CONSIDERATIONS FOR THE E.D. WITH CONCURRENCE BY THE E5D _. _ _ _

GENERAL

1. Isolation of one or both OTSG's reduces the RCS cooldown rate which increases the time to reach cold shutdown and to terminate the primary to secondary leak. ,

2. Isolation of one OTSG when both are leaking may increase the integrated dose since the release will continue frm the unisolated 0TSG for a longer period. _. _

3. Isolation of both OTSG's requires feed and bleed cooling which could result in releases of steam or steam and water directly to the atmosphere.

- - 4. An isolated OTSG may flood, after wilich it may not be possible to unisolate and return the OTSG to service.

5. Isolation of direct steam releases to the atmosphere is expected to reduce the offsite thyroid dose by a factor of at least 8. ~~

6. Isolation for dose reduction should be based on measured dose rate to preclude premature isolation. _ _. __

I. ISOLATION OF ONE OTSG SHOULD BE AVOIDED IF

1. RCP's are not available - natural circulation cooldown may not be possible with one OT5G since flow in one loop can stagnate and bubble could fonn in the hot leg as primary pressure is reduced.

2. Both OTSG's leak but the difference in leak rate is less than a

-- --~

factor of eight. Otherwise, the delay in cooldown may negate the dose reduction fom isolating one OTSG.

~

l

! II. OTSG ISOLATION MAY BE DESIRABLE IF

1. RCP's are operating, the condenser is unavailable, only one OTSG is leaking and iodine dose rates are high. In this situation high iodine release rates could be terminated by isolation of the

~

lesking OTSG.

Although cooldown time is increased, radioactivity releases will be terminated and RCP operation enables control of the RCS which in turn allows cooldown of the leaking OTSG. _ _ _ _ ___ _

III OTSG ISOLATION CRITERIA SHOULD BE REEVALUATED IN THE FOLLOWING SITUATIONS

1. RCP's Operating, condenser unavailable, both OTSG's leaking, iodine dose rates are high - isolation of one OT5G may be desirable if the leak rate in one OTSG is significantly (about 8) greater than in the other. The reduced dose rate from isolation of one OTSG must be weighed against the shorter cooldown time with steaming both OTSG's.

7.0 g

. . . - - . , - _ . - , , - . , , - - .,.c.- - , _ , , - - . - -. p.__

2. Cond:nser available - Isolation of on2 or both OTSG's greatly increases comidown times and increases risk of inadvertent or uncontrolled releases. A decision to isolate earlier than required by procedural guidelines should be based on measured dose rates if s possible. In the absence of fuel failures, actual releases under s such conditions are expected to be quite low.

Only one OTSG is leaking and BWST level is 21 feet. If the good 3.

OTsG 1s not expected to leak because shell/ tube delta T is being -

controlled, then isolation is not required. Recall than the BWST level was based on both steam lines being flooded. If only one OTSG may be flooded, then BWST depletion could not occur until 15 ft.

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StRMARY .. . ,, ?..,.; . ..:.%,,v t,:.W L4..:..i. ww... .:;:ms.tdg nL ,2h6

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-Both OTSG * ' -- # - "

Both OTSG

• One OTSG ' Leaking more ' '"'C ' Leaking J -

CP Condenser Leaking Than 90% to One -

Equally , c.~

ON Available -

Avoid isolation Avoid isolation Avoid isolation (III.2) (III.2)

(III.2. I.2)

ON Not Available Consider isolation Consider isolation Avoid isolation (II.1) (II.1) _

of one (I.2) 0FF Available Avoid isolation Avoid isolation Avoid isolation of one OTSG (I.1) of one OTSG (I.1) of one OTSG

( I .1, I . 2,_III ._2_)_ _.

OFF Not Available Avoid isolation Avoid isolation Avoid isolation

. of one OTSG (I.1) of one OTSG (I.1) of one (1.1, I.2)

. - +

O O

9.0 Draft 0

TEMPORARY-SHORT TERM MEASURES TO REDUCE OR TERMINATE RELEASES

1. Releases can be temporarily terminated by-() a. Terminating steaming to the condenser and not steaming to atmosphere. _ _ _ _. _.

b. Not more than 1 RCP should be run. -

c. If natural circulation is lost, steam again.

If steam generator pressure reached 1000 psi., steam again.

d. Heatup rate, following tenmination of steaming, is estimated to be 100-1700F.  ;

These steps may. provide enough time to return an RCP to operation, restore a condenser to service, or initiate protective actions, while delaying the initiation of feed and bleed cooling.

O T

l 4

4 O

10.0

ATP 1210-6 SMALL BREAK LOCA IMMEDIATE ACTIONS

1. Verify that loss of subcooled margin is being treated.

1.1 HPI initiated (2 pumps full flow). .

1.2 All RCP's off.

1.3 EFW actuated and level being increased to 90-95%.

2. Verify that reactor trip containment isolation has occurred.

3. Verify that 1600 psi and 4 psi containment isolation has occurred.

4. Maintain primary to secondary heat transfer by reducing OTSG pressure.

5. IF F primary to secondary heat transfer THEN open the PORY and keep cannot be established; it open until heat transfer is established or LPI is in operation.

FOLLOWUP ACTIONS CAUTION DO NOT START ANY MAJOR MOTORS DURING BLOCK LOADING.

O CAUTION 00 NOT ATTEMPT TO OPERATE ES VALVES TO THE NON-ES POSITION AND 00 NOT TRIP ANY ES COMPONENTS UNTIL THE ES SIGNAL IS BYPASSED. THE BREAKER ANTI-PUMP FEATURE WILL PREVENT RECLOSURE OF TRIPPED BREAK-ERS UNTIL THE ES START SIGNAL IS CLEARED.

1. IF a valid plant saturation THEN declare a Site Emergency c6ndition occurs; (carry out EPIP 1004.3). ,

2. IF at any time the RCS becomes THEN go to ATP 1210-8 siiperheated;

3. IF at any time indications of OTSG THEN go to ATP 1210-5 Tube rupture occur;

4. Maintain RCS pressure and temperature in the applicable region of the pressure temperature curve in ATP 1210-10. (Comply with Emergency NPSH requirements).

