Text

Forwards Final Procedures 2-ST-8,2-ST-11,2-ST-6 & 2-ST-9 for Special (Low Power) Test Program,Incorporating Westinghouse & NSSS Vendor Comments.Also Forwards Variation of Tests 2 & 7
	ML19312E829
Person / Time
Site:	North Anna
Issue date:	06/13/1980
From:	Sylvia B; Virginia Power (Virginia Electric & Power Co)
To:	Harold Denton, Youngblood B; Office of Nuclear Reactor Regulation
Shared Package
ML19312E830	List: ML19312E829; ML19312E836; ML19312E840;
References
	528, NUDOCS 8006170611
	Download: ML19312E829 (3)
	v • d • e

. l,...

VruorxrA ELECTIHC AND Powen COMPANY R acitwoxn,V23tonw xA 2026t June 13, 1980 Mr. Harold R. Denton, Director Serial No. 528 Office of Nuclear Reactor Regulat.!on N0/ERS/GAK:ms Attn:

Mr. B. Joe Youngblood, Chief Docket No. 50-339 Licensing Branch No. 1 License No. NPF-7 Division of Licensing U. S. Nuclear Regulatory Commission Washington, D. C.

20555 SPECIAL (LOW POWER) TESTS NORTH ANNA UNIT 2

Dear Mr. Denton:

During April, 1980, we forwarded our first draf t of procedures to you for the Special (Low Powe r) Test Program at North Anna Powe r Station (Unit 2).

On May 14, 1980, we met with members of your staff concerning this program.

During the meeting we provided a revised set of procedures for your review.

We have since received comments from Westinghouse, our NSSS vendor.

Appropri-ate comments have been incorporated into the applicable test procedures.

We are enclosing our final version of those procedures.

Also, we have included an attachment which describes our variation of Tests 2 and 7.

We will be forwarding an Operating License Amendmen t request which will provide a Sa fe ty Evaluation for the test program.

Should you need further information, please contact us.

Very truly yours, J/ /

fu

.f s-B. R.

Sylvia Manager-Nuclear Operations and Maintenance Attachment cc:

Mr. James P. O'Reilly 8006170'l 6 //

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Attachment Pagn 1 Information regarding the differences between the North Anna test proce-dures and the Sequoyah test procedures for natural circulation with loss of power is provided below as requested by members of your staff in a meeting on May 14, 1980.

The Sequoyah Tests 2 and 7 (loss of offsite power and loss of onsite/

offsite power) have been combined into one procedure for North Anna Unit 2.

The purpose of Tes t 2 is to demonstrate that decay heat can be removed via the steam generators by maintaining steam generator levels with the auxiliary feedwater systen under simulated conditions of loss of offsite powe r.

The purpose of Test 7 is the same as Test 2 except that there will be a loss of all AC (simulated) and steam generator levels will be maintained with the steam driven auxiliary feedwa te r pump.

Due to the nature of these two tests, they can be combined into one procedure with Test 2 leading into Test 7 with greater safety and improved operator training.

The following is a listing of the advant-ages of combining the two tests and performing them as proposed.

Test 2 will be discussed first and then Test 7.

Test No. 2 Natural Circulation - Loss of Offsite Power 1.

If auxiliary feedwater valves were lef t open and auxiliary feedwater was initiated as in a loss of power event, the injection of feedwater in the steam generators would cause a rapid drop in RCS temperature and pressure.

This is an undesirable condition with a critical reactor and would not be of any benefit in accomplishing the goal of the test.

The auxiliary feedwater control valves will be shut just prior to stop-ping all reactor coolant pumps and the running main fee 2ter pump.

Then the auxiliary feedwater control valves will be throt tied to main-tain steam generator levels.

2.

The North Anna auxiliary feedwater pump normal lineup configuration is one-on-one, meaning each steam generator has a dedicated auxiliary fe edwa te r pump.

This makes steam generator leve ls more dif ficult to control, thus increasing the possibility of perturbations on the primary syatem.

The procedure as written will allow bet ter cont rol of steam generator levels.

3.

A cooldown would af fect the ladication from.the> nuclea r ins..rumenta-tion system, which Ls undestrable.

Therefore, maintaining T(COLD) rela-tively constant is important.

The added control of the auxiliary feed-water additions will improve the operators ability to maintain a constant T(COLD).

4.

Significant ope rato r attention will be necessary to maintain the reactor critical at one percent powe r during the test.

Additional operator attention to diesel operation and a less controllable fe*2 te r system is not necessary to demonstrate the purpose of this test.

)

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Attrchment PJ.g3 2 5.

North Anna Preoperational Tests 2-P0-69 and 2-PO-70 are diesel tests. These tests demonstrate the ability of the diesels starting, coming up to speed and voltage, and sequentially loading on bus under-voltage and safety injection.

Repeating these tests in the natural circulation procedure is redundant and is not necessary to meet the purpose of the natural circulation test.

6.

North Anna Start-Up Test Procedure 2-SU-38, Station Blackout Test, demonstrates that the emergency diesels will start and the eme rgency buses will supply power to safety related equipment to bring the plant to and maintain hot standby conditions subsequent to loss of. normal station power at equal to or greater than ten percent generator power.

It is not necessary to repeat this test as a natural circulation proce-dure to meet the purpose of the natural circulation test.

Test No. 7 Natural Circulation - Loss of Onsite/Offsite Power 1.

Normal auxiliary feed lineup is one-on-one.

Thus, this test requir-es realignment of the auxiliary feed train.

By combining this test with Test No.

2, this sequence is initiated by tripping the motor driven auxiliary feed pumps and then realigning valves to provide feed flow to the three steam generators by use of the steam driven auxiliary feed pump.

Operators will be gaining experience in controlling steam genera-tor levels by manually positioning valves in the auxiliary feedwa ter pumphouse. This realignment and feeding of all three steam generator is required to maintain steam generator levels since steam is being drawn from all three steam generators to drive the turbine-driven auxiliary feed pump.

2.

Due to the more stable control of the plant and deleting the requirement for station battery drain, the procedure eliminates the time restraints on this test.

By removing the time restraints, it allows more freedom to gain additional operator experience at various operator work stations duiing the conduct of this test.

3.

As stated in the NRC Safety Evaluation heport (NUREC-0053) 'for North Anna Unit 2, the Natural Circulation Test should not pose an undue risk to the public or risk damage to the nuclear plant.

By maintaining the emergency bus available, safety is enhanced and it does not undermine the pu rpose of the natural circulation procedure.

A simulated loss of the emergency bus will be provided by the procedure.

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-ST-8 VIRGINIA ELECTRIC'AND' POW.R_C,QMEANY--

Date:

06-12-80 Page 1 of SPECIAL TEST PROCEDURE FOR NORTH ANNA POWER STATION UNIT #

2 1

TITLE:

NATURAL CIRCULATION VERIFICATION i

l t

Prepared By:

G.

A.

KANN Date:

06-12-8C Engineering Reccamended Approval:

Date:

d-//-fC STATION NUCLEAR SAFETY AND OPERATING COMMITTEE REVIEW OF PROCEDURE:

l Unreviewed Safety Question:

es ONo Disposition:

Approved Disa prov OAPProved as Modified Chairman's Signr.ture:

/

Date:

/7 /b (f

I SYSTEM NUCLEAR SAFETY AND OPERATING. COMMITTEE REVIEW OF PROCEDURE:

NOTE:

Review not required unless an unreviewed safety question is involved as determined above.

Disposition:

OAPProved Disapproved Approved as Modified Chairman's Signature:

Date:

VERIFICATION OF NRC APPROVAL:

6 1

Aparoved O Not Required Station Manager's Signature:

Date:

TEST RE5'JLTS REVIEW.D BY ENGINEERING:

Date:

TEST RESULTS REVIEWED BY STATION NUCLEAR SAFETY AVD CPERATING COMMITTEE:

NUT A CONTRO'. LED Chairman's Sienature:

Ocvmoem Date:

Comments:

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s TEST RESULTS (Use accitional :: ages as necced) page 2 of DISCREPANCl!$ (Lis by numcer):

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RESCLUTION OF 3iSCRE?ANCIES (LIS* hv numcer :=rrescendinc to accve):

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4 CHRCN0 LOGICAL LOG (Use acd'l ; mages as needec)

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2-ST-8 Page 1 of 13 06-12-80 VIRGINIA ELECTRIC AND POWER COMPA_NY NORTH ANNA POWER STATION UNIT NO. 2 NATURAL CIRCULATION VERIFICATION

References:

1.

Precautions, Limitation and Setpoints for Westinghouse NSSS system 2.

Technical Specifications, North Anna Unit #2 3.

WCAP-8747: North Anna Nuclear Design Report 4.

North Anna Station Curve Book 5.

2-OP-5.2 6.

2-0P-30 7.

2-0P-31 8.

1 EP-2 9.

ASME Steam Tables

2-ST-8 Page 2 of 13 06-12-80 1.0 Purpose 1.1 To demonstrate natural circulation when RCPs are tripped.

1.2 Demonstrate the capability to revove decay heat with natural circulation.

1.3 Demonstrate that steam generator pressure and feedwater flow can be controlled under conditions of natural circulation to maintain adequate cooling of the reactor coolant system.

1.4 Demonstrate the ability to maintain natural circulation and saturation margin with the loss of pressurizer heaters.

1.5 Determine RCS depressurization rate after pressurizer heaters are tripped while in natural circulation.

1.6 Determine whether saturation margin can be increased by increasing charging flow, while in natural circulation.

1.7 Determine the capability of the saturation meters to indicate the saturation margin, while in natural circulation.

1.8 Demonstrate the effects of charging and secondary steam flows on the control of the saturation margin at low saturation margins, while in natural circulation.

1.9 To provide operations personnel with experience in unit operations under natural circulation conditions.

t

2-ST-8 Page 3 of 13 06-12-80 Initials 2.0 Initial Conditions 2.1 The reactor is critical in manual rod control at 3 percent power.

Bank D is in bank select.

2.2 All three reactor coolant pumps are in operation.

2.3 Pressurizer pressure and level control are in automatic main-taining RCS pressure at approximately 2235 psig and pressurizer level at approximately 22 percent.

2.4 Steam dump valves are in the pressure control mode maintaining steam generator pressure at approximately 1005 psig and RCS T COLD temperature at approximately 547 F.

2.5 Steam generator level is being maintained at approximately 33 percent on narrow range in one of the following modes; 2.5.1 Main feedwater system in automatic on the bypass valves.

2.5.2 If main feedwater pump operation cannot be maintained under these conditions, the auxiliary feedwater system is in service in accordance with 2-0P-31.2.

2.6 Stutdown banks are fully withdrawn and control banks are above i

their insertion limits.

Control bank D is near 160 steps; this is to establish a zero moderator temperature coefficient.

2.7 Excess letdown is available for service; however, do not use unless absolutely necessary.

2.8 The CVCS is in a normal at-power makeup and letdown configuration.

2.9 Temporary instrumentation is installed in accordance with Attach-ment 6.3.

NOTE:

Record the following on each strip chart:

a.)

Test Number b.)

Recorder QA Number

O 2-ST-8 Page 4 of 13 06-12-80 Initials 2.0 Icitial Conditions (cont.)

c.)

Time and Date d.)

Chart Speed e.)

Scale Used f.)

Test Point g.)

Parameters 2.10 The computer trend printer is set up to monitor the parameters indicated in Attachment 6.4.

2.11 The analog trend recorder on the main control board is set up to monitor the hottest incore T/C in each quadrant, as determined by the P-250 incore thermocouple map.

Saturation margin, computer point UO969, is monitored on the digital display.

2.12 All test equipment to be used in the performance of this test is operational and in calibration, and has been recorded on the TEST EQUIPMENT DATA SHEET (Attachment 6.1.)

2.13 Immediately prior to the perpermance of this test, the Test Engineer

.e:

has reviewed the latest revisions of the applicable references in order to improve his familiarity with this procedure and insure i

that it is still valid for the test, i.e., changes to the system, equipment, or component since the procedtre was approved will not affect its performance.

2.14 The Shift Supervisor on duty has been notified of the impending

)

test and will coordinate its perfcrmance.

2.15 Engineered Safety Features and Reactor Protection Modifications have been made in accordance with Attachment 6.6.

2.16 Motor operated feedwater isolation valves MOV-FW-254A, B, and C and main feedwater control valves FCV-2478, 2488, and 2498 are shut.

2-ST-8 Page 5 of 13 06-12-80 Initials 3.0 Precautions 3.1 Refer to Operational Safety Criteria in Attachment 6.7.

3.2 Do not exceed 5 percent thermal power at any time while the test is in progress.

3.3 Ensure seal flow to each reactor coolant pump is maintained between 7-11 during the test, and adjust as necessary at least every

~

100 p change in RCS pressure (2-0P-5.2).

3.4 The Operational Safety Criteria is prominently displayed in the Main Control Room.

3.5 Avoid rapid or sudden changes in steam pressure and feedwater flow to prevent rapid cooling of the reactor coolant.

3.6 Af ter the reactor coolant pumps are tripped, the normal delta T and T indications will become unreliable. Delta T and T AVG AVG shall be calculated by taking the difference and the average of the hot and cold leg wide range temperatura indications respec-tively.