5. Verify containment emergency cooling.

6.

pd Maintain RCP seal injection and seal cooling to assure long term availability of the RCPs.

l l

1.0 Draft 0

i

7. Control HPI and restart RCPs whtn conditions are met. (Refer to ATP 1210-10).

8. Close; O RC-V-40A/B RC-V-41A/B RC-V-44 -

RC-V-28 RC-V-42 RC-V-43.

9. If the RCS is solid and subcooled, then refer ATP 1210-9 to establish a pzr steam bubble.

10. Maintain steam generator tube to shell dT less than 700F.

11. Cooldown at approximately 1000F/ hour (1.60F/ minute), using ATP 1210-10 figure 1 and 1A.

12. Stop non-essential secondary equipment when time pemits.

13. -

IF subcooled margin is regained; THEN CF-Y-1A and CF-V-1B may be closed when RCS pressure reaches 700 psig.

14. Monitor BWST level. If a source of barated water is available makeup to the BWST to avoid transfer to the RB sump while the HPI pumps are on.

O is. If eiectricai ioadin9 Permits. bypass ES and start a spent fuei Pump (6 amp) and penetration cooling fan (10 amp). (IP and IS Bus Load Limit 180 amps.)

16. Prior to going on DHR or establishing recirc. from the RB sump open DH-V-64 and MU-V-198 to minimize radiation exposure.

17. IF after 20 minutes the diesel THEN bypass ES and place the giinerators are not required; diesels in standby.

18. IF BWST level reaches 36 inches THEN establish HPI/LPI TE0-LO level alarm) before LPI flow operation in the " piggyback" is established; mode as follows:

a. Open DH-Y7A while observing HPI and LPI flow.

b. Open DH-V-6A.

c. Close DH-V-5A while observing LPI flow.

d. MU-V-14A may be left open in case the LPI pump trips.

e. Open DH-Y-7B while observing HPI and LPI flow,

f. Open DH-V-68.

g. Close DH-V-5B while observing LPI flow.

h. MU-V-148 may be left open in case the LPI pump trips.

O 2.0 oreft 0

19. Place the RB hydrogen monitor in service p:r OP 1105-18 and start the Hydrogen Recombiner if hydrogen level reaches 0.5% (OP 1104-62).

O ~~

20. when BwsT 1evel reaches 36 inches and LPI flow is established transfer LPI suction to the RB sump.

21 . Stop emergency feedwater when LPI or DHR is in operation. ,

22. Throttle DH-Y-19A and B and re-open DH-V-4A and B.

24. Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> assess Auxiliary Building radiation levels and establish one of the long term recirculation modes in OP 1104-4.

25. IF controls for DC-V-2A/B and DC-V-65A/B THEN control cooling are in-accessible; rate by throttling DR-Y-1A/B.

Monitor RB sump for ph, boron concentration, and isotopic analysis.

26.

Add sodium hydroxide thru the DHR system as required to control ph.

27. Containment isolation valves may be opened when the criteria is met. (Refer to ATP 1210-10).

O O

3.0 Draft 0

• * " ' =-- ~,-.w w . . . - . _ . , _ _, __

ATP 1210-7 pdGE BREAK LOCA IMMEDIATE ACTION Q 1. Verify that HPI and LPI pumps are operating and valves are full open.

4 2. Verify that both Core Flood valves are open.

3. Verify that RB Spray and RB Cooling are operating.

4. Verify that Reactor trip containment isolation has occurred.

5. Verify that 1600 psi and 4 psi containment isolation has occurred. 7 FOLLOW-UP ACTION CAUTION DO NOT START ANY MAJOR MOTORS DURING BLOCK LOADING.

CAUTION DO NOT ATTEMPT TO OPERATE ES VALVES TO THE NON-ES POSITION AND l DO NOT TRIP ANY ES COMPONENTS UNTIL THE ES SIGNAL IS BYPASSED,  !

THE BREAKER ANTI-PUMP FEATURE WILL PREVENT RECLOSURE OF TRIPPED BREAKERS UNTIL THE ES START SIGNAL IS CLEARED.

1. Declare a Site Emergency (carry out EPIP 1004.3).

2. Close MS-V-1 A,B,C and D.

3. Verify RB isolation by checking the indicating lights for each valve-on panel PCR.

4. If only one LPI pump is operating, open DH-V-38A and B, to provide

.at least 1000 gpm per leg.

5. IF RCS pressure is above the THEN go to ATP 1210-6 iiiaximum pressure for LPI operation;

6. IF superheat is indicated by ir. core THEN go to ATP 1210-8.

T[C;

, 7. Monitor BUST and Sodium Hydroxide tank levels. Verify Hydroxide is being injected to control ph.

8. Stop non-essential secondary equipment when time permits.

9. Throttle LPI/BS pumps only if required to prevent pump runout (LPI 3500 gpm, BS 1800 gpm).

10. Refer to ATP 1210-10 for criteria for HPI termination.

. O n. Open DH-V-64 and Hu-V-igs before recirculation is established from the RB sump.

1.0 Graft o

12. IF BWST leval reach 2s 36 inches THEN establish HPI/LPI TE0-LO level alarm) before HPI is operation in the " piggyback" terminated; mode as follows:

O a.

b.

Open DH-V-7A while observing HPI and LPI flow.

Open DH-V-6A

c. Close DH-V-5A while observing LPI flow,

d. MU-V-14A may be left open in case the LPI pump -

trips.

e. Open DH-V-78 while observing HPI and LPI flow. i

f. Open DH-Y-6B '

g. Close DH-V-5B while observing LPI flow,

h. MU-V-148 may be left open in case the LPI pump trips.

13. Switch LPI suction to the RB sump when the BWST decreases to 36". .

14. Place the RB hydrogen monitor in service per OP 1105-18 and if hydrogen level reaches 0.5% start the Hydrogen Recombiner (1104-62).

15. IF after 20 minutes the diesel THEN bypass ES and place the giinerators are not required; diesels in standby.

16. Stop emergency feedwater when LPI or DHR is in operation.

17. Start Spent Fuel Cooling (6 amps) electrical load permits (1P &lS bus load limit 180 amps).

18. Stop RB Spray pumps when RB pressure is less than 4 psig.

O 19- Tarottie os-v-19^ aad 8 and re-oPea os-v-4^ aad B-1 20. Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> assess Auxiliary Building radiation levels and establish one of the long term recirculation modes in OP 1104-4.