3.7 Maintain T at approximately the pre-RCP trip temperature to COLD maintain accurate NIS power level monitoring.

3.8 Do not exceed primary to secondary differential pressure at 1600 psi.

3.9 Maintain less than 100 psi differential pressure between any two steam lines and greater than 600 psi in each steam generator.

3.10 Note possible effects of polarity changes in moderator temperature coefficient as temperature changes.

2-ST-8 Page 6 of 13 06-12-80 Initials 3.0 Precautions (cont.)

3.11 The pressurizer temperature shall be limited to a normal maximum heatup or cooldown of 90'F in any one hour period, with a maximum spray water temperature to pressurizer temperature differential of 320*F.

3.12 Do not borate under natural circulation conditions while the reactor is critical.

3.13 Pressurizer spray should be initiated slowly to minimize thermal stress and maintain continuous flow for uniform chemistry unless otherwise directed. Auxiliary spray must be isolated if letdown is isolated.

3.14 The reactor coolant system (except the pressurizer) temperature and pressure shall be limited in accordance with the limit lines shown on figures 3.4-2 and 3.4-3 of the technical specifications during heatup or cooldown, with a maximum heatup or cooldown, of 50 F in any one hour period.

3.15 Anytime speed is changed on any recorder, initial, date, time and speed should be listed on the recorder.

3.16 Should a reactor trip occur during natural circulation, close spray valves (PCV-2455A & 3) and restart reactor coolant pump 2-RC-P-1C prior to closing the reactor trip breakers.

3.17 Maintain D Bank at > 100 steps during the conduct of this test.

Should this limit be reached, insert coutrol Bank D to zero steps and restart RCPs per instructions in this procedure.

Contact reactor engineer for further instructions.

2-ST-8 Page 7 of 13 06-12-80 Inttials 4.0 Instructions 4.1 Record the time on the data recorder charts in the instrument rack room and start the recorders at 125 mm/ min.

4.2 Begin recording on the reactivity computer.

4.3 Prepare the plant computer to record data as specified in Attachment 6.4.

Record the initial steady state values as specified in.2.

4.4 Place the pressurizer level controller LC 2459B in manual. Adj ust,

if necessary, to match letdown to maintain constant pressurizer level prior to tripping the RC pumps.

CAUTION: Continously monitor main steam line pressures and care-fully control feedwater addition during the transient to insure that differential pressure between any two steam lines does not exceed 100 psid.

NOTE:

Steam gcuerator pressure, level and flow conditions should be held as close as possible to stable conditions as natural circulation develops. Reactor coolant system cold leg temperatures should be maintained within 5 F of 547 F.

NOTE:

At the initiation of natural circulation (RCP trip), the following system response is expected:

a) Wide range T

- increase (26 to 45*F at s 3 H

percencpower3t b) Wide range T

- slight increase or constant Cold c) Core exit thermocouple - increase (26 to 45'F at 3 percent power)

S d) Pressurizer level - increase (10 to 16 percent at 3 percent power)

S e) Pressurizer pressure - increase CAUTION,: Following reactor coolant pump trip, T and delta T indication will be unreliable.

AVE CAUTION: Af ter tripping RC pumps, tl:e RCS pressure is expected to increase as much as 50 psi depending on power level of the core. Be prepared to use auxiliary spray to control pressure as stated in Steps 4.6 and 4.7 below.

2-ST-8 Page 8 of 13 06-12-80 Initials 4.0 Instructions (cont.)

4.5 Simultaneously trip all three reactor coolant pumps in accor-dance with 2-0P-5.2.

Place spray valve controllers PC-2444G and PC-2444H in manual and then open valves PCV-2455 A and B.

4.6 If RCS pressure exceeds 2285 PSIG, open auxiliary spray valve HCV-2311. Maintain regenerative heat exchanger charging outlet temperature (TI-2123) above 350*F or confirm that the 320'F temperature differential of precaution 3.11 can be maintained.

4.7 If RCS pressure exceeds 2310 PSIG, close charging line valve HCV-2310 and manually throttle spray valves PCV-2455A and B, as required to m intain RCS pressure below 2310 psig.

CAUTION: Once auxiliary spray is initiated to limit RCS pressure, insure that a minumum continuous auxiliary spray flow is maintained to the pressurizer by turning on one bank of backup pressurizer heaters and adjusting the position of PCV-2455 A and B to maintain the RCS pressure at approxi-mately 2235 psig.

4.8 Maintain RCP seal injection at 7-11 GPM to each pump.

4.9 Maintain charging flow to match letdown in order to maintain a constant RCS water mass.

(Maintain pressurize-Ic rel -:ppre::1-mately constant after equilibrium has been reached on natural circulation by manually adjusting charging flow.)

NOTE:

Allow the pressurizer level to increase when the average RCS temperature increases (Expected increase is approxi-mately 3/4 percent per *F increase in average RCS tempera-ture).

4.10 Carefully control additions of feedwater to the steam generators to maintain levels at approximately 33 percent.

NOTE:

After tripping RC pumps, the SG 1evels may shrink slightly and then swell as natural circulation develops.

4.11 If required, adjust the pressure setpoint on steam dump pressure controller PC-2464 B to maintain RCS cold leg temperatures within 5'F of 547 F.

2-ST-8 Page 9 of 13 06-12-80

-Initials 4.0 Instructions (cont.)

NOTE:

Natural circulation flow will be stable (within approxi-mately 10 to 20 minutes) when:

a) Delta T between wide range T and T is constant b) Delta T between wide range Y andEdfeexit temperatureasindicatedbythold e core exit T/Cs is constant c) Wide range T is approximately equal to core exit T/Caverageke$perature(SeeAttachment6.8) 4.12 After natural circulation steady state conditions have been reached mark each recorder. Continue recording data for a minimum of 30 minutes.

l NOTE:

Once equilibrium has been established adjust trend printer printout intervals as specified by the Test Engineer.

l 4.13 Complete Attachment 6.10 Auxiliary Spray Test.

NOTE:

Can be done in conjunction with Step 4.12.

4.14 The recorder speed may be changed at the direction of the Test Engineer.

4.15 Record the data indicated on Attachment 6.12.

NOTE:

Test engineer will determine intervals for taking data.

4.16 Shut off pressurizer heater groups 1, 2, 3, 4 and 5 by moving handswitch to "Stop - Pull to Lock" and mark each recorder.

4.17 Stop pressurizer spray by opening PCV-2455A and B.

NOTE:

The following steps will allow the pressurizer to cool and slowly decrease system pressure. The purpose is to determine the time that saturation margin can be maintained without the use of pressurizer heaters and then verify the margin can be reestablished through charging or sec~ndary steam flow.

4.18 Complete Attachment 6.11 depressurization rate.

2-ST-8 Page 10 of 13 06-12-80 Initials 4.0 Instructions (cont.)

NOTE:

The primary system pressure will now be monitored to determine the rate of depressurization. The saturation margin should be monitored closely.

Increase RCS charging flow when the saturation margin approaches 20*F or as specified by Test Engineer. Slowly increase steam dump flow when RCS pressure indicated an increasing trend.

CAUTION: Excessive steam flow could cause a large decrease in RCS pressure.

4.19 As Reactor Coolant System pressure decreases, reduce seal injectin HCV-2186, to maintain reactor coolant pump seal water flow at 7-11 GPM (not to exceed 30 gpm total flow).

4.20 When RCS pressure decreases to 2000 psig verify the P-11 per-missive, close PORV block valves (MOV-2535 and 2536) and block the automatic low pressurizer pressure safety injection signal.

4.21 Once it is determined by the Test Engineer that sufficient data has been recorded to determine a depressurization rate, mark the recorders.

4.22 At this time set up conditions for low pressure natural circu-lation test.

4.22.1 Decrease RCS pressure slowly to between 20-30 F sat-uration margin using auxiliary spray, if necessary.

NOTE:

Do not go below 20*F saturation margin.

4.22.2 Once it is determined by the test engineer that RCS pressure and saturation margin conditions meet the intent of this test, establish an increasing RCS pressure by increasing charging flow. Then slowly increase steam dump flow to increase saturation margin by 10*F.

CAUTION: Excessive steam flow could cause a large decrease in RCS pressure.

2-ST-8 Page 11 of 13 06-12-30 Initials 4.0 Instructions (cont.)

4.23 Once control of saturation margin using charging has been demonstrated or if it cannot be increased in above mode, turn pressurizer heaters on and place heater control in automatic with a setpoint of 2235 psig.

4.23.1 When RCS pressure increases above 1990 psig, open PORV block valves MOV-2535 and 2536.

4.23.2 Verify Safety injection block is removed at 1990 psig.

s 4.24 Place steam dump contral in automatic with setpoint s 1005 psig.

4.25 Insert control bank D to zero steps.

1' 4.26 If auxiliary spray is being used to control pressurizer pressure, open normal charging HCV-2310 and shut auxiliary spray valve HCV-2311.

4.27 Place pressurizer spray controllers in manual / closed prior to starting the first reactor coolant pump.

4.28 When T

-T 5 5*F restart coolant pump "C" in accordance with h

C 2-0P-5.2.

Continue to collect data through the restart.

4.29 After steady state conditions have been reached, restart reactor i

coolant pump A in accordance with 2-0P-5.2.

Continue to collect 4

data through the restart.

4.30 After steady state conditions have been reached, restart reactor coolant pump B in accordance with 2-0P-5.2.

Continue to collect data through the restart.

4.31 Stop the recorders and trend printers.

4.32 Return pressurizer level and pressure to normal and place controls in automatic.

3

2-ST-8 Page 12 of 13 06-12-80 Initials 4.0 Instrnetions (cont.)

4.33 Remove ESF and RTF actuation blocks in accordance with.6, unless the next test to be performed requires this modification then disregard this step, place N/A in the signature line and initial.

NOTE:

Re-Instate all safety functions if a delay of testing of 4

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or more is anticipated.

4.34 Notify Shift Supervisor that the test is completed.

4.35 Using 1967 ASME steam tables, determine the saturation margin using the pressure and temp (rature recorded in 6.12 and plot these values along with the saturation margins taken from the saturation meter vs time and attach to this procedure.

4.36 An evaluation of the accuracy of the saturation meter should be l

done at this time.

4.37 Keep the printouts and charts from the recorders and trend

]

printer with this procedure and remove the recorders if this i

]

concludes the natural circulation testiag.

I l

Completed By:

Time /Date:

I I

2-ST-8 Page 13 of 13 06-12-80 Initials 5.0 Acceptance Criteria 5.1 Natural circulation is established.

5.2 Saturation margin is maintained without reactor coolant pump flow.

5.3 Saturation margin is maintained without pressurizer heaters and reactor coolant pump flow.

5.4 Saturation meters indicate a saturation margin within 1.0 degree Fahrenheit of the margin as determined from the steam tables.

5.5 RCS depressurization rate with a loss of pressurizer heaters is determined.

5.6 Effects of charging and steam flows on saturation margins are deterelaed.

6.0 Attachments 6.1 Test Equipment Data Sheet 6.2 Initial Conditions 6.3 Temporary Recorders 6.4 Process Computer Trend Blocks 6.5 Core Power Determination 6.6 Engineered Safety Features and Reactor Protection Modifications 6.7 Operational Safety Criteria 6.8 Core AT with Natural Circulation Estimated Range 6.9 Training Log 6.10 Auxiliary Spray Test i

6.11 Depressurization Rate 6.12 Saturation Margin l

l

2-ST-8.1 Page 1 of 1 4

06-12-80 TEST EQUIPMENT DATA SHEET TEST EQUIPMENT DESCRIPTION

MODEL NUMBER VEPC0 QA NUMBER l

d i

1

(

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t J

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I

NOTE: This applies only to temporarily installed test equipment or instrumentation.

Permanent instrumentation which is part of the system and shown on drawings should not be included.

Completed By:

Date:

4

2-ST-8

-.2 Page 1 of 3 06-12-80 INITIAL CONDITIONS Pressurizer Pressure psig PR-2444 Red Pen Pressurizer Level LR-2459 Red Pen RCS Loop 1 Hot Leg Temperature

F TR-2413 Red Pen RCS Loop 1 Cold Leg Temperature

F TR-2410 Red Pen RCS Loop 2 Hot Leg Temperature

F TR-2423 Green Pen RCS Loop 2 Cold Leg Temperature F

TR-2420 Green Pen RCS Loop 3 Hot Leg Temperature F

TR-2433 Blue Pen RCS Loop 3 Cold Leg Temperature

F TR-2430 Blue Pen Steam Generator 1 Level (NR)

(LI-2474)

Steam Generator 2 Level (NR)

(LI-2484)

Steam Generator 3 Level (NR)

(LI-2494)

Steam Generator 1 Level (WR)

LR-2477 Pen 1 Red Pen i

Steam Generator 2 Level (kR)

LR-2477 Pen 2 Green Pen i

l Steam Generator 3 Level (WR)

LR-2477 Pen 3 Blue Pen

,. ~,..