21 . IF controis for DC-V-2A/B and THEN control cooling rate by UC'-V-65A/B are in-accessible; throttling DR-V-1A/B. .

22. Monitor RB sump for ph, boron concentration, and isotopic analysis.

Add sodium hydroxide thru the DHR system as required to control ph.

23. Containment isolation valves may be opened when the criteria is met. (Refer to ATP 1210-10).

l O

2.0 Draft 0

_ - , _ . - ~ --

ATP 1210-8 (RCS SUPERHEATED)

O I=<E0IATE ACTION

1. Verify HPI and LPI have been initiated (all available pumps).

2. Verify OTSG levels are 90-95%. -

i

3. Decrease OTSG pressure to achieve 1000F/hr decrease in secondary saturation temperature.

4. Verify core flood valves CF-V-1 A and CF-V-1B are open.

5. IF RCS pressure is greater than THEN open the PORY until l!700 psig; . Fpressure decreases to 100 psig above OTSG pressure.

. FOLLOW-UP ACTICN

1. IF the RCS hot leg temperature is THEN declare an Alert Featerthan6200F; (carry out EPIP 1004.2).

2. IF any two valid incore temperature THEN declare a Site Emergency Radings greater than 7000F .(carry out EPIP 1004.3).

following a Rx trip;

3. Determine region on PT curve, Figure 1 in ATP 1210-10, and proceed as follows:.

O 3.1 E saturated THEN go to ATP 1210-2.

3.2 -IF beyond curve 4 THEN go to Immediate ActTons above.

3.3 IF beyond curve 5 1 HEN go to Step 4.

3.4 E beyond curve 6 THEN go to Step 5.

4. .Incore Themocouple Temperature beyond Curve 5 4.1 Start one RCP per loop if possible without defeating interlocks.

CAUTION Do not go below steam pressure required for EF-P-1 (150 psig) unless EF-P-2A or EF-P-28 or auxiliary steam (for EF-P-1) is available.

4.2 Decrease OTSG pressure to 400 psig or less to achieve a 1000F decrease in secondary T-sat.

Q- 1.0 Draft 0

._ ,.,...~____.,,__,_,...,m _ , . . . _ _ _ _ _ _ _ _ , , . _ _ _ . , . . . , . . _ . _ . . _ _ , _ _ _ _ . . _ _ . . - . _ _ _ _ _ _ _ . . _ . _ .

I l

4.3 Open high point vents.

RC-V-40A

-O RC-v-40B i

RC-V-42 RC-V-44 RC-V-41A RC-V-418  :

RC-V-43 RC-V-28 I

4.4 Continue to decrease OTSG pressure to maintain a 1000F/hr decrease in secondary T-sat.

4.5 Monitor reactor building hydrogen levels and start the recombiner if H2 concentration is greater than 0.5% (OP i 1104-62).

4.6 If primary to secondary heat transfer cannot be established

. open the PORY (RC-RV-2) and block valve (RC-V-2) and keep them open. (Refer to Attachment 1 for the PORY jumper procedure.)

When the RCS returns to saturation go to ATP 1210-9.

4.7 IF primary to secondary heat THEN cycle the PORV to Iransfer is established; matritain RCS pressure at 25 to 100 psig above OTSG pressure.

4.8 When the RCS returns to saturation close the high point vents I

O aad PORv aad so to ATP izi0-2.

5. Incore Thermocouple Temperature beyond Curve 6.

5.1 Defeat starting interlocks and start all available RCPs. Do not defeat overload trips. (Refer to Attachment 2 for the RCP interlock defeat procedure.) '

5.2 Decrease OTSG pressure as rapidly as possible to atmospheric 4

pressure if auxiliary steam (For EF-P-1) or EF-P-2A or EF-P-2B is available (150 psig if not).

5.3 Open the PORY (RC-RV-2) and block valve (RC-V-2). (Refer to Attachment 1 for the PORY jumper procedure.)

i I

5.4 Open high point , vents.

RC-V-40A RC-V-40B RC-V-42 RC-V-44 RC-V-41 A RC-V-41 B RC-V-43 RC-V-28 O s s Operate 11 atmosphere.

r9i a-NOTE 9.3 Energize all pressurizer heaters. .

CAUTION Compensate for increasing pressure (due to heating pressurizer) by throttling open on MU-Y-5.

9.4 Monitor pressurizer water temperature. Do not exceed a 1000F/Hr. heatup rate.

9.5 When pressurizer temperature reaches saturation temperature for the desired RCS pressure, increase letdown until letdown is 25 gpm greater than makeup. Monitor the RCS saturation margin and manually open turbine bypass valves to maintain 250F subcooled.

9.6 Place pressurizer heaters in auto control with setpoint at the desired pressure.

9.7 Carefully monitor RCS pressure decrease to saturation pressure for pressurizer temperature at which point pressure stabilization should occur.

CAUTION Do not let pressure decrease violate the 250F subcooled l margin requirement.

NOTE

1. Continued stable RCS pressure with letdown greater than makeup indicates formation of steam bubble in pressurizer.

2. With a 25 gpm excess letdown (vs. makeup), the pressurizer level will drop at approximately 1.5 inches per minute. At this rate it will take between 25 and 30 minutes for level to come onto scale.

Select (search) alternate pressurizer level instruments during bubble formation to read on scale level as soon as it becomes available.

2.0 Draft 0 l

I. . - . - - . - . . . - - - . . - - - . - - . . --- - - - - - - - ------- ---- -

l l

l I

CAUTION m If pressurizer level is not on scale after 40 minutes with (d a 25 gpn excess letdown and if a stable RCS pressure is being maintained, reduce excess letdown and investigate level instruments for malfunction.

9.8 Continue cooldown using OP 1102-11.

10. If pressurizer steam bubble is not established then continue HPI cooling until recirculation from R8 sump is required by BWST level.

11. When RCS pressure and temperature conditons a e met establish DHR and stop RCP.

12. When RCS pressure is stable and DHR flow is greater than 1500 gpm close the PORV and high point vents. Stop the makeup pumps when seal injection is no longer required.

O O

3.0 Draft 0

I-ENCLOSURE 1 Verify that total HPI flow exceeds the required flow for RCS pressure as indicateri below.