2-ST-8.2 Page 2 of 3 06-12-80 INITIAL CONDITIONS Steam Generator 1 Pressure psig Pf-2474 St, tam Generator 2 Pressure psig PI-2484 Steam Generator 3 Pressure psig PI-2494 4

6 l

Steam Generator 1 Feedwater Flow X10 #/hr (FI-2476)

I 0

Steam Generator 2 Feedwater Flow X10 #/hr (FI-2486) 6 Steam Generator 3 Feedwater Flow X10 #/hr (FI-2496) i 6

Steam Generator 1 Steam Flow X10 lbs/hr (FI-2474) l 6

Steam Generator 2 Steam Flow X10 lbs/hr (FI-2484) 6 Steam Generator 3 Steam Flow X10 lbs/hr (FI-2494) i Loop 1 Tavg protection

F (TI-2412D)

Loop 2 Tavg protection

F l

(TI-2422D)

Loop 3 Tavg protection F

.(TI-2432D) l

- =,-.

2-ST-8.2 Page 3 of 3 06-12-80

'tTIAL CONDITIONS Loop 1 AT protection (TI-2412A)

Loop 2 AT protection (TI-2422A) i Loop 3 AT protection l

(TI-2423A)

NIS Channel N-41 NIS Channel N-42 I

NIS Channel N-43 i

NIS Channel N-44 Attach a copy of the computer printout of the Incore Thermocouple Temperature map.

Temperature in Turbine - Drive Aux Feed

F Pump Room Control Room Temperature

F Outside Temperatue

F Completed By:

Date:

)

i

2-ST-2

.3 Page 1 of 2 06-12-80 1

TEMPORARY RECORDERS Connect temporary strip-chart recorders as indicated below.

6.3.1 Reactivity-Computer Recorder a.

Flux b.

Average wide range TCOLD b.

Average wide range TH0T d.

Reactivity Set the chart speed on the following records to 125 mm/ min.

6.3.2 Strip-Chart Recorder No. 1 Channel Connection Monitoring FP-414B, C1-432 RCS Flow, Loop 1 1

2 FP-424B, C1-433 RCS Flow, Loop 2 3

FP-434B, C1-434 RCS Flow, Locp 3 4

FP-455B, C1-427 Pressurizer Pressure 5

FP-459B, C1-442 Pressurizer Level 6.3.3 Strip Chart Recorder No. 2 Channel Connection Monitoring 1

PP-474B, C2-433 S/G No. 1 Pressure 2

LP-474B, C1-429 S/G No. 1 Level 3

FP-474B, C3-741 S/G No. I Steam Flow I

4 PP-484B, C2-444 S/G No. 2 Pressure 5

LP-484B, C1-430 S/G No. 2 Level 6

FP-484B, C3-746 S/G No. 2 Steam Flow

2-ST-2

.3 Page 2 of 2 06-12-80 TEMP 0 NARY R' CORDERS (cont.)

E 6.3.4 Strip-Chart Recorder No. 3 Ch5nnel Connection Monitoring 1

PP-494B, C2-445 S/G No. 3 Pressure 2

LP-494B, C1-431 S/G No. 3 Level 3

FP-494B, C3-748 S/G No. 3 Steam Flow 4

CC-424 S/G No. 1 Aux Feed Flow 5

CD-425 S/G No. 2 Aux Feed Flow 6

CB-426 S/G No. 3 Aux Feed Flow 6.3.5 Strip-Chart Recorder No. 4 Channel Connection Monitoring 1

FD-122, C6-556 RCS Charging Flow

+

2 FD-150, C6-456 RCS Letdown Flow 3

PP-403A, C4-443 Wide Range RCS Pressure 4

TD-454, C6-636 Pressurizer Steam Temp.

5 TD-453, C6-636 Pressurizer Liquid Temp.

6.3.6 Strip-Chart Recorder No. 5 Channel Connection Monitoring 1

TP-413A, C1-435 Wide Range T L P 1 H0T 2

TP-410A, C2-435 Wide Range T L OP 1 COLD 3

TP-423A, C1-436 Wide Range T L P 2 H0T l

\\

4 TP-420A, C2-436 Wide Range T L P 2 COLD 5

TP-433A, C1-441 Wide Range T L P3 H0T 6

TP-430A, C2-441 Wide Range T L P3 COLD The above installation has been completed and check-out is satisfactory.

)

/

Signature Date The above installation has been removed.

/

1 Signature Date l

2-ST-8 Attrchment 6.4 Page 1 of 3 06-12-80 PROCESS COMPUTER TREND BLOCK A COLUMNS ADDRESS PARAMETER UNITS 1

T0406A RCL A T F

COLD 2

T0426A RCL B T F

COLD 3

T0446A RCL C T F

COLD 4

T0419A RCL A T F

HOT 5

70439A RCL B TH0T 6

T0459A RCL C TH0T 7

T0400A T

LOOP A

F AVG 8

T0420A T

LOOP B F

AVG 9

T0440A T

LOOP C

F AVG 10 T0403A AT LOOP A 11 T0423A AT LOOP B 12 T0443A AT LOOP C 13 F0128A CHARGING FLOW GPM 14 F0134A LETDOWN FLOW GPM 15 U1250 HIGHEST REL FUEL ASSY PWR 16 LO480A PRESSURIZER LEVEL 17 LO112A VCT LEVEL 18 U1251 HIGHEST PEL ASSY PWR INDENT 4

s c

2-ST-8 f

Attechment 6.4 Page 2 of 3 06-12-80 PROCESS COMPUTER TREND BLOCK B COLUMNS ADDRESS PARAMETER UNITS 1

LO400A S/G A LEVEL 2

LC420A S/G B LEVEL 3

LO440A S/G C LEVEL 4

PO400A S/G A PRESS PSIG S

P0420A S/G B PRESS PSIG 6

PO440A S/G C PRESS PSIG 7

P0483A PRESSURIZER P PSIG 8

PO498A RC SYSTEM P PSIG 9

P0142A CHARGING PRESS PSIG 10 UO482 AVG PZR PRESS PSIG 11 UO483 AVG PZR LEVEL 12 U1118 RX THERMAL POWER MW 13 U1170 AVG T/C TEMP

F 14 AS REQUIRED HOTTEST T/C (QUADRANT 1)

F 15 AS REQUIRED HOTTEST T/C (QUADRANT 2)

F 16 AS REQUIRED HOTTEST T/C (QUADRANT 3)

F 17 AS REQUIRED HOTTEST T/C (QUADRANT 4)

F 18 UO969 SATURATION MARGIN

F 1

m,

2-ST-8 Attochment 6.4 Page 3 of 3 06-12-80 PROCESS COMPUTER TREND BLOCK C COLUMNS ADDRESS PARAMETER UNITS 1

T0003A INCORE T/C

'F 2

T0006A INCORE T/C

F 3

T0002A INCORE T/C

F 4

T0005A INCORE T/C

F 5

T0020A INCORE T/C

F 6

T0024A INCORE T/C

F 7

T0022A INCORE T/C

F 8

T0023A INCORE T/C

F 9

T0045A INCORE T/C

F 10 T0033A INCORE T/C

F 11 T0036A INCORE T/C

F 12 T0029A INCORE T/C

F 13 T0030A INCORE T/C

F 14 T0046A INCORE T/C

F 15 T0048A INCORE T/C

F 16 T0044A INCORE T/C

F 17 P0499A RC SYSTEM P PSIG 18 PO484A PRESSURIZER P PSIG l

2-ST-8 Att:chment 6.5 Page 1 of 5 06-12-80 l

CORE POWER DETERMINATION NOTE: This Attachment will be completed by the Reactor Engineer at his discretion.

1.0 PURPOSE 1

The PWRMONT program provides a method for using the movable detector system to obtain a measure of reactor power during natural circulation testing. The program is first normalized to actual reactor power using j

a steady state calorimetric and single pass map. Single pass maps are then run during natural circulation to measure reactor power.

The PWRMONT package consists of the PWRMONT task and certain modif-ications to the existing Westinghouse PRIORITY SCAN and M/D COMPUTATIONS i

programs.

Description The PWRMONT program uses data generated by the M/C COMPUTATIONS program to calculate reactor power based on the following equation:

5 Calculated Power = (I Ni) x K0864 i=1 Where: Ni = Normalized integral for detector i K0864 = PWRMONT calibration factor (See Section 3 Usage)

In addition to the above calculation, the PWRMONT program retrieves valves calculated by the M/D COMPUTATIONS programs and outputs them in the format shown on Figure 1.

This format is self-explanatory except 1

the column labled " SCALE". This column indice.ted the gain setting for each detector and is interpreted as follows:

SCALE GAIN 1

50 MA 2

150 MA 3

500 MA 4

1500 MA 5

5000 MA l-1 i

...T.

LT-- ~

2-ST-8

'.5 Page 2 of 5 06-12-80 Initials 2.0 Initial Conditions 2.1 All initial conditions for 1-0P-57 have been verified.

2.2 Notify the Shift Supervisor on duty of the impending test and coordinate its performance through him.

3.0 Precaution 3.1 Step 2, Instruction must be performed if the normalized integrals shown on Figure 1 are to be useful.

3.2 The upper and lower limit switch settings for the chosen IC-path locations must be accurate if the axial off-sets shown on Figure 1 are to be useful. These limit switch settings can be verified by observing F/M chart recorders and calculating relative detector location by observing flux depressions at known grid strap locations.

3.3 Do not change the value of K0900 during natural circulation testing except when starting a new test, i.e. K0900 = 0.

NOTE:

If more than 25 passes are taken during natural circulation, K0900 will automatically return to 1 and the PWRMONT program will operate correctly.

3.4 Do not request any movable detector data output via the operator's console during natural circulation testing.

4.0 Instructions 4.1 Load the paper tape containing the PRIORITY SCAN and M/D COMPUTA-TIONS program modifications.

4.2 Update the movable detector normalization constants K0908-K0912 using standard flux mapping procedures by insecting each detector in J-7.

(A common group thimble may be used if location J-7 is not available).

.._.22.__._.__

2-ST-8 Attschment 6.5 Page 3 of 5 06-12-80 4.0 Instructions (cont.)

i Calculate the normalization factors by determining the ratio of each Norm Integral to Detector A as follows:

,"f"##

1.0 Norm Factor Det. A

gr 1 n egral B,

rm Norm Factor Det. B = Norm Integral A

f.

=

Norm Factor Det. C =

n egral D,

m Norm Factor Det. D = Norm Integral A Nom Integral E,

Norm Factor Det. E = Norm Integral A i

This step should be repeated at an interval prescribed by the Reactor Engineer based on experience with detecto drift.

Record Initial Norm constants below:

Det. A K0908 1.0 Det. D K0911 Det. B K0909 Det. E K0912 Det. C K0910 4.3 Choose the 10-path locations for each of the five detectors. These locations should be chosen to give the best overall core power monitoring using available core locations. Select detector gain settings to range recorder traces which perk between 3 and 10 when i

the detector scans the selected thimble.

4.4 Set U0072 to

-1.

This prevents the FQSUREY program from interfer-ing with the PWRMONT program.

4.5 Set K0900 to 0.

This sets the current M/D pass number to 0.

5.6 Set K0864 to 1.0.

This sets the PWRMONT calibration factor to 1.0.

2-ST-8 Att:chment 6.5 Page 4 of 5 06-12-80 4.0 Instructions (cont.)

4.7 Simultaneously initiate a singe pass flux map and a calorimetric.

4.8 Detenmine new K0864 value as follows:

New (K0864) = Current (K0864) x (Calorimetric calculated Power)

(PWRMONT Calculated Power)

NOTE:

The PWRMONT calculated power will be output on the utility printer following the single pass map as shown in Firgure 1.

4.9 Repeat Steps 7 and 8 as necessary until the calorimetric power and the PWRMONT power agree to the desired accuracy (i 1% RTP).

4.10 Set K0900 to 0.

This sets the current M/D pass number to 0.

4.11 Initiate single pass maps at will during natural circulation tests to measure reactor power. The movable detectors do not aeed to be withdrawn between passes.

4.12 The PWRMONT program also puts calculated power into addressable constant U0012. Therefore, this point can be trended if desired.

4.13 Following natural circulation testing, reload the tape containing the original PRIORITY SCAN nad M/D COMPUTATIONS Westinghouse programs.

l

2-ST-8

,.5 Page 5 of 5 06-12-80 f

NOR'ill ANNA UNIT 2 - M/D POWER MONITORING 15-80 Det Norm Factors:

K0908 K0909 K0910 K0911 K0912 1.000 1.000 1.000 1.000 1.000 CALORIMETRIC CALIB CONST = 2.206 TIME 18:42 PASS NO.

1 CALC PWR 99.376 %

DET THIMBLE SCAIE NORM INTEGRAL A0 MD-1 H-03 3

7.486

-3.412 MD-2 C-08 4

10.189

-3.488 MD-3 F-04 4

10.006

-3.041 MD-4 C-12 3

7.319

-11.726 MD-5 G-09 4

10.050 2.452 PAhS5 TIME 18:50.

PASS NO.

12 CALC 'cWR 99.498 %

DET THIMBLE SCALE NORM INTEGRAL A0 MD-1 H-03 3

7.485

-3.141 MD-2 C-08 4

10.191

-3.134 MD-3 F-04 4

10.003

-2.731 l

MD-4 C-12 3

7.371

-10.225 MD-5 G-09 4

10.055 2.639 FIGURE I PWRMONT PROGRAM CUTPUT i

.~

~.

2-ST-8

'.6 i

Page 1 of 10 06-12-80 ENGINEERED SAFETY FEATURES AND REACTOR PROTECTION MODIDICATIONS During the performance of these tests, modifications wil.' made to the Engineered Safety Features and the Reactor Protection systems. The systems will operate as specified below.

A.

All automatic Safety Injection (SI) functions, except reactor trip, will be blocked. A Safety Injection actuation signal will result in the following:

1.

Reactor Trip 2.

Control Room Trip Indication and Alarms B.

Safety Injection actuation can be initiated by manual switch operation.

I C.

The High Steam Line Flow Coincident with Low Steam Line Pressure or Low-Low T signal will result from a Low Steam Line Pressure only.

AVG D.

The High Steam Line differential Pressure signal will be blocked.

E.

Containment Spray and acutation system will not be changed.

i.

Containment Phase A isolation will not operrte automatically.

It can be initiated manually by Phase A manual actuation or Safety Injection manual actuation.

G.

Phase B isolation system will not be changed.

H.

Steam Line Isolation will result from any one of the following.

1.

Manual 2.

Containment Pressure - Intermediate High-High 3.

Steam Line Pressure Low I.

Feedwater Isolation will result from:

1) High-High Steam Generator Water Level.

2) Manual Safety Injection.

3) Reactor trip with low T,yg.

~

2-ST-8.6 Page 2 of 10 06-12-80 J.

Auxiliary Feedwater Pump start will result from any one of the following.

1.

Station Blackout 2.

Main Feedwater Pump Trip 3.

Steam Genrator Low-Low Level NOTE:

Setpoint changed from 18 percent NR to 5 percent NR 4.

Manual initiation of Safety Injection K.

The following Reactor Trip signals will be blocked.

1.

Overtemperature delta T 2.

Overpower delta T L.

The following Reactor Trip signals will be blocked by the normal P-7 interlock.

1.

Low Primary Coolant Flow 2.

Undervoltage 3.

Underfrequency 4.

Pressurizer Low Pressure 5.

Pressurizer High Level 6.

Turbine Trip Signal M.

The following Reactor Trip signals will be operable at the setpoint specified.

1.

Power Range, Low Range Neutron Flux 7 percent RTP 2.

Intermediate Range, Neutron Flux 7 percent RTP 3.

Steam Generator Water Level 5 percent NR N.

The following Reactor Trip signals will not be changed.

1.

Pressurizer High Pressure 2.

Low Feedwater Flow

.. __.__.___....___.Ili..

.. R...._.

__~_.__.ZZ 2-ST-8.6 Page 3 of 10 06-12-80 3.

Safety Injection Input 4.

Manual Reactor Trip 5.

Power Range, Neutron Flux High Positive Rate 6.

Power Range, Neutron Flux High Negative Rate I

7.

Source Range, Neutron Flux 8.

Power Range, High Range Neutron Flux 0.

Hardware Modifications Initial 1.0 Prepare the required SSPS test boards as follows:

1.1 (6.6 A, F, I J) Remove CR48 from each of two SSPS Universal Boards (6056D21G01). Label each board and record its serial number as follows:

"A313 TEST BOARD - TRAIN A" "A313 TEST BOARD - TRAIN B" i

1.2 (6.6, C) Remove CR35, CR36 and CR48 from each of two SSPS Univeral Boards (6056D21G01) and connect a jumper from the anode hole of CR35 to the anode hole of CR36.

Label each board and record its serial number as follows:

"A206 TEST BOARD - TRAIN A" "A206 TEST BOARD - TRAIN B" 1.3 (6.6, D) Remove CR2, CR3, CR8 and CR9 frem each of two SSPS Safeguards Output Board (6056D32G01). Label each board and record its serial number as follows:

"A516 TEST BOARD - TRAIN A" "A516 TEST BOARD - TRAIN B" l

l i

2-ST-8

' Attachment 6.6 Page 4 of 10 06-12-80 Initials Remove CR1 and CR7 from each of two SSPS Safeguards Output Boards (6056D32G01). Label each board and record its serial number as follows:

"A517 TEST BOARD - TRAIN A" "A517 TEST BOARD - TRAIN B" 1.4 (6.6, K) Remove CR23, and CR24 from each of two SSPS U.V. Output Board (6058D45G01). Label each board and record its serial number as follows:

"A515 TEST BOARD - TRAIN A" "A515 TEST BOARD - TRAIN B" 2.0 Place SSPS Train "A" in test as follows:

2.1 Place the " Multiplexer Test" switch for Train "A" in the

" Normal" position. Then, have the Operator close the BYPASS breaker which parallels the reactor trip breaker for Train "A".

Confirm this action by verifying the following:

NOTE: The Operator must rack-in the BYPASS breaker prior to closing.

2.1.1 The " General Warning" lamp for the Train "A" illuminates.

2.1.2 The red breaker position indicator "BYA" (fer Train A under test) is illuminated on the MCB.

2.1.3 Annunciators IK G-1, "SFGDS PROT SYS TR A TROUBLE,"

actuates.

2.2 On the Output Relay Test Panel, place the MODE SELECTOR switch in the " TEST" position and verify that the "0PERATE" lamp goes off.

~..

2-ST-8.6 Page 5 of 10 06-12-80 Initials 2.3 On the Logic Test Panel, place the INPUT ERROR INHIBIT switch in the " INHIBIT" position.

3.0 Remove the following Train "A" SSPS boards and record their Serial numbers below:

A313 A206 A516 A517 A515 4.0 Install the test boards prepared in Section 1.0 in their appro-priate slots.

"A313 TEST BOARD - TRAIN A" "A206 TEST BOARD - TRAIN A" "A516 TEST BOARD - TRAIN A" "A517 TEST BOARD - TRAIN A" "A515 TEST BOARD - TRAIN A" 5.0 Return SSPS Train "A" to service as follows:

5.1 Place the MODE SELECTOR switch to "0PERATE".

5.2 Have the Operator place the following manual block switches for Trains A and B in the " BLOCK" position:

NOTE: Blocks will not be set unless their associated permis-sives are present.

SOURCE RANGE BLOCK & RESET INTERMEDIATE RANGE BLOCK POWER RANGE BLOCK LO S.P.

LO T-AVE SI - A(B) BLOCK & RESET LO PRZ SI - A(B) BLOCK & RESET l

t

2-ST-8.6 Page 6 of 10 06-12-80 Initials 5.3 Place the INPUT ERROR INHIBIT switch to " NORMAL".

5.4 Verify that both Reactor Trip Breakers are closed.

5.5 Have the Operator open and rack out the BYPASS Preaker which was closed in Step 2.1.

NOTE: The " General Warning" lamp should go off.

CAUTION: If the MULTIPLEXIR TEST switch will pass through the

" INHIBIT" position in the following step, ensure that there is no "Ceneral Warning" for the opposite train.

5.6 Return the MULTIPLEXER TEST switch for Train "A" to the "A" + B" position.

5.7 Verify that Control Room annunciator IK-7 for Train A is extinguished.

6.0 Place SSPS Train "B" in test as follows:

6.1 Place the " Multiplexer Test" switch for Train "A" in the

" Normal" position. Then, have the Operator close the BYPASS breaker which parallels the reactor trip breaker for Train "B".

Confirm this action by verifying the following:

NOTE: The Operator must rack-in the BYPASS breaker prior to closing.

6.1.1 The " General Warning" lamp for train "B" illuminates.

6.1.2 The red breaker position indicator "BYB" (for Train B under test) is illuminated on the MCB.

6.1.3 Annunciators IK G-2, "SFGDS PROT SYS TR B TROUBLE," actuates.

l

2-ST-8

..6 Page 7 of 10 06-12-80 Initials 6.2 On the Output Relay Test Panel, place the MODE SELECTOR switch in the " TEST" position and verify that the "CPERATE" lamp goes off.

6.3 On the Logic Test Panel, place the INPUT ERROR INHIBIT switch in the " INHIBIT" position.

7.0 Remove the following Train "B" SSPS boards and record their Serial numbers below:

A313 A206 A516 A517 ASIS 8.0 Install the test boards prepared in Sectin 1.0 in their appro-priate slots.

"A313 TEST BOARD - TRAIN B" "A206 TEST BOARD - TRAIN B" "A516 TEST BOARD - TRAIN B" "A517 TEST BOARD - TRAIN B"

" ASIS TEST BOARD - TRAIN B" 9.0 Return SSPS Train "B" to service as follows:

9.1 Place the MODE SELECTOR switch to "0PERATE".

l 9.2 Have the Operator place the following manual block switches for Trains A and B in the " BLOCK" position:

1 1

NOTE: Blocks will not be set unless their associated permis-sives are present.

SOURCE RANGE BLOCK & RESET INTERMEDIATE RANGE BLOCK 4

2-ST-8.6 Page 8 of 10 06-12-80 Initials POWER RANGE BLOCK LO S.P.

LO T-AVE SI - A(B) BLOCK & RESET LO PRZ SI - A(B) BLOCK & RESET 9.3 Place the INPUT ERROR INHIBIT switch to " NORMAL".

9.4 Verify that both Reactor Trip Breakers are closed.

9.5 Have the Operator open and rack out the BYPASS breaker which was closed in Step 6.0.

NOTE: The " General Warning" lamp should go off.

CAUTION: If the MULTIPLEXER TEST switch will pas through the

" INHIBIT" position in the following step, ensure that there is no " General Warning" for the opposite train.

9.6 First return the Multiplexer Test switch for Train "A" to normal. Then return the " Multiplexer Test" switch for Train "A" to the "A" + B" position.

9.7 Verify that Control Room annunciator IK-15 for Train B is extinguished.

10.0 Return the SSPS to normal as follows:

10.1 Place SSPS Train "A" in test in accordance with Steps 2.1 through 2.3.

10.2 Remove the test boards instalied in Section 4.0.

10.3 Install the SSPS boards removed in Step 3.0 and record their serial numbers below:

A313 A206 A516 A517 ASIS

2-ST-8.6 Page 9 of 10 06-12-30 Initials 10.4 Return SSPS Train "A" to service in accordance with Section 5.0 10.5 Place SSPS Train "B" in test in accordance with Steps 6.1 through 6.3.

10.6 Remove the test boards installed in Section 8.0.

10.7 Install the SSPS boards removed in Step 7.0 and record their serial numbers below:

A313 A206 A516 A517 A515 10.8 Return SSPS Train "B" to service in accordance with Section 9.0.

10.9 Perform 2-PT-36.1 for SSPS Trains "A" and "B".

NOTE:

Insure that the test board modifications are corrected prior to returning these boards to stock.

P.

Setpoint Changes 1.0 Change 18% Steam Generator Lo-Lo trip to 5% by adjusting the Signal Comparator Card from 1.800 VDC trip to 0.500 VDC trip and from 1.900 VDC reset to 0.600 VDC reset.

Signal Comparator Card Procedure LC-474A ICP-P-2-L-474 LC-475A ICP-P-2-L-475 LC-476A ICP-P-2-L-476 LC-484A ICP-P-2-L-484

.-. ~. -

2-ST-8.6 Page 10 of 10 06-12-80 Initial LC-485A ICP-FA>-L-485 LC-486A ICP-P-2-L-486 LC-494A ICP-P-2-L-494 LC-495A ICP-P-2-L-495 LC-496A ICP-P-2-L-496 2.0 Verify Power Range, Low Range Neutron Flux trip is set at 7 percent RTP.

3.0 Verify Intermediate Range, Neurton Flux trip is set at 7 percent RTP.

4.0 Following Natural Circulation testing or when directed to by the Test Engineer return Steam Generator Lo-Lo level trip from 5% to 18%.

Signal Comparator Card Procedure LC-474A ICP-P-2-L-474 LC-475A ICP-P-2-L-475 LC-476A ICP-P-2-L-476 LC-484A ICP-P-2-L-484 LC-485A ICP-P-2-L-485 LC-486A ICP-P-2-L-486 LC-494A ICP-P-2-L-494 LC-495A ICP-P-2-L-495 LC-496A ICP-P-2-L-496

2-ST-8.7 Page 1 of 2 06-12-80 OPERATIONAL SAFETY CRITERIA During the performance fo these tests, the operator must meet the following set of criteria for operation.

A.

For all tests Primary System Subcooling (T,,

Margin)

> 20 F a.

b.

Steam Generator Water Level Span

~ 33 percent c.

Pressurizer Water Level (1) With RCP's Running 21 percent Span (2) Natural Criculation 2 Value when RCP's tripped d.

Loop AT 5 65*F e.

T

$ 580*F AVG f.

CoreExitTemperature(hig!.e.4t) 5 610*F g.

Power Range Neutron Flux

< 5 percent RTP h.

Control Bank D

> 100 steps withdrawn B.

Reactor trip and test termination must occur if any of the following conditions are met a.

Primary System Subcooling (T Margin) 5 15*F sat b.

Steam Generator Water Level

< 5 percent Narrow Range Span c.

NIS Power Range, 2 Channels

> 7 percent RTP d.

Pressurizer Water Level 5 17 percent Span or an unexplained decrease of more than 5 percent not concurrent with a T,yg change e.