RC Pressure, psig Required HPI flow gpm 0 530 -

600 530 1200 470 1500 430 1600 420 1800 390 2400 280 2500 250 If flow requirements are not met verify valve positions and attempt to start another Make-Up Pump.

4 O -

'+

O 4.0 Draft 0 i

ATP 1210-10 ABNORMAL TRANSIENTS RULES, GUIDES AND GRAPHS O CONTENTS SECTION 1.0 RULES 1.1 Margin to Saturation Determination / Limit -

1.2 High Pressure Injection (HPI) Initiation Criteria.

1.3 High Pressure Injection (HPI) Throttling Criteria.

1.4 Reactor Coolant Pump (RCP) Trip Criteria.

1.5 Emergency Feedwater (EFW) Throttling Criteria. -

1.6 OTSG Level Rule.

SECTION 2.0 GUIDES 2.1 Reactor Coolant Pump (RCP) Restart Criteria.

2.2 Pressurizer Level Guide 2.3 Emergency Feedwater (EFW) Actuation Response 2.4 Operation of Containment Isolation Valves after Auto Closure.

Os 2.5 Elevated Reactor Building (RB) Temperature / Rapid RCS Depressurization Effects on Instrumentation.

2.6 Reactor Coolant (RCS) Natural Circulation Verification 2.7 Actions for Failure of the Emergency Feedwater System 2.8 Actions for Low Level Alanns on Condensate Storage Tanks.

. _ . . . 2.9 Feeding Dry OTSG SECTION 3.0 GRAPHS AND TABLES Figure 1 RCS Press / Temperature Limits Figure 1A RCS Press / Temperature Limits Narrow Range. _ _ _ _

Table 1 Pressurizer Spray Flow for Various RCP Combinations O

1.0 Draft 0

x

.g m

• 1.0 RULES O i .i HarsiatoSaturationoetemisatiea/'imitauie The minimal margin to, saturation is 250F as determined by the saturation margin meter and/or the average of the five -(5) -

P.ighest operable incore thermocouples and RC narrow or wide range pressure indication.

a. Use the most conservative operable indication of saturation margin. .

b. The saturation margin meter is' only to be used when RCP(s) are operating and RCS temperature greater than 3000F.

~

4 1.2 High Pressure Injection ~(HPI) Initiation Criteria '

Full (2 MU pumps) HPI must be initiated at full,' capacity when:

a. 1600 psig ESAS has auto initiated or '

b. Subcooling margin is less than 250F or O c. Neither OTSG is available as a heat sink 1.3 High Pressure Injection (HPI) Throttling Criteria Throttle HPI only if one or more of the following criteria are met: -

a. HPI must be throttled to prevent pump runout (550' gpm/ pump).

NOTE Do not throttle to less than 500 gpm/ pump unless one of the below criteria (b,c, or d) is met.

b. HPI must be throttled to prevent violation of the applicable brittle fracture / Thermal shock curve limitations.

c. HPI may be throttled if LPI flow is greater than 1000 gpm in each line and stable for 20 minutes.

Q 2.0 .-

Draft 0

d. HPI may be throttled if the required 25 F subcooling margin exists and pressurizer level is established greater than 0".

1 Open MU-V-36 and MU-V-37 when HPI is manually throttled below 500 gpm/ pump.

- - - - ~ ~ - - - - -

1.4 Reactor Coolant Pump (RCP) Trip Criteria A. If 25oF subcooling margin is lost immediately trip all

operating reactor coolant pumps (RCPs).

CAUTION If 25oF subcooling margin is lost and all operating RCPs are not tripped within two (2) minutes. Then leave one RCF per Loop on for at least two hours.

B. If 25oF subcooling margin is lost immediately following a RCP restart and does not return witntn z minutes, the RUP must be tripped again and not restarted until 25oF

subcooling margin is regained.

O 1.5 Emergency Feedwater (EFW) Throttling Criteria ,

A. To prevent RCS overcooling due to excessive feed rates, 4 manually control EFW flow as necessary to maintain OTSG pressure to within 100 psig of desired pressure.

Monitor RCS Cold Leg Temperatures to insure that EFW flow is not causing a significant RCS temperature decrease B. To insure adequate EFW flow, verify decreasing incore T/C temperatures.

If incore T/C temperatures are not decreasing, increase i EFW flow to at least 450 gpm (27!igpm per SG) until OTSG level setpoint is reached. If incore T/C's are decreasing, the 100 psig criteria takes priority.

1.6 OTSG Level Rule l A. If 25oF subcoolin operable OTSG(s) to g margin 90-95% is lost raise (Operating level in the Range).

NOTE If the loss of subcooling margin was due to a loss of Q secondary system pressure do not attempt to raise level in the affected OTSG(s) until pressure control is ,

regained.

i 3.0 Draft 0 '

t I- , - _ . . - . _ - - - . - . . . _ . _ . _ - _ - - . . - - - - - _ _ . _ _ _ - - - - - - - - - - -- - - - - - - - ~ <-

B. Maintain OTSG 1evel Greater than or equal to 30" start-up Q - ~~

range with RCP's on.

C. Maintain OTSG 1evel Greater than or equal to 50% operate range with RCP's off.

2.0 GUIDELINES

~~ ~ ~ ~ ' 2.1 Reactor Coolant Pump (RCP) Restart Criteria RCP(s) may be restarted if the minimum emergency NPSH is available (See Curve 3 Figure 1 or 1A) and greater than or equal to 25oF subcooling margin exists.

2.2 Pressurizer Level Guide If the reactor is not tripped and pressurizer level cannot be maintained greater than or equal to 150 inches, then trip the reactor and initiate HPI.

2.3 Emergency Feedwater (EFW) Actuation Response When EFW actuates respond as follows:

A. Verify EF-P-1, 2A, 28 start.

B. Verify Discharge pressure greater than 1010 psig.

O C. Dispatch an Auxiliary Operatcr (A.0) to EF-V-30A/B. Take

manual control of these valves in the event that emergency i feedwater cannot be established from the Control Room.

NOTE This; A.0 shall perform no other duties until EFW flow to the OTSG(s) has been verified by the Control Room.

D. Verify EFW flow by flow indication if below OTSG 1evel setpoint.

E. Verify EF-Y-30A/B control OTSG(s) level at setpoint.

2.4 Operation of Containment Isolation Valves After Auto Closure A. Containment isolation valves may be opened to obtain samples in accordance with approved procedures. The isolation valves shall be reclosed after the sample is obtained.