Any Loop AT

> 65*F

-.W

--W.+wa y

w y

=

2-5I-8.7 o

Page 2 of 2 06-12-80 f.

TAVG g.

Core Exit Temperature (highest)

> 610*F h.

Uncontrolled rod motion C.

Safety injection must be manually initiated if any of the following conditions are met a.

Primary System Subcooling (T Margin)

$ 10*F sat b.

Steam Generator Water Level

< 0 percent Narrow Range Span or Equivalent Wide Range Level c.

Containment Pressure 2 17 psia d.

Pressurizer Water Level

< 10 percent Span or an unexplained decrease of more than 10 percent not concurrent with a T

change AVG e.

Pressurizer Pressure Decreases by 200 psi or more in an unexplained manner Safety injection termination must be in accordance with the termination criteria set forth in the Station Emergency Procedures.

- ~

2-ST-8.8 Page 1 of 1 06-12-80 j

CORE AT WITH NATURAL CIRCULATION ESTIMATED RANGE Core AT (*F)

Power Level (%)

2-Operating Loops 3-Operating Loops 1

10-35 7-36 1 1/2 19-45 13-31 3

26-45 NOTE: These values of core AT reflect an uncertainty of 0.5 core power.

I i

s vn

-,ev y

g-n

2-ST-8.9 Page 1 of 1 06-12-80 TRAINING LOG The following personnel PARTICIPATED in the performance of the test, as defined in 2-SU-1, Attachment 5.6:

Name (print)

The following personnel OBSERVED the performance of this test, as defined in 2-SU-1, Attachment 5.6:

Name'(print)

Name (print)

The completed Individual Training Record, 2-SU-1, Attachment 5.6, Attachment A, for each of the above-named individuals has been attached to this procedure.

Shift Supervisor

/

Signature Date

2-ST-8

-.10 Page 1 of 2 06-12-80 AUXILIARY SPRAY TEST 1.

OBSERVE straight - line trace of pressurizer pressure on recorder PR-2444.

RECORD pressurizer pressure indicated on PI-2444:

psig.

2.

Place spray valve controllers PC-2444G and H in MANUAL and OPEN Valves PCV-2455A and B.

CAUTION: The following steps place the plant in a condition for the establishment of initial baseline data. A sufficient degree of uncertainty exists such that spray flow may be initiated upon the execution of any step. Observe ALL available indications of RCS pressure.

Do not allow RCS pressure to fall below 2135 psig.

Immediately upon any sudden or uncontrolable pressure decrease, shut auxiliary spray valve HCV-2311 and open charging valve HCV-2310.

If system pressure response becomes unduly sensitive to changes in valve position under these conditions, establish minicum letdown, balance the charging flow for constant pressurizer level, and reattempt this Attachment.

3.

OPEN auxiliary spray valve HCV-2311 and observe system pressure response.

4.

SHUT charging valve HCV-2310 and observe system pressure response.

5.

Slowly begin shutting pressurizer spray valve PCV-2455A, and then, if necessary, PCV-2455B, observing RCS pressure indication.

Under the direction of the Shif t Supervisor, establish the optimum valve position operating range for pressure control i

under these conditions.

t

~

a 2-ST-8.10 Page 2 of 2 06-12-80 RECORD:

PCV-2455A and B position at which system pressure decrease is first obtained.

PCV-2455A PCV-2455B FI-2212 i

TI-2123 CAUTION: During the following step, observe the Tsat "*#

and do not allow the system to fall below a 20*F saturation margin.

6.

Reposition PCV-2455A and B to the positions established in step 5 to maintain minimum auxiliary spray flow. Observe restoration of system pressure by automatic heater operation. Re-establish charging and letdown to the conditions existing prior to step 4.13 in the body of the procedure.

~

i l

. ~ -. -. - -.. =

o 2-ST-8

'.11 Page 1 of 1 06-12-80 1

DEPRESSURIZATION RATE Attach copies of the computer trend printout and the brush recorder charts to this page.

From the above data, starting after equilibrium has been reached, calculate the depressurization rate and the pressurizer cooldown rate (liquid temp) and record below.

Depressurization Rate psig/hr.

Pressurizer Cooldown Rate

F/hr.

Calculated by Reviewed by NOTE: A plot of the RCS depressurization rate vs time can be made from the attached data if desired.

i l

l 1

1 l

I i

I

.__ _I

c.~...

.~..:

. = -_.u..; _.u.-

9.

2-ST-8

_.12 Page 1 of 1 06-12-80 SATURATION MARGIN SATURATION METERS TIME SCI-RC-200A SCI-RC-200B Completed by:

Date:

.=

VEPCO Pi10PERTY

'n:ia document is the.:rcWt7 of th'3 ADM-40.0

'/irr; inia Electric and I'c.cer Cerp'.ry d is to be ret C "d '@ H l' W" #' . '

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-ST-11 VIRGINIA-ELECTRIC-AND-POWER COMPANY Date:

06-12-80 Page 1 of 2

SPECIAL TEST PROCEDURE FOR NORTH ANNA POWER STATION UNIT #

2 TITLE:

EFFECT OF STEAM GENERATOR SECONDARY SIDE ISOLATION ON NATURAL CIRCULATION Prepared By:

G. A. KANN Date:

ce; A n Date:

[//dd Engineering Recommended Approval:

STATION NUCLEAR SAFETY AND OPERATING COMMITTEE REVIEW OF PROCEDURE:

Unreviewed Safety Question:

Yes No Disposition:

Approved O Disa no ed OAPProved as Modified Chairman's Signature:

s Date: [/. Cs 5

SYSTEM NUCLEAR SAFETY AND OPERATING COMMITTEE REVIEW OF PROCEDURE:

NOTE:

Review not required unless an unreviewed safety question is involved as determined above.

Disposition:

DAPProved Disapproved OAPProved as Modified Chairman's Signature:

Date:

VERIFICATION 0F NRC APPROVAL:

OApproved Not Required Station Manager's Signature:

Date:

)

TEST RESULTS REVIEWED BY ENGINEERING:

Date:

TEST RESULTS REVIEWED BY STATION NUCLEAR SAFETY AND OPERATING COMMITTEE:

Chairman's Signature:

IVO T

.a. ro,f rn Date:

s,,D

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UGCUMENT Comments:

5 di>W i 4 jg g

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. u s,..., _ y (y' WEST Rrypyny 8006170 M/

e TEST RESULTS (Use additional pages as needed)

Page 2 of _

110 DISCRE?ANCIES (Lisc by numoer).

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l' RESOLUTION OF DISCREFANCIES (List by nummer corres=ending to accvel:

CRITICUE:

LL2_

4 3

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CHRONOLOGICAL LOG (Use add'1 pages as needed)

Page _ of e

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s 2-ST-11 Page 1 of 13 06-12-80 VIRGINIA ELECTRIC AND POWER COMPANY NORTH ANNA POWER STATION UNIT NO. 2 EFFECT OF STEAM GENERATOR SECONDARY SIDE ISOLATION ON NATURAL CIRCULATION

References:

1.

Precautions, Limitation and Setpoints for Westinghouse NSSS system 2.

Technical Specifications, North Anna Unit No. 2 3.

WCAP-8747: North Anna Nuclear Design Report 4.

North Anna Station Curve Book 5.

2-0P-5.2 6.

2-0P-31 1.0 Purpose 1.1 Determine the effect of steam generator isolation on natural circulation conditions.

1.2 Verify that natural circulation can provide sufficient flow to remove decay heat after partial loss of heat sink.

1.3 Verify that natural circulation can be reestablished in a primary loop after a steam generator is returned to service.

1.4 To provide operations personnel with experience in unit operation under natural circulation conditions.

2-ST-11 Page 2 of 13 06-12-80 Initials 2.0 Initial Conditions 2.1 The reactor is critical in manual rod control at 1 percent power. Bank D is in Bank Select.

2.2 All three reactor coolant pumps in operation.

2.3 Pressurizer pressure and level control are in automatic maintain-ing RCS pressure at approximately 2000 psig and pressurizer level at approximately 22 percent.

2.4 Steam dump valves are in the pressure control mode maintaining steam generator pressure approximately 763 psig and RCS temper-ature at 515 5'F.

2.5 Steam generator level will be maintained at approximately 33 percent on narrow range. Main feedwater system in automatic on bypass valves.

If main feedwater pump operation cannot be maintained under these conditions, the auxiliary feedwater system is in service in accordance with 2-0P-31.2.

2.6 Shutdown banks are fully withdrawn and control banks are above their insertion limits. Control bank D is near 160 steps; this is to establish a zero moderator temperature coefficient.

R2. 7 Steam generator chemistry is in a condition such that blowdown may be isolated for the duration of this test.

2.8 Excess letdown is available for service if required during this test; however do not use excess letdown unless absolutely required.

2.9 The CVCS is in a normal at power makeup and letdown configura-tion.

2.10 Temporary instrumentation is installed in accordance with.3.

2-ST-11 Page 3 of 13 06-12-80 Ieitials 2.0 Initial Conditions (cont.)

NOTE:

Record the following on each strip chart:

a) Test Number b) Recorder QA Number c) Time and Date d) Chart Speed e) Scale Used f) Test Point g) Parameter 2.11 The computer trend printer is set up to monitor the parameters indicated in Attachment 6.4.

2.12 The analog trend recorder on the main control board is set up to monitor the hottest incore T/C in each quadrant, as determined by the P-250 incore thermocouple map. Saturation margin (UO969) is monitored on the digital display.

2.13 All test equipment to be used in the performance of this test is operational and in calibration, and has been recorded on the TEST EQUIPMENT DATA SHEET (Attachment 6.1).

2.14 Immediately prior to the performance of this test, the Test Engineer has reviewed the latest revisions of the applicable references in order to improve his familiarity with this procedure and insure that it is still valid for the test, i.e., changes to the system, equipment, or component since the procedure was approved will not affect its performance.

2.15 The Shift Supervisor on duty has been notified of the impending test and will coordinate its performance.

I

2-ST-11 Page 4 of 13 06-12-80 Initials 2.0 Initial Conditions (cont.)

2.16 The setpoint on atmospheric relief valve pressure controller PC-MS-201B is set at 1025 psig. This should prevent opening of main safety valves during isolation.

2.17 Engineered Safety Features and Reactor Protection modifications have been made in accordance with Attachment 6.6.

2.18 Instrumentation section has completed ICP-P-2-P-474,-485 and

-496 to adjust the bistable input voltage for PC474A, PC485A, and PC496A to trip at 3.929 VDC (0UTPUT LED, OFF) and to reset at 4.029 VDC (OUTPUT LED, ON) in lieu of the listed values of 4.286 VDC trip and 4.386 VDC reset.

NOTE:

This will set the low steam line pressure bistable to trip at 550 psig vice 600 psig.

2.19 Motor operated feedwater isolation valves MOV-FW254A,B,C and main feedwater control valves FCV-2478, 2488 and 2498 are shut.

i

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2-ST-11 Page 5 of 13 06-12-80 Imitials 3.0 Pr eautions 3.1 Refer to Operational Safety Criteria in Attachment 6.7.

3.2 Do not exceed 5% rated thermal power at any time while the test is in progress.

3.3 Ensure seal flow to each reactor coolant pump is maintained at between 7-11 gpm during the test, and adjust as necessary at least every 100 psi change in RCS pressure (2-0P-5.2).

3.4 The Operational Safety Criteria is prominently displayed in the Main Control Room.

3.5 Avoid rapid or sudden changes in steam pressure and feedwater flow to prevent rapid cooling of the reactor coolant.

3.6 After the reactor coolant pumps are tripped, the normal delta T and T indications will become unreliable. Delta T and T avg avg shall be calculated by taking the difference and the average of the hot'and cold leg wide range temperature indications respec-i tively.

j 3.7 Maintain T at 515iS*F (the pre-RCP trip temperature) to COLD maintain accurate NIS power level monitoring, unless otherwise specified in the test, i

3.8 Do not exceed primary to secondary differential pressure of 1600 psi.

3.9 Maintain less than 100 psi differet tial pressure between any 1

two steam lines and greater than 600 psig in each steam generator, except when SG "B" is isolated the differential pressure between SG B and the other generators may approcch 250 psid.

i l

2-ST-11 Page 6 of 13 06-12-80 Initials 3.0 Precautions (cont.)

3.10 Note possible effects of polarity changes in moderator tempera-ture coefficient as temperature changes.

3.11 The pressurizer temperature shall be limited to a normal maximum spray water temperature to pressurizer temperature differential of 320*F.

Auxiliary spray must be isolated if letdown is isolated.

3.12 Do not borate under natural circulation conditions while the reactor is critical.

3.13 Pressurizer spray should be initiated slowly to minimize thermal stress. Maintain continuous flow for uniform chemistry unless otherwise directed.

3.14.The reactor coolant system (except the pressurizer) temperature and pressure shall be limited in accordance with the limit lines shown on figures 3.4-2 and 3.4-3 of the technical specif-ications during heatup or cooldown, with a maximum heatup or.

cooldown of 50*F in any one hour period.

3.15 Anytime speed is changed on any recorder, initial, date, time, and speed should be listed on the recorder.

3.16 Should a reactor trip take place during natural circulation, close spray valves (PCV-2455A & B) and restart reactor coolant pump 2-RC-P-IC prior to closing the reactor trip breaker.

3.17 Maintain control bank D > 100 steps during the conduct of this test. Should this limit be reached, insert control bank D to zero steps and restart RCP's per instructions in this procedure.

Contact Reactor Engineer for further instructions.

2-ST-11 Paga 7 of 13 06-12-80 Initials 3.0 Precautions (cont.)

3.18 When testing with the reactor coolant in the low temperature range of 450*F to 500*F, maintain the lithium concentration at 2.0 to 2.2 ppm, the upper part of the lithium range. This is especially necessary since high boric acid concentrations (~

1000 ppm) are being used.

4.0 Instructions 4.1 Record the time on the data recorder charts in the instrument rack rcom and start the recorders at 125 mm/ min.

4.2 Begin recording on the reactivity computer.

4.3 Prepare the plant computer to record data as specified in.4.

Record the initial steady state values as specified in Attachment 6.2.

4.4 Place the pressurizer level controller LC 2459B in manual.

Adjust, if necessary, to match letdown to maintain pressurizer level prior to tripping the RC pumps.

CAUTION: Continuously monitor main steam line pressures and carefully control feedwater addition during the transient to ensure that differential pressure between any two steam lines does not exceed 100 psid.

NCJE:

Steam generator pressure, level and flow conditions should be held as close as possible to stable conditions as natural circulation develops. Reactor coolant s:; tem cold leg temperatures should be maintained at 515 5*F.

NOTE:

At the initiation of natural circulation (RCP trip),

the following system response is expected.

1.

Wide range fhot; increase (7 to 26 F at ~ 1 percent power).

2.

Wide range Teold; slight decrease or constant 3.

Core exit thermocouples; increase (7 to 26 F at ~

1 percent power).

4.

Pressurizer level; increase (2 to 7 percent at

~ 1 percent power).

2-ST-11 Page 8 of 13 06-12-80 Initials 4.0

. Instructions (cont) 5.

Pressurizer pressure; increase.

CAUTION: Following reactor coolant pump trip T and and delta

- 8 T indication will be unreliable.

CAUTION: After tripping RC pumps, the RCS pressure is expected to increase as much as 50 psi depending on power level of the core. Be prepared to use auxiliary spray to control pressure as stated in steps 4.6 and 4.7.

4.5 Simultaneously trip all three reactor coolant pumps in accordance with 2-0P-5.2.

Place spray valve controllers PC-2444G in

)

manual and then open valves PCV-2455A and B.

j 4.6 If RCS pressure exceeds 2050 psig, open auxiliary spray valve HCV 2311. Maintain regenerative heat exchanger charging outlet temperature (TI-2123) above 350*F or confirm that the 320*F temperature differential of precaution 3.11 can be maintained.

I 4.7 If RCS Fressure exceeds 2075 psig, close charging line valve HCV 2310 and manually throttle spray valves PCV-2455A and B, as f

required, to maintain RCS Pressure below 2075 psig.

1 CAUTION: Once auxiliary spray is initiated to limit RCS pressure, insure that a minimum continuous auxiliary spray flow is maintained to the pressurizer by turning on one bank of backup pressurizer heaters and adjusting the position of PCV-2455 A and B to maintain the RCS pressure at approximately 2000 psig.

i 4.8 Maintain RCP seal injection at 7-11 GPM to each pump.

l l

4.9 Maintain charging flow to match letdown and maintain a constant RCS water mass.

(Maintain pressurizer level approximately 1

1 constant after equilibrium has been reached on natural circulation 1

by manually adjusting charging flow).

l NOTE:

Allow the pressurizer level to increase when the average RCS temperature increases (expected increase is-approx-imately 3/4 percent per *F increase in average RCS temperature).

O 2-ST-11 Page 9 of 13 06-12-80 Initials 4.0 Instructions (cont) 4.10 Carefully control additions of feedwater to the steam generators to maintain levels at approximately 33 percent.

NOTE:

After tripping RC pumps, the SG levels may shrink slightly and then swell as natural circulation develops.

4.11 If required adjust the pressure setpoint on steam dump pressure controller PC-2464 B to maintain RCS cold leg temperatures within 5*F of 515*F.

NOTE:

Natural circulation flow will be stable (within approx-imately 10 to 20 minutes) when:

a) Delta T between wi range T and T constant H0T COLD b) Delta T between wide range T and core exit temperatureasindicatedbykOhcoreexitT/Csis constant c) Wide range T is approximately equal to core exit H0T T/C temperatures (See Attachment 6.8) 4.12 Verify / restore the RCS pressure to approximately 2000 psig.

NOTE:

Upon isolating the steam generator, the primary pressure is expected to increase 100 psi within 10 minutes and the primary to secondary differential pressure is l

expected to reach 1300 to 1400 psi.

In the event the primary pressure rises to 2075 psig, adjust auxiliary spray to limit RCS pressure.

NOTE:

Again allow the pressurizer level to increase when T is increased.

(Expectedincreaseisapproximately3fEg percent per *F increase in TAVG

NOTE:

When steam generator B is isolated the differential pressure between steam generator B and the other steam generators is expected to be in the range 50 to 250 psid.

4.13 Isolate steam generator B by closing main steam valves TV-MS-213B and TV-MS-201B, steam generator blowdown valves TV-BD-200C for steam generator B, and main feedwater valve FCV-2489.

t 2-ST-11 Page 10 of 13 06-12-80 Initials 4.0 Instructions (cont) 4.14 Carefully control feedwater additions to the remaining steam generators to hold the level at approximately 33 percent.

It may be necessary to adjust the steam dump pressure controller setpoint to reduce T in the unisolated loops so that the COLD steam generator pressure in the isolated loop remains below the 1025 psig setpoint of the steam generator B atmospheric relief valve.

NOTE:

During this transient the following responses can be expected:

1.

Wide range T OT' I""#****

2.

Wide range fr1 P B, increase to ~ T COLD HOT

3.

Wide range T fr1 Ps A and C, constant using steam dump. COLD 4.

Core exit thermocouples, increase 3 to 9*F.

5.

Pressurizer level, increase ~ 4 percent in level.

i 6.

Pressurizer pressure, increase to ~ 2100 psig.

)

4.15 Allow natural circulation conditions to stabilize as determined when:

a) the delta T for loop B is approximately zero and stabilized.

b) the delta T between wide range T and T fr1 Ps H0T COLD A and C are constant.

c) the delta T between wide range T and core exit tempera-COLD j

ture as indicated by the core exit T/C's is constant.

d) Wide range T is approximately equal to core exit T/C HOT temperatures.

(See Attachment 6.8).

l

}

4.16 Slowly reduce the setpoint on atmospheric relief valve controller 4

PC-NS-201B, allowing steam generator B to reach approximate equilibrium with the steam header pressure. Slowly restore feedwater by throttling FCV-2489 to maintain ~ 33 percent level.

n.

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2-ST-11 Pega 11 of 13 06-12-80 l

INITIALS l

4.0 Instruction (cont) 4.17 Reestablish steam generator B blowdown as required by Chemistry Department.

4.18 Open main steam trip by pass valve TV-MS213B to equalize pressure with the steam header.

4.19 Open main steam trip valve TV-MS201B.

4.20 Close main steam trip by-pass valve TV-MS213B.

4.21 Adjust setpoint on atmospheric relief valve pressure controller PC-MS-201B to 1025 psig.

4.22 Allow natural circulation to stabilize as determined when:

a) Delta T between wide rnge T and T is constant.

H0T COLD b) Delta T between wide rage T and core exit temperature COLD as indicated by the core exit T/Cs is constant.

c) Wide range T is approximately equal to core exit T/C HOT temperatures (see Attachment 6.8).

4.23 Insert Control Bank D to zero steps.

4.24 Open normal charging HCV-2310 and shut auxiliary spray valve HCV-2311.

4.25 Place pressurizer spray controllers in manual / closed.

4.26 Verify T C'

~

H 4.27 Restart all three reactor coolant pumps in accordance with 2-OP-5.2, beginning with C, A and then B.

4.28 Stop the Recorders and Trend Printers.

4.29 Return charging and letdown to normal.

4.30 Return RCS pressure to 2235 psig.

4.31 Return steam dump pressure control setpoint to 1005 psig.

2-ST-11 Page 12 of 13 06-12-80 INITIALS 4.0 Instructions (cont) 4.32 Remove ESF and RTP actuation blocks in accordance with.6, unless the next test to be performed requires this modification to be made.

If this is the case, disregard this step, place N/A in the signature line and initial.

1 NOTE:

Re-Instate all safety function if a delay of testing of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or more is anticipated.

4.33 Keep the printouts and charts from the recorders and trend i

printer with this procedure and remove the recorders if this i

concludes the natural circulation testing.

4.34 Reset low steam line pressure bistables PC474, PC485, and PC496 to 600 psig.

4.35 Notify Shift Supervisor that the test is completed.

Completed by:

Time /Date:

2-ST-11 Page 13 of 13 06-12-80 Initials 5.0 Acceptance Criteria 5.1 With a partial loss of heat sink (one steam generator), sufficient natural circulation flow to remove 1 percent reactor power was demonstrated.

5.2 Natural circulation was reestablished in primary loops after an isolated steam generator was returned to service.

6.0 Attachmencs 6.1 Test Equipment Data Sheet 6.2 Initihl Conditions 6.3 Temporary Recorders 6.4 Process Computer Trend Block Data 6.5 Core Power Determination 6.6 Engineered Safety Features and Reactor Protection Modifications 6.7 Operational Safety Criteria 6.8 Core Delta T with Natural Circulation 6.9 Training Log i

2-ST-11.1 Page 1 of 1 06-12-80 TEST EQUIPMENT DATA SHEET TEST EQUIPMENT DESCRIPTION

MODEL NUMBER VEPC0 QC NUMBER h

1 i

NOTE: This' applies only to temporarily installed test equipment or instrumentation.

Permanent instrumentation which is part of the system and shown on drawings should not be included.

Completed By:

Date:

2-ST-11.2 Page 1 of 3 06-12-31 INITIAL CONDITIONS Pressurizer Pressure psig PR-2444 Red Pen Pressurizer Level LR-2459 Red Pen RCS Loop 1 Hot Leg Temperature

F TR-2413 Red Pen RCS Loop 1 Cold Leg Temperature

F TR-2410 Red Pen RCS Loop 2 Hot Leg Temperature

F TR-2423 Green Pen RCS Loop 2 Cold Leg Temperature

F TR-2420 Green Pen RCS Loop 3 Hot Leg Temperature

F TR-2433 Blue Pen RCS Loop 3 Cold Leg Temperature

F TR-2430 Blue Pen Steam Generator ? Level (NR)

(LI-2474)

Steam Generator 2 Level (NR)

(LI-2484)

Steam Generator 3 Level (NR)

(LI-2494)

Steam Generator 1 Level (WR)

LR-2477 Pen 1 Red Pen Steam Generator 2 Level (WR)

LR-2477 Pen 2 Green Pen Steam Generator 3 Level (WR)

LR-2477 Pen 3 Blue Pen Steam Generator 1 Pressure Psig PI-2474 Steam Generator 2 Pressure Psig PI-2484 Steam Generator 3 Pressure Psig PI-2494

___-__1.-

2-ST-11.2 Page 2 of 3 06-12-80 INITIAL CONDITCNS 6

Steam Generator 1 Feedwater Flow X10 #/hr (FI-2476) 0 Steam Generator 2 Feedwater Flow X10 #/hr (FI-2486) 6 Steam Generator 3 Feedwater Flow X10 #/hr (FI-2486) 0 Steam Generator 1 Steam Flow X10 lbs/hr (FI-2474) 6 Steam Generator 2 Steam Flow X10 lbs/hr (FI-2484) 0 Steam Generator 3 Steam Flow X10 lbs/hr (FI-2494)

Loop 1 Tavg Protection

'F (TI-2412D)

Loop 2 Tavg Protection

'F (TI-2422D)

Loop 3 Tavg Protection

F (TI-2432D)

Loop 1 AT Protection (TI-2412A)

Loop 2 AT Protection (TI-2422A)

Loop 3 AT Protection (TI-2432A)

NIS Channel N-41 i

NIS Channel N-42 NIS Channel N-43 NIS Channel N-44 Attach a copy of the computer printout of the Incore Thermocouple Temperature map.

Temperature in Turbine - Drive Aux Feed Pump Room

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

2-ST-11.2 Page 3 of 3 06-12-80 Control Room Temperature

'T i

Outside Temperature

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Completed By:

3 Date:

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2-ST-11

..3 Page 1 of 2 06-12-80 TEMPORARY RECORDERS C:nnect temporary strip-chart recorders as indicated below.

6.3.1 Reactivity-Computer Recorder a.

Flux b.

Average wide range TCOLD b.

Average wide range THOT d.

Reactivity Snt the chart speed on the following records to 125 mm/ min.