B. Other containment isolation valves automatically closed shall remain closed Lntil the following conditions are met.

O 1. Reactor building pressure is less than 2 psig.

2. Containment radiation levels have been assessed based on radiation monitor readings or samples.

4.0 Draft 0

t ,

3. The integrity of the system has been assessed. _ . _ _ _ _ _

~ ~ - - ' - - ~

(Stable surge tank level, visual inspection or pressure test should be considered-to verify N integrity) .

4. The Shift Supervisor or Emergency Director shall give permission to re-open containment isolation valves.

5. Installed radiation monitors or portable monitors shall be available to detect any release that may result from opening the valve.

2.5 Elevated Reactor Building (RB) Temperature / Rapid RCS Depressurization Effects on Instrumentation Elevated Reactor Building temperature can affect fluid density in instrument reference legs and cause pressurizer and 0TSG level indications to be erroneously high.

Instrument reference legs may be locally heated above average containment temperature. DO NOT rely solely on single level readouts.

Rapid RCS depressurization (to 600 psig within several minutes) will cause pressurizer level indication to be erroneously high

__ - . _ . _ _ ____due to off gassing and water ejection from the reference leg.

. Extreme depressurization coupled with high reference leg  ;

temperature can cause reference leg boiling.

O, 2.6 Reactor Coolant System (RCS) Natural Circulation Yerification Verify natural circulation by one or more of the following methods.

NOTE Indication of natural circulation may not stabilize for 15 to 30 minutes.

! 1. RCS Delta T increases to approximately 300F to 500F l (dependent on Decay Heat) and stabilizes and Th is less l than 6000F.

2. Incore thermocouple temperatures stabilize, and are tracking.TH-

3. Cold leg temperatures approach saturation temperature for l secondary side pressure (normally within 5 minutes).

4. Verify heat removal from OTSG's.

a. Steam flow indication.

{-} b. Feed flow indication.

l 5.0 Draft 0

NOTE, p Heat removal and RCS delia T may not be noticeable V for low decay heat case.

2.7 Actions for Failure of the Emergency Feedwater System -

NOTE If EF-P-1 or either motor driven pump have started attempts to start additional pumps may be performed when plant conditions become stable.

A. Failure of EF-P-1 to Start.

1. Verify that MS-V-2A and MS-V-2B are open.

_ _ _ _ . 2. OPEN MS-V-13A and MS-V-13B.

3. If EF-P-1 fails to start go to defeat on all four auto-start-defeat switches and CLOSE MS-V-13A and

_ _ _ _ _ . MS-V-138.

4. Have an auxiliary operator check locally that EF-P-1 overspeed trip is reset and that the Manual Operator O for MS-V-6 is in the open position.

5. Open MS-V-13A and MS-Y-138.

B. Failure of EF-P-2A or EF-P-28 to Start.

1. Verify that there is voltage available at the associated bus.

NOTE With an ES signal present there will be a 20 second delay in pump start.

I

2. Verify that control power is available as indicated by the green indicator light at the control switch.

3. Verify all four auto-start-defeat switches are in defeat. Manually start he pump using the control l switch.

t

! 4. Check locally for targets on relays located at the switchgear and check the 10 amp closing fuses.

i O 5. Use the 69 bypass key and attempt to start the pump locally.

6.0 Draft 0

? . - . . _- -- _ __. . _ _ .- -

l C. Failure of EF-V-30A or EF-V-30B to Open.

O V 1. Check steam generator level to determine whether an open signal is required.

2. Verify that EF-V-30A and EF-V-308 Hand-Auto stations -

are in AUTO.

3. If the valves have failed closed, place the hand-auto station in HAND and attempt to open the valve.

4. If the valves have not opened, switch to the back-up manual loader and attempt to open using the backup manual control station located in the Control Room.

5. If the valves are still not open, have the auxiliary operator establish comunications with Control Room Operator and take local handwheel control of the valves and open them as directed by the Control Room Operator.

D. No Indicated Flow (Low Flow) With Steam Generator Level Below Setpoint.

1. Verify that EFP discharge pressure is higher than steam generator pressure. If not turbine header pressure setpoint may be reduced to get additional fl ow.

2. Verify that the following valves are open:

EF-V-2A EF-Y-30A EF-V-1A EF-Y-2B EF-V-30B EF-V-1B

3. Have auxiliary operator check locally for pump malfunction and correct lineup of manual valves.

2.8 Actions for Low Level Alarms on Condensate Storage Tanks

1. If Condensate Storaga Tanks low level alarms occur as a result of the Condensate Storage Tanks being used to i supply emergency feedwater, continue supplying emergency feedwater from the Condensate Storage Tanks until the water level decreases to the low low level alarm point.

This will leave 67,000 gallons of water in each tank.

2. When level has decreased below the low low level alarm point (about two feet on the indicating range on the Condensate Storage Tanks level gauges) break vacuum per OP 1106-15 (if not already broken). Take suction directly from the condenser hotwell by depressing the emergency alignment control pushbutton located on the control room console and verify C0-V-12 and CO-V-13 open.

Pushing the emergency alignment control pu:;hbutton positions the valves as follows:

7.0 Draft 0

CO-Y Close - prevents air from entering the pump suction line.

O CO-V Close - prevents air from entering the pump suction line.

CO-V Open - permits the pump to take suction directly from the Hotwell.

3. While still supplying the emergency feedwater pump suction (s) from the condenser hotwell, make preparations to supply the EfJ header directly from the Dsmineralized Water Storage Tank (DW-T-2) as follows:

a. Insure closed DW-V-44, DW-V-30, DW-V-33, DW-V-49, DW-Y-46 and DW-V-38.

b. Close or verify closed C0-V-107, C0-V-108, DW-Y-2, CO-Y-24, CO-Y-103A and C0-V-103B (C0-P-3A/B must be secured).

c. Open DW-V-28, DW-V-29, DW-Y-32.

d. Verify open C0-V-13, C0-Y-14A and C0-V-148.

Continue supplying emergency feedwater from the condenser hotwell until the hotwell level reaches 5 feet decreasing as indicated on the hotwell level gauge on the control room console. This will leave 6900 gallons of water in O the hotwell before inadequate suction pressure exists.

4. When the condenser hotwell reaches 5 feet decreasing level as indicated on the hotwell level gauge, complete alignment of DW-T-2 to the EFP header and supply suction water as follows:

a. Open DW-V-35 and DW-V-34.

b. Start DW-P-2 if power is not available for DW-P-2, open DW-V-30 for gravity feed.

c. Close C0-V-12.

d. Close CO-Y-8 using manual handwheel.

NOTE Do not reset the Emergency Alignment Control pushbutton for CO-V-6, 7, 8.

Station an operator to monitor the EFP(s) suction gauge (s) and in communication with the Control Room.

8.0 Draft 0

5. When the EFP's suction pressure gauge (s) read 2.0 psig or if cavitation occurs due to inadequate suction pressure and when

,-s all other sources of Bnergency Feedwater have been exhausted,

(,,/ shift emergency feedwater suction to the Reactor Building River water supply as follows: -

a. Start RR-P-1 A or RR-P-1B (if not already running) to satisfy the opening interlock of EF-V-4 and EF-V-5. s

b. Unlock and close breakers for EF-Y-4 and V5 on 1C-E.S. --

V.C.C.

c. Unlock EF-V-4 and EF-V-5 locally.

d. Open EF-V-4 and EF-V-5.

e. Close C0-V-13. _. . _ _ _ _

f. Close C0-Y-14A and C0-V-148.

~~

NOTE After introduction of- river water, OTSGs may._not_be_. _

used for subsequent heat up without engineering evaluation of OTSG integrity.

2.9 Feeding Dry 0TSG O' l. Feed a dry (less than 18" SU range) OTSG with Main.Feedwater_if __

available.

2. Feedrate not to exceed 0.05 x 106 lbm/hr until OTSG 1evel is restored.

3. If MFW is not available, use EFW (maintain tube to shell Delta T to less than 700F).

l i

O 9.0 Draft 0

TABLE 1 0 _ . _ . _ _ _ _ _ - _ _ . Pressurizer Spray Flow for Various RC Pump Combinations NUMBER OF RC PUMPS RUNNING

- \

_ SPRAY FLOW

. _ .___ _ ._. _ LOOP A LOOP B (% FULL FLOW) 2 2 100 2 1 92 2 0 84 1 (Spray line next to running pump) 2 60 1 (Spray line next to running pump) 1 53

_ _ . _ _ _ . _ _ . .1 (Spray line next to idle pump) 2 50_ __ . _ _ _ _

1 (Spray line next to running pump) 0 41 1 (Spray line next to idle pump) 1 38 1 (Spray line next to idle pump) 0 76 0 2 20 0 1 0

% ,e + wm ,A m.

O maem e.-

9

• 1 O

Orakt O

. -.. _ , , . . ,.-, . . _ . - _ . _ _ . . - . _ . - . . _ _ - . - .- _ --_. .._,_ - ~... _. ,_ ,_ - --_.

FIGURE 1: PTS GUIDANCE RC PRESSURE / TEMPERATURE LIMITS 2500 =i=. =:= ..t= r = == E=1=- mis = 3=i==r= := E .m Zim. . CURVE DESCRIPTIONS

( 00

• ' i?

• 2 iIW NYY 5I? 5 '55 -i V 5!5 is:D~2 *!5 ai-j!!= Mi5- MiFi -

miisi -Mi! lek 'jl=: iii:i Instrument errors included as

.= EjE 5iis E" +1E n ted in parenthesis.

1300 ikii= Eh= ==}5: =M15 2!!M: =Eli ME-  :: .

gi.. :=i; .:.gE ={ii : qEji= g- p = jai i=gui; :i;ji=~ . :;=- --g :' :i=;iE 1. Tech. Spec. 3.1.2 Heatup &

1200 -EEEIW 41 LIE =Y 55E Ni -N M="- 5IU =$5 5!E =- Cooldown Limitations to 5

.= p_.E. :_-ii..t=.=. .i_=.t_E.:. i j.E_i=._. E. .i. =. .=. =. 8 6 . j EFPY (50 psIg, 12oF). Tc -

__Ei,_u.:u..=ii ~ - + E. . i. J. u. . =.i. .i. _E..=_i.t.E. .

2.

Therma 1 Shock Curve (no 1100 IE : a= '

JMMin IEE fi- ='ilif =:5'l 5 = iE!E = =i = El . error included SCM/incore T/C lei:=i ~~:!-Ei "hi Ei2 EiEF 5i5 Sh fi5 5-IPl E!Ili?S hu ifE Emergency NPSH Curve for i 4 in h 3

.E -

= if ih! :: if 2000

2= =#h .

2 RCP Operation; i.e. one s!-si :==E+ .

!55 51.@ Edis :!Ii? ' i!#= ~ i f.: =E!!E F-  := l.. per Icop (94.9 psig, 5.6 F)Tc

iE iE Ei=E =El 4. 25 F Subcooling Margin 1900 lWE i= Hiri E ~

f;i"i. s"h

i k..g 2q. =p . '"= g

• 3 =2 ii-i

'+E-f-L j..f.:g

__.r . - 1 G

.1 Q"n.

i

Z'Z 1:7 . . " :. .

~ 1:_ c:.

~;y 5 (no error inc1uded)TH /Incore T Clad less than 14000F

= l EIE Eb: *.2rz '

I~ ~ !"E='EIE EAE *E GE - d:J t=-

'~

1800 '=i~="~" (no error included)Incore T/C

:-J4iE-i = = =: "5 55E= 5IM: 55-- ='-!!5- i fiht 5NE =i=: -i / . = 6. T C1ad 1ess' than 18000F 1700 W 9;9 Mi= ; ii ii M= ?f: E in  :!/ ::

(n error included)incore T/C

~ ;={-E:!M ~= ME O.Ei -5i5 Ef5 W:EMIE- :/ d-E Ei5 5!55 = - =

1600 T-EiEis O = : Ei=-M Ef5 555 'iEiE" /.!!5 E555 E5!! :=}/_ = EMENTS

= FJ lii!5[i:ih5i M5 $b5:"E ff E!5]if5155"I. :?Ei=: = When indicated RCS pressure is f.

~

1500 F:4+-4W=i- 535E 5

.__~ 2 =:.