6.3.2 Strip-Chart Recorder No. 1 Channel Connection Monitoring 1

FP-414B, C1-432 RCS Flow, Loop 1 2

FP-424B, C1-433 RCS Flow, Loop 2 3

FP-434B, C1-434 RCS Flow, Loop 3 4

FP-455B, C1-427 Pressurizer Pressure 5

FP-459B, C1-442 Pressurizer Level 6.3.3 Strip Chart Recorder No. 2 Channel Connection Monitoring 1

PP-474B, C2-433 S/G No. 1 Pressure 2

LP-474B, C1-429 S/G No. 1 Level 3

FP-474B, C3-741 S/G No. 1 Steam Flow 4

PP-484B, C2-444 S/G No. 2 Pressure 5

LP-484B, C1-430 S/G No. 2 Level 6

FP-484B, C3-746 S/G No. 2 Steam Flow

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2-ST-11.3 Page 2 of 2 06-12-80 TEMPORARY RECORDERS (cont.)

6.3.4 Strip-Chart Recorder No. 3 Channel Connection Monitoring 1

PP-494B, C2-445 S/G No. 3 Pressure 2

LP-494B, C1-431 S/G No. 3 Level 3

FP-494B, C3-748 S/G No. 3 Steam Flow 4

CC-424 S/G No. 1 Aux Feed Flow 5

CD-425 S/G No. 2 Aux Feed Flow 6

CB-426 S/G No. 3 Aux Feed Flow 6.3.5 Strip-Chart Recorder No. 4 Channel Connection Monitoring 1

FD-122, C6-556 RCS Charging Flow 2

FD-150, C6-456 RCS Letdown Flow 3

PP-403A, C4-443 Wide Range RCS Pressure 4

TD-454, C6-636 Pressurizer Steam Temp.

5 TD-453, C6-636 Pressurizer Liquid Temp.

6.3.6 Strip-Chart Recorder No. 5 Channel Connection Monitoring 1

TP-413A, C1-435 Wide Range T L P 1 HOT 2

TP-410A, C2-435 Wide Range T L P 1 COLD 3

TP-423A, C1-436 Wide Range T P 2 H0T 4

TP-420A, C2-436 Wide Range T P 2 COLD 5

TP-433A, C1-441 Wide Range T L P3 HOT 6

TP-430A, C2-441 Wide Range T L P3 COLD Th2 above installation has been completed and check-out is satisfactory.

/

Signature Date Thn above installation has been removed.

/

Signature Qate

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_.._--c_.__..__

2-ST-11.4 Page 1 of 3 06-12-80 PROCESS COMPUTER TREND BLOCK A COLUMNS ADDRESS PARAMETER UNITS 1

T0406A RCL A TCOLD 2

T0426A RCL B TCOLD

.)

T0446A RCL C TCOLD 4

T0419A RCL A THOT 5

70439A RCL B THOT 6

T0459A RCL C TH0T 7

T0400A T

OOP A

'F AVG 8

T0420A T

LOOP B

F AVG 9

T0440A T

LOOP C

'F AVG 10 T0403A AT LOOP A 11 T0423A AT LOOP B 12 T0443A AT LOOP C 13 F0128A CHARGING FLOW GPM 14 F0134A LETDOWN FLOW GPM 15 U1250 HIGHEST REL FUEL ASSY PWR 16 LO480A PRESSURIZER LEVEL 17 LO112A VCT LEVEL 18 U1251 HIGHEST REL ASSY PWR INDENT 1

2-ST-11.4 Page 2 of 3 06-12-80 PROCESS COMPUTER TREND BLOCK B COLUMNS ADDRESS PARAMETER UNITS 1

LO400A S/G A LEVEL LO420A S/G B LEVEL' 3

LO44CA S/G C LEVEL 4

PO400A S/G A PRESS PSIG S

PO420A S/G B PRESS PSIG 6

PO440A S/G C PRESS PSIG 7

PO483A PRESSURIZER P PSIG 8

PO498A RC SYSTEM P PSIG 9

P0142A CHARGING PRESS PSIG 10 UO482 AVG PZR PRESS PSIG 11 UO483 AVG PZR LEVEL 12 U1118 RX THERMAL POWER MW 13 U1170 AVG T/C TEMP

F 14 AS REQUIRED HOTTEST T/C (QUADRANT 1)

F 15 AS REQUIRED HOTTEST T/C'(QUADRANT 2)

F 16 AS REQUIRED HOTTEST T/C (QUADRANT 3)

F 17 AS REQUIRED HOTTEST T/C (QUADRANT 4)

F 18 UO969 SATURATION MARGIN

F I

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

~. - -

2-ST-11.4 Page 3 of 3 06-12-80 PROCESS COMPUTER TREND BLOCK C COLUMNS ADDRESS PARAMETER UNITS 1

T0003A INCORE T/C

'F 2

T0006A INCORE T/C

'F 3

T0002A INCORE T/C

F a

4 T0005A INCORE T/C

F 5

T0020A INCORE T/C

F 6

T0024A INCORE T/C

F 7

T0022A' INCORE T/C

F 8

T0023A INCORE T/C

F 9

T0045A INCORE T/C

F 10 T0033A INCORE T/C

F 11 T0036A INCORE T/C

'F l

12 T0029A INCORE T/C

F i

i 13 T0030A INCORE T/C

'F i

14 T0046A INCORE T/C

F 15 T0048A INCORE T/C

F 16 T0044A INCORE T/C

'F 17 PO499A RC SYSTEM P PSIG 18 P0484A PRESSURIZER P PSIG 4

r-

2-ST-11.5 Page 1 of 5 06-12-80 CORE POWER DETERMINATION NOTE: This Attachment will be completed by the Reactor Engineer at his discretion.

1.0 PURPOSE The PWRMONT program provides a method for using the movable detector 4

system to obtain a measure of reactor power during natural circulation testing. The program is first normalized to actual reactor power using a steady state calorimetric and single pass map. Single pass maps are then run during natural circulation to measure reactor power.

The PWRMONT package consists of the PWRMONT task and certain modif-ications to the existing Westinghouse PRIORITY SCAN and M/D COMPUTATIONS programs.

Description l

The PWRMONT program uses data generated by the M/C COMPUTATIONS program to calculate reactor power based on the following equation:

5 Calculated Power = (I Ni) x K0864 i=1 Where: Ni = Normalized integral for detector i K0864 = PWRMONT calibration factor (See Section 3 Usage)

In addition to the above calculation, the PWRMONT program retrieve; valves calculated by the M/D COMPUTATIONS programs and outputs them in the format shown on Figure 1.

This format is self-explanatory except the column labled " SCALE". This column indicated the gain setting for each detector and is interpreted as follows:

SCALE GAIN 1

50 MA 2

150 MA 3

500 MA 4

1500 MA 5

5000 MA

2-ST-11.5 Page 2 of 5 06-12-80 Isitials 2.0 Initial Conditions 2.1 All initial conditions for 1-OP-57 have been verified.

2.2 Notify the Shift Supervisor on duty of the impending test and coordinate its performance through him.

3.0 Precaution 3.1 Step 2, Instruction must be performed if the normalized integrals shown on Figure 1 are to be useful.

3.2 The upper and lower limit switch settings for the chosen 10-path locations must be accurate if the axial off-sets shown on Figure 1 are to be useful. These limit switch settings can be verified by observing F/M chart recorders and calculating relative detector location by observing flux depressions at known grid strap locations.

3.3 Do not change the value of K0900 during natural circulation testing except when starting a new test, i.e. K0900 = 0.

NOTE:

If more than 35 passes are taken during natural circulation, K0900 will automatically return to 1 and the PWRMONT program will operate correctly.

3.4 Do not request any movable detector data output via the operator's console during natural circulation testing.

4.0 Instructions 4.1 Load the paper tape containing the PRIORITY SCAN and M/D COMPUTA-TIONS program modifications.

4.2 Update the movable detector normalization constants K0908-K0912 using standard flux mapping procedures by insecting each detector in J-7.

(A common group thimble may be used if location J-7 is not available).

2-ST-11.5 Page 3 of 5 06-12-80 4.0 Instructions (cont.)

Calculate the normalization factors by determining the ratio of each Norm Integral to Detector A as follows:

""f",g*2a

1.0 Norm Factor Det. A

rm In egral B =

Norm Factor Det. B = Norm Integral A Norm Factor Det. C = Norm Integral C

Norm Integral A n egral D =

rm Norm Factor Det. D = Norm Integral A

"" I" "E#8 norm Factor Det. E = Norm Integral A

=

This step should be repeated at an interval prescribed by the Reactor Engineer based on experience with detector drift.

Record Initial Norm constants below:

Det. A K0908 1.0 Det. D K0911 Det. B K0909 Det. E K0912 Det. C K0910 4.3 Choose the 10 path locations for each of the five detectors. These locations should be chosen to give the best overall core power monitoring using available core locations. Select detector gain settings to range recorder traces which perk between 3 and 10 when the detect,r scans the selected thimble.

4.4 Set UOO72 to -1.

This prevents the FQSUREY program from interfer-ing with the PWRMONT program.

4.5 Set K0900 to 0.

This sets the current M/D pass number to 0.

5.6 Set K0864 to 1.0.

This sets the PWRMONT calibration factor to 1.0.

o

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2-ST-11.5 i

Page 4 of 5 06-12-80 4.0 Instructions (cont.)

4.7 Simultaneously initiate a singe pass flux map and a calorimetric.

4.8 Determine new K0864 value as follows:

New (K0854) = Current (K0864) x (Calorimetric Calculated Power)

(PWRMONT Calculated Power)

NOTE:

The PWRMONT calculated power will be output on the utility printer following the single pass map as shown in Firgure 1.

4.9 Repeat Steps 7 and 8 as necessary until the calorimetric power and the PWRMONT power agree to the desired accuracy ( 1% RTP).

4.10 Set K0900 to 0.

This sets the current M/D pass number to 0.

4.11 Initiate single pass maps at will during natural circulation tests to measure reactor power. The movable detectors do not need to be withdrawn between passes.

4.12 The PWRMONT program also puts calculated power into addressable constant U0012. Therefore, this point can be trended if desired.

4.13 Following natural circulation testing, reload the tape containing the original PRIORITY SCAN nad M/D COMPUTATIONS Westinghouse programs.

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2-ST-11 Attachaent 6.5 Page 5 of 5 06-12-80 NORTH ANNA UNIT 2 - M/D POWER MONITORING 15-80 Det Norm Factors:

K0908 K0909 K0910 K0911 K0912 1.000 1.000 1.000 1.000 1.000 CALORIMETRIC CALIB CONST = 2.206 TIME 18:42 PASS NO.

1 CALC PWR 99.376 %

DET THIMBLE SCALE NORM INTEGRAL A0 MD-1 H-03 3

7.486

-3.412 MD-2 C-08 4

10.189

-3.488 MD-3 F-04 4

10.006

-3.041 MD-4 C-12 3

7.319

-11.726 MD-5 G-09 4

10.050 2.452 PASS 5 c.

TIME 18:50 PASS NO.

12 CA!.C PWR 99.498 %

DET THIMBLE SCALE NORM INTEGRAL A0 MD-1 H-03 3

7.485

-3.141 MD-2 C-08 4

10.191

-3.134 MD-3 F-04 4

10.003

-2.731 MD-4 C-12 3

7.371

-10.225 MD-5 G-09 4

10.055 2.639 FIGURE I PWRMONT PROGRAM OUTPUT

.__....a_._.___..~_--.._.

.m 2-ST-11.6 Page 1 of 10 06-12-80

+

ENGINEERED SAFETY FEATURES AND REACTOR PROTECTION MODIDICATIONS During the performance of these tests, modifications will made to the Engineered Safety Features and the Reactor Pretection systems. The systems will operate as specified below.

t A.

All automatic Safety Inja: tion (SI) functions, except reactor trip, will be blocked. A Safety Injection actuation signal will result in the following:

1.

Reactor Trip 2.

Control Room Trip Indication and Alarms B.

Safety Injection actuation can be initiated by manual switch operation.

C.

The High Steam Line Flow Coincident with Low Steam Line Pressure or

~

Low-Low T signal will result from a Low Steam Line Pressure only.

gyg D.

The High Steam Line differential Pressure signal will be blocked.

E.

Containment Spray and acutation system will not be changed.

4 F.

Containment Phase A isolation will not operate automatically.

It can be initiated manually by Phase A manual actuation or Safety Injection manual

-l actuation.

l G.

Phase B isolation system will not be changed.

i H.

Steam Line Isolation will result from any one of the following.

1.

Manual 4

2.

Containment Pressure - Intermediate High-High 3.

Steam Line Pressure Low I.

Feedwater Isolation will result from:

i

1) High-High Steam Generator Water Level.

2) Manual Safety Injection.

3) Reactor trip with low T,y 1

i

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2-ST-11.6 Page 2 of 10 06-12-80 J.

Auxiliary Feedwater Pump start will result from any one of the following.

1.

Station Blackout 2.

Main Feedwater Pump Trip 3.

Steam Genrator Low-Low Level NOTE:

Setpoint changed from 18 percent NR to 5 percent NR 4.

Manual initiation of Safety Injection K.

The following Reactor Trip signals will be blocked.

1.

Overtemperature delta T 2.

Overpower delta T L.

The following Reactor Trip signals will be blocked by the normal P-7 interlock.

1.

Low Primary Coolant Flow 2.

Undervoltage 3.

Underfrequency 4.

Pressurizer Low Pressure 5.

Pressurizer High Level 6.