W 'iS / M 5I- .=4 =?1 i- less than 500 psig refer to

. . := t . = = u 2; 1m.2.

F:gure 1A.

3.=- -=-=,_: = t-

_ == .i2:= r o : = - } . :-.. . _. - --

- - -= : =.f -- - - - -

J - --

1400 ~EEEEI =E" 5 # N I5d5N =5l -

NOTE: Pressurized Thermal

- ==}=-hsjiiii ":EE:Eii." 2!@ .- unhEi;Eff.i iEj@ . -iji? )_j?[=};i' Shock Requitements PO j

=.E'- 'i. "i- M

= li E 5 i= !E [E f=45 5/ =~  :

555 "=5-I=iij E!=~ =

are only a concern when RCS is less than E'El:F := == Elf E5? Ni:.= 5000 F.

%5f5fE. -5/s#E5E "=i4lE==/

Wit =+: #! 2 : Ei" M~ f I!!'E -!E 52/E= EEE =EE / !Ijf h r i A. Ouring Emergency Conditions i5 ' -ii - l EU =! maintain RCS pressure /

~

=

1100 i ~I' 2' I *

/~i EI E /" 'i -

E

:! iH .U..L- .= E E iE" 2 i j E= EiE- "-- =--- ==  : temperature between curves U. . :;: h;= . . ir-SE E

/ ==$-- $= '/. / .5 E.

[= No. 2 and No. 4 (acceptable Tr b=_h T_h  : r. . '

1000

.= fa g:: , 11 .E f-=:u = ---._ .: operating region for

== .;_: . : = ==: =;g/p.1  :~ . . . .72/ 7=; ; ;.x:

preventing thermai shock) f=!= =i =ia ._ ;g =!j e:. .=.jz = Eft;m=: =E;= =;. f 9ir F= maintaining minimum RC Pump 2:-i.W = - i1 '!i%= - #f:! :; EE " "E/e -GF =: =i5' =d[}:Mn=E Eh . NPSH if applicable.

M N

~ '

800 Er^ -

5I I/ ~ ' Y -Y N 8. Thermal Shock Prevention 3.= .;q ry.y

.c j -The {-E=-

-/n - iL= g:is= -

. Guidance, n.

11 a.a. ..I-i- /.i ,

i=- -R -

1. With RCP's off & HPI on 700 2 -

.- 1

.- p maintain RCS pressure /

i T

_ C_._ . . . . . r: . _r. . . g .l temperature between

.:J .. .

500~

. ._ ._:  :.;..n_._ .L._2.

i

_/

" /.

F W j..~ T

2. During any cooldown main-tain less than 100 F/hr.

./: /  : [.

(1.6 F/ min.)

p

~~

400 __i _+ - / ~/  ::E li either statement No. 1 or iio.

f ._f "3. .

l. i. 2 above is violated, stabilize

>^

/I '

I l[ .

..I the plant and depressurize as 300 necessary to maintain RCS press-

/ '2 -

- - - . Mj_.

ure/ temperature between curves

~

[5 ,6 .

00 i l'~ I I. No. 2 and No. 4. Do not cause

! {O 'I I

..~

d ;. l l-. i . any significant heatup or re-pressurization. If possible

! j j  !

100 l ,

4  ; (i.e. non loca, non OTSG tube 7 _ __. _.j_ _:.__.a .

--- d' - -- +l -rupture), a 3 hr. hold should be i

0 - ' ' ' ' ' maintained at the stabilized 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 condition between curves No. 2 t

l and No. 4 of Fig. I and 1A.

FIGURE 1A: PTS GUIDANCE NARROW RANGE RC PR ESSURE / TEMPERA"URE LIMf"S 500 -. . . . ~ - - - - - -

r p .. .. . .;, CURVE DESCRIPTION

= r r - - r ,--- . _. . . .. . t: E= j  :

..e..._..,1 -r -----

n--J :_ -r-- r r 9480 E

I= 'I -

~ ~

' W --'"~t-

• ~

! 2 EEE=/K :iEEEE Instrument errors included as *

= _ur - + _--

2. . n _. : . . _ . d noted in parenthesis.

1..__. _

.__4_.. . . _ _ . . . . _2- l -- =: r t =.... . =._

gg) 7 Err -i=ll" :=isbE_ .I. :25=.5}s? lidiE F .!"5{~Efi 1. Tech. Spec. 3.1.2 Heatup 5 h f i-" "~'"r'!!!!"~5hni=--55[EIE!!5ii i}#"!5515/5! . iiE(=iggi Cooldown limitations to 5

~E' SrDi DFEE5h . . __**~= . . _ _ .. .; .. m _ J--T :i!EEIElE/:li eel ['4 El=g: EFPY. (25 psig, 120F). Tc .

440 _

, _;n= , - - = a_; .r 2. Thermal Shock Curve (no error

~3 4 " - - ~3 ~~=

~

~-]>'EE l EU~  ::... :jzzi inc1uded) .' SCM/Incore T/C 1 ""~~ T~~.zEE~. .!. = .. :.:S: ="~i-":-- Jzz

=2._... "-' ~EI=:~r 420 *d- ;U""~Et =E C~Z 3. Emergency NPSH Curve for 2 Il =IM"!!iti=Ehldi!MMEEi=iilE .i Eij3 /.bi . /4-  : L_!]Ms!!E RCP operation, i.e. one pump '

y =:= h,5;=4:; E=j= IF/!i ~f!E~ i? per loop (94.9 psig. 5.60F) .T'c 4 - . .

400 7 LiElE*/-i! N /ij!EEEijE s 4. 250F Subcooling Margin (no

. ._- P i:'..4iMEEEIE- . . . . . . _ . . gg M :sssElE=E5f=_=i=il5

..._...p...4 . . . .

error included) . Tg/Incore T/C

-- - -~~~~--- - ~ --~ ggg j gg=f j-.gggg= 3g .

380

--..;..  ;:......g-.n. g g==;== n u== g u= =l: a --

r

./= 5E= >l .; a. -= :=.. -.-~.:. - = ...- -

f a. .n i.. .

REQUIREMENTS 360 'T 5IT=FiEEE ==~iiE4E4 /iM/;i=h:g :.EIEEEiEEEI I

- - -a = .. .,n . =:.=,f u=,.r=y;=--- rt=====9, r=. =. ,l v When indicated RCS pressure is

. - =

./m=.-J m=2e =mi=="

=-

q._;:g 2 :=r=;._ ,=.{-- -'---- 3:3;= -- - f jag 3 ;=:====ju g=-. greater than 500 psig refer to f 3=

340 - - - - - - - -- - - - - + - - - - - - - - - - -

Fig. 1.

E.i=i= . 'rd===E.!" T= I "_ ~Z.l""."/="@/j=T-Eli/555E555215555 .

320 =

E 5* ' *

~ ~

NOTE: Pressurized Thermal i !- # ri ;E=. f.r-~t=I-i=.. ......:. iyE.. .. . .E c. s.=. Er =m.. n r . / . . _=_.ff =._=--run .

.. n==: Shock Requ.irements are 300 IE UI i'i- EO=rE=E==k _Jr# iiG LEE / E==-JEE~ HEE =- only a concern when ljh:- ,. - -iriE;l==g5j:.._ L_._:t== _ :j-_lj:-M; {-- - TMEjjijt RCS is less than 5000F.

--3 2

......P -=_v=..__.f'E =: .iE EUUEiEl55 .E E. __ St=" d E== ~EE,EEE:_

. . . _ . A. During Emergency Conditions 280 _

4 _i.. g{'===iigE=EEW/f_. 5=i;Ej.ggf.ij&g5}E;i.ing.1;: maintain RCS pressure /

- - : - - py .. . _ q _; = 7. _.__.__.___,f. __;__7__g=g ;gu_.g ;--- r-- . _

temperature between curves v ._2. a=u. :1.=-- - ---

g.._ _. =.-. q_ ..p= j =. .;=. .gg=. ;=. ==. g=..g - No. 2 and No. 4 (acceptabie

~ ~ ~

E== Perat.ing region or 240

' l / ' ' -" T.'Z .? - '

preventing thermal shock) 8 4: _= f.. f =. T .. Y'-E E i' EEE i" maintaining E E !" E E I" RC: =Pump j2

• 4E=: Ei=  ::EE=E9f/.==EE:E!'! ==! minimum r- -- =r g - - -_ _ , _ _ 3. . . _ f . ._; .. . _ _: . . . . . . . . . . . .

220 - - - - - - - -

NPSH if app 1icable.

'~~

= ". . . _ Z _. .~ rEEZC"-~1. =f=: :=p~=~ " dE= Z - _" - _"_  : 7E=i

. . . .Z E =i= .~._22.._. ==i="-- B.

-r---- _

Thermai Shock Prevention 200 ._ ' M E!'i"E=i*~~ F " "E" ~

'* ' Guidance.

i ':!!

lE55!I_El55hEEi I /.!= Ili?-!Ei4=E"ia tr 1. With RCP's off & HPI on j-- ' @ ==5; :B f E E /W ^~'!i:ini-fi;ij maintain RCS pressure / ..

180 - -

-

• uiS[55EddjiEj : I. . Eii4E :_ . temperature between -

160 ' " - I- iIII:li II -- - - ~- " 'i='" ' =; f- :-- curves No. 2 & No. 4.

- S N 2 E-E_==r--=_---2.  ;;_= m .= _; A"S. t  : 2. During any cooldown main-

.f.._f M -~~~ZZ" _.i_=d="- E f= ? ~ tain Iess than 100 F/hr.

140 _

7"8 D'EEEEiF"- F-EUE E *E ~~I===" ~

(1.6 F/ min.)

. 5"iUMEE55555= A=55E~2= i:EEI=E"= T - If either statement No. 1 or No

- - r m----  : qrp r r- - - -

2 above is violated, stabilize 120 " -

.:J:j = . ;_ .- the plant and depressurize as p::=.p-3:Ey =;j :y_;jpru

. :: =_ .__ : .. ..:=_=....._.a...-'

necessary to maintain RCS press .

100 - - - - - -

ure/ temperature between curves .-

'"E;i/=:====22

_- i = 1- .- ==

No. 2 and No. 4. Do not cause 80 SMIE - " ~

g gn = a q := . I '.: N

. . _ _ _ any significant heatup or re-

_. .=-: .

=. p 2- ~ "= pressurization. If possible 60 ~ ~ ~

~ ~~ . . . . . . . . _ _ _ . -_b. - - - - ~ - -. -._ - -__ - :: ;_;= r_ 2 = _;= =_. = u. . . =

(i.e. non loca, non OTSG tube x .:-: -. - - - - - -. _ E = =: ai-:=.iEEEE .= .T 2. =_ =. : : uz. :-En rupture), a 3 hr. hold should be 2_.

- :- - ;_ _ 7--- - - - - - -- - -- ~ Z maintained at the stabilized  ;

() ---- . ._.._.f_..._.

' ' " ~

condition between curves No. 2

- .._._ a--

y n= == = == : =:- - r- .-==:

and No. 4 of Fig. I and 1A.

20  :

._ . a . ai =_ 2 : -i:- =E

- = s . . =_ . _ . . ._ _ . : _ _ 2 = ..=. _u .

0 = ' '-" D 'i- i ' ' ' '

130 160 190 220 250 260 310 340 370 400 430 460 490 0M0RATM RC TMFMRfyA1hg r w m._ m _ n _f e

1 ATTACHMENT 2 PROGRAM: ATOG TRAINING UNIT ~ l WEEK OF TO MdNDAY TUESDAY WEDNESDAY THURSDAY FRIDAY l'10-1 2 Rx Trip 1210-2 Loss of 1210-3 Excessive 1210-8 RCS Super- 1210-5 OTSG Tube Subcooling Margin Cooling heated Rupture l'210-10 Abnormal 1210-6 Small Break 1210-4 Lack of Heat 1210-9 HPI Cooling /

Transient Rules, LOCA Transfer Recovery from Solid Guides & Graphs Operations Prioritization of 1210-7 Large Mass / Energy for HPI Cooling Methods Break LOCA Cooling Simulator: Simula tor: Simulator: ,

Simulator: Simulator:

Unannounced Unannounced Unannounced Unannounced Casualties & LER Casualties & LER Unannounced Drills Casualties Casualties Casualties Drills r

CLASSROOM: 0800 - 1130 SIMULATOR: 1200 - 1600 m