Turbine Trip Signal M.

The following Reactor Trip signals will be operable at the setpoint specified.

1.

Power Range, Low Range Neutron Flux 7 percent RTP 2.

Intermediate Range, Neutron Flux 7 percent RTP 3.

Steam Generator Water Level 5 percent NR N.

The following Reactor Trip signals will not be changed.

1.

Pressurizer High Pressure 2.

Low Feedwater Flow i

2-ST-11.6 Page 3 of 10 06-12-80 3.

Safety Injection Input 4.

Manual Reactor Trip 5.

Power Range, Neutron Flux High Positive Rate 6.

Power Range, Neutron Flux High Negative Rate 7.

Source Range, Neutron Flux 8.

Power Range, High Range Neutron Flux 0.

Hardware Modifications Initial 1.0 Prepare the required SSPS test boards as follows:

1.1 (6.6 A, F, I J) Remove CR48 from each of two SSPS Universal Boards (6056D21G01). Label each board and record its serial number as follows:

"A313 TEST BOARD - TRAIN A" "A313 TEST BOARD - TRAIN B" 1.2 (6.6, C) Remove CR35, CR36 and CR48 froi.: each of two j

l SSPS Univeral Boards (6056D21G01) and connect a jumper from the anode hole of CR35 to the anode hole of CR36.

Label each board and record its serial number as follows:

"A206 'EST BOARD - TRAIN A" "A206 TEST BOARD - TRAIN B" 1.3 (6.6, D) Remove CR2, CR3, CR8 and CR9 from each cf two SSPS Safeguards Output Board (6056D32G01).

Labe'.

ach board and record its serial number as follows:

"AS16 TEST BOARD - TRAIN A" "A516 TEST BOARD - TRAIN B"

2-ST-11

.6 Page 4 of 10 06-17-80 Initials Remove CR1 and CR7 from each of two SSPS Safeguards Output Boards (6056D32G01). Label each board and record its serial number as follows:

"A517 TEST BOARD - TRAIN A" "A517 TEST BOARD - TRAIN B" 1.4 (6.6, K) Remove CR23, and CR24 from each of two SSPS U.V. Output Board (6058D45G01). Label each board and record its serial number as follows:

" ASIS TEST BOARD - TRAIN A" "A515 TEST BOARD - TRAIN B" 2.0 Place SSPS Train "A" in test as follows:

2.1 Place the " Multiplexer Test" switch for Train "A" in the

" Normal" position. Then, have the Operator close the BYPASS breaker which ps.allels the reactor trip breaker for Train "A".

Confirm this action by verifying the following:

NOTE: The Operator must rack-in the BYPASS breaker prior to closing.

2.1.1 The " General Warning" lamp for the Train "A" illuminates.

2.1.2 The red breaker position indicator "BYA" (for Train A under test) is illuminated on the MCB.

2.1.3 Annunciators IK G-1, "SFGDS PROT SYS TR A TROUBLE,"

actuates.

2.2 On the Output Relay Test Panel, place the MODE SELECTOR switch in the " TEST" position and verify that the "0PERATE" lamp goes off.

-~ ~

_ _ _ _ _ _ ~

2-ST 11.6 Page 5 of 10 06-12-80 Initials 2.3 On the Logic Test Panel, place the INPUT ERROR INHIBIT switch in the " INHIBIT" position.

3.0 Femove the following Train "A" SSPS boards and record their Serial numbers below:

A313 A206 A516 AS17 ASIS 4.0 Install the test boards prepared in Section 1.0 in their apprn-priate slots.

"A313 TEST BOARD - TRAIN A" "A206 TEST BOARD - TRAIN A" "A516 TEST BOARD - TRAIN A" "A517 TEST 30ARD - TRAIN A" "A515 TEST BOARD - TRAIN A" 5.0 Return SSPS Train "A" to service as follows:

5.1 Place the MODE SELECTOR switch to "0PERATE".

5.2 Have the Operator place the following manual block switches for Trains A and B in the " BLOCK" position:

NOTE: Blocks will not be set unless their associated permis-sives are present.

SOURCE RANGE BLOCK & RESET INTERMEDIATE RANGE BLOCK POWER RANGE BLOCK LO S.P.

LO T-AVE SI - A(B) BLOCK & RESET LO PRZ SI - A(B) BLOCK & RESET

=--J 2-ST-11 Attcchment 6.6 Page 6 of 10 06-12-80 Initials 5.3 Place the INPUT ERROR INHIBIT switch to " NORMAL".

5.4 Verify that bot.h Reactor Trip Breakers are closed.

5.5 Have the Operator open and rack out the BYPASS breaker which was closed in Step 2.1.

NOTE: The " General Warning" lamp should go off.

CAUTION:

If the NULTIPLEXER TEST switch will pass through the

" INHIBIT" position in the following step, ensure that there is no " General Warning" for the opposite train.

5.6 Return the MULTIPLEXER TEST switch for Train "A" to the "A" + B" position.

5.7 Verify that Control Room annunciator IK-7 for Train A is extinguished.

6.0 Place SSPS Train "B" in test as follows:

6.1 Place the " Multiplexer Test" switch for Train "A" in the

" Normal" position. Then, have the Operator close the BYPASS breaker which parallels the reactor trip breaker for Train "B".

Confirm this action by verifying the following:

NOTE: The Operator must rack-in the BYPASS breaker prior to closing.

6.1.1 The " General Warning" lamp for train "B" illuminates.

6.1.2 The red breaker position indicator "BYB" (for Train B under test) is illuminated on the MCB.

6.1.3 Annunciators IK G-2, "SFGDS PROT SYS TR B TROUBLE," actuates.

2-ST-11

'.6 Page 7 of 10 06-12-80 Initials 6.2 On the Output Relay Test Panel, place the MODE SELECTOR switch in the " TEST" position and verify that the "0PERATE" lamp goes off.

6.3 On the Logic Test Panel, place the INPUT ERROR INHIBIT switch in the " INHIBIT" position.

7-3 Remove the following Train "B" SSPS boards and record their Serial numbers below:

A313 A206 A516 A517 A515 8.0 Install the test boards prepared in Sectin 1.0 in their appro-priate slots.

"A313 TEST BOARD - TRAIN B" "A206 TEST BOARD - TRAIN B" "A516 TEST BOARD - TRAIN B" "A517 TEST BOARD - TRAIN B" "A515 TEST BOARD - TRAIN B" 9.0 Return SSPS Train "B" to service as follows:

9.1 Place the MODE SELECTOR switch to "0PERATE".

9.2 Have the Operator place the following manual block switches for Trains A and B in the " BLOCK" position:

NOTE: Blocks will not be set unless their associated permis-sives are present.

SOURCE RANGE BLOCK & RESET INTERMEDIATE RANGE BLOCK

'i~T_

2-ST-11.6 Page 8 of 10 06-12-80 Initials POWER RANGE BLOCK LO S.P.

j LO T-AVE SI - A(B) BLOCK & RESET f

LO PRZ SI - A(B) BLOCK & RESET 9.3 Place the INPUT ERROR INHIBIT switch to " NORMAL".

9.4 Verify that both Reactor Trip Breakers are closed.

9.5 Have the Operator open and rack out the BYPASS breaker which was closed in Step 6.0.

NOTE: The " General Warning" lamp should go off.

CAUTION: If the MULTIPLEXER TEST switch will pas through the

" INHIBIT" pesition in the following step, ensure that there is no " General Warning" for the opposite train.

9.6 First return the Multiplexer Test switch for Train "A" to normal. Then return the " Multiplexer Test" switch for Train "A" to the "A" + B" position.

9.7 Verify that Control Room annunciator IK-15 for Train B is extinguished.

10.0 Return the SSPS to normal as follows:

10.1 Place SSPS Train "A" in test in accordance with Steps 2.1 through 2.3.

10.2 Remove the test boards installed in Section 4.0.

10.3 Install the SSPS boards removed in Step 3.0 and record their serial numbers below:

A313 A206 A516 A517 A515 L

l

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~. - -.

2-ST-11.6 Page 9 of 10 06-12-80 Initials 10.4 Return SSPS Train "A" to service in accordance with Section 5.0 10.5 Place SSPS Train "B" in test in accordance with Steps 6.1 through 6.3.

10.6 Remove the test boards installed in Section 8.0.

10.7 Install the SSPS boards removed in Step 7.0 and record their serial numbers below:

A313 A206 A516 i

A517 A515 10.8 Return SSPS Train "B" to service in accordance with Section 9.0.

10.9 Perform 2-PT-36.1 for SSPS Trains "A" and "B".

NOTE:

Insure that the test board modifications are corrected prior to returning these boards to stock.

P.

Setpoint Changes 1.0 Change 18% Steam Generator Lo-Lo trip to 5% by adjusting the Signal Comparator Card from 1.800 VDC trip to 0.500 VDC trip and from 1.900 VDC reset to 0.600 VDC reset.

Signal Comparator Card Procadure LC-474A ICP-P-2-L-474 i

LC-475A ICP-P-2-L-475 LC-476A ICP-P-2-L-476 LC-484A ICP-P-2-L-A84

. -. ~. -. -

2-ST-11 Attcchment 6.6 Page 10 of 10 06-12-80 Initial LC-485A ICP-P-2-L-485 LC-486A ICP-P-2-L-486 LC-494A ICP-P-2-L-494 LC-495A ICP-P-2-L-495 LC-496A ICP-P-2-L-496 2.0 Verify Power Range, Low Range Neutron Flux trip is set at 7 percent RTP.

3.0 Verify Intermediate Range, Neurton Flux trip is set at 7 percent RTP.

4.0 Following Natural Circulation testing or when directed to by the Test Engineer return Steam Generator Lo-Lo level trip from 5% to 18%.

Signal Comparator Card Procedure LC-474A ICP-P-2-L-474 LC-475A ICP-P-2-L-475 LC-476A ICP-P-2-L-476 LC-484A ICP-P-2-L-484 LC-485A ICP-P-2-L-485 LC-486A ICP-P-2-L-486 LC-494A ICP-P-2-L-494 LC-495A ICP-P-2-L-495 LC-496A ICP-P-2-L-496

~

2-ST-11 Attschment 6.7 Page 1 of 2 06-12-80 OPERATIONAL SAFETY CRITERIA During the performance fo these tests, the operator must meet the following set of criteria for operation.

A.

For all tests Primary System Subcooling (T,,t Margin)

> 20*F a.

b.

' Steam Generator Water Level Span

~ 33 percent c.

Pressurizer Water Level (1) With RCP's Running 21 percent Span (2) Natural Criculation 2 Value when RCP's tripped d.

Loop AT 5 65*F e.

T

$ 580 F AVG f.

Core Exit Temperature (highest) 5 610*F g.

Power Range Neutron Flux

< 5 percent RTP h.

Control Bank D

> 100 steps withdrawn B.

Reactor trip and test termination must occur if any of the following conditions are met a.

Primary System Subcooling (T Margin) 5 15*F sat b.

Steam Generator Water Level

< 5 percent Narrow Range Span c.

NIS Power Range, 2 Channels

> 7 percent RTP d.

Pressurizer Water Level 5 17 percent Span or an unexplained decrease of more than 5 percent not concurrent with a T,yg change e.

Any Loop AT

> 65 F

2-ST-11

-.7 Page 2 of 2 06-12-80 f.

T

> 580*F gyg g.

Core Exit Temperature (highest)

> 610*F h.

Uncontrolled rod motion C.

Safety injection must be manually initiated if any of the following conditions are met a.

Primary System Subcooling (T Margin) 5 10*F sat b.

Steam Generator Water Level

< 0 percent Narrow Range Span or Equivalent Wide Range Level c.

Containment Pressure 2 17 psia d.

Pressurizer Water Level

< 10 percent Span or an unexplained decrease of more than 10 percent not concurrent with a T

change AVG e.

Pressurizer Pressure Decreases by 200 psi or more in an unexplained manner Safety injection termination must be in accordance with the termination criteria set forth in the Station Emergency Procedures.

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

2-ST-11

.8 Page 1 of 1 06-12-80 CORE AT WITH NATURAL CIRCUIATION '

ESTIMATED RA"GE Core AT (*F)

Power Level (%)

2-Operating Loops 3-Operating Loops

)

1 10-35 7-36 1 1/2 19-45 13-31 3

26-45 NOTE: These values of core AT reflect an uncertainty of 0.5 core power.

t i

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C 6

2-ST-11.9 Page 1 of 1 06-12-80 TRAINING LOG The following personnel PARTICIPATED in the performance of the test, as defined in 2-SU-1, Attachment 5.6:

Name (print)

The following personnel OBSERVED the performance of this test, as defined in 2-SU-1, Attachment 5.6:

Name (print)

The completed Individual Training Record, 2-SU-1, Attachment 5.6, Attachment A, for each of the above-named individuals has been attached to this procedure.

Shift Supervisor

/

Signature Date l

l

.

ML19312E829

Contents

Text

Dear Mr. Denton:

References:

1.0 Norm Factor Det. A

References:

1.0 Norm Factor Det. A

Navigation menu

ML19312E829

Text

Dear Mr. Denton:

References:

1.0 Norm Factor Det. A

References:

1.0 Norm Factor Det. A

Navigation menu

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