Text

Letter Submitting a Report Which Demonstrates That Tests to Be Conducted During Power Ascension Testing Meet the Intent of Sections D.1.c and D.1.d of Appendix a to Regulatory Guide 1.58
	ML18098A046
Person / Time
Site:	Saint Lucie
Issue date:	04/01/1976
From:	Robert E. Uhrig; Florida Power & Light Co
To:	Boyd R; Office of Nuclear Reactor Regulation
References
	L-76-151
	Download: ML18098A046 (93)
	v • d • e

NRC'FORM 196 (2-76)

V.S. NU~.EAR REGULATORY COMMON NRC DISTRiBUTION For, PART 60 DOC'KET TLRIAL DOCKFT NUM8ER FILE NVMSER Mr Boyd LETTE R ml ORIGINAL CI COP Y DESCRIPTION ONOTORIZED

% UNC LASS IF I E D PROP

'lorida Power

& Light Co Miami, Fla R E Uhrig INPUT FORM ENCLOSURE DATE OF DOCUMENT 4-1-76 DATE RECEIVED

4. 1Z 76 NUMSER OF COPIES RECEIVED one signed'tr trans the following:

Information concerning Preoperational testing per Reg Guihe 1 A.'......

PLANT NAME:

St Lucie SAFETY ASSIGNED AD:

BRANCII CHIEF:

PROJECT MANAGER;

LXC, SST, FOR ACTION/I

~Wn r7 6'

v c.i NFORhlATION ENVIRO "19-7 ASSIGNED AD:

BRANCH CHXEF

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PROJECT kfANAGER:

LIC~ ASST ehf

~LE NRC P

I&Et GOSSICK & STAFF AS'N'E~ER C

KNXGHT SI15lEIL PAMLXCKI INTERNALD ISTR I BUTION BE NARD'PPOLXTO OPERATING REACTORS STELLO OPERATING TECH NKEMLZE ERNST

~AT.LARD SPANGLER SITE TECH GAKIXLL STEPP HULMAN PROJECT MANAGEMENT BOYD P,

COLLINS HOUSTON PETERSON MELTZ HELTEMES SKOVHOLT LPDR ~ F+

~ ci c,e TIC NS ASLB REACTOR SAFETY ROSS NOVAK ROSZTOCZY CHECK AT & I-SALTZMAN RUTBERG EXTERNAL DISTRIBUTION NATL LAB REG. V"IE LA PDR CONSULTANTS EISENHUT SHAO BAER SCHMENCER GRIMES SXTE SAFETY & E ANALYSIS DENTON & MULLER BR OKI VEN NATL LAB ULRXKSON(ORNL)

SITE ANALYSIS VOLLtKR BUNCH J.

COLLINS KREGER CONTROL NUMBER 3G~)

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Q ling CZ FLORIDA POWER 8I LIGHT COMPANY April 1, 1976 L-76-151 Director of Nuclear Reactor Regulation Attention:

Mr. Roger S.

Boyd, Director Division of Project Management U.

S. Nuclear Regulatory Commission Washington, D. C.

20555

Dear Mr. Boyd:

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Re:

St. Lucie Unit 1 Docket. No. 50-335 Preoperational Testing per Re ulator Guide 1.68 Regulatory Guide 1.68 Appendix A Section D.l.c calls for a test demonstrating "plant response to load swings, including response to automatic dispatcher control, if applicable (50%, 100;)."

(Automatic dispatcher control is not applicable to St. Lucie Unit, 1.)

Section, D.l.d calls for a test demonstrating "auto-matic control system checkout steam generator level control, automatic rod control, turbine control (25%)."

tO I

To satisfy the requirements of item B.2 of Enclosure 1 to Facility Operating License DPR-67, Florida Power and Light Company (FPL) hereby submits a report which demonstrates that tests to be con-ducted during power ascension testing meet the intent of sections D.l.c and D.l.d of Appendix A to Regulatory Guide 1.68..

We will satisfy the requirements of Sections D.l.c and D.l.d by performing tests in accordance with revised preoperational test procedure no.

1400084, entitled "Automatic Control System Check-

out, Steam Generator Level Control, CEA Regulating

System, Auto-matic Turbine Control, and Load Swing Test."

In addition, pre-operational test procedure no.

0110090, entitled "10% Load Reduction Turbine Runback Test," will provide further data demonstrating plant response during a load swing.

Our NSSS vendor has recommended

that, due to fuel preconditioning considerations, the performance of these;tests take place after the 100% test plateau has been reached.

Therefore, we do not plan to conduct the tests during the initial ascent to 100% rated power.

It should be noted that, during the initial power ascension, data will be taken every four (4) hours in accordance with preoperational procedure no.

0010180, which is the Power Ascension Sequencinq,,

Document.

This data will demonstrate plant response during tran-sients and normal maneuvering and reveal problems which may be occuring.

In addition, plant control systems are monitored during test. trips scheduled for the initial ascent to 100% power.

HELPING BUILD FLORIDA

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Director of Nuclear Reactor Regulation Attention:

Mr. Roger S.

Boyd Page Two April 1, 1976 Preoperational test no.

1400084 is to be performed at 25%,

50%,

and 90% rated power.

The test demonstrates the automatic capabilities of the CEA regulating

system, the steam generator feedwater control system, and the turbine control syst: em and documents that all three systems give adequate and stable response sponses during steady state and expected transient conditions.

'trip chart recorders are utilized on these and other syste ms so that the plant response to load swings of up to 10% can be analyzed.

Preoperational test no.

0110090 gives us an additional 10% load swing at 80% rated power where brush recorders are used to analyze plant response.

We consider these tests and the consequent data to satisfy Regulatory Guide 1.68 Appendix A sections D.l.c and D.l.d.

Copies of preoperational test procedures

1400084, 0110090, and 0010180 are attached as Attachments 1,

2, and 3, respectively.

Very uly yours, Robert E. Uhrig Vice President REU:MAS:sb cc:

Mr. Norman C. Moseley (w/o attachments)

Jack R.

Newman, Esquire (w/o attachments)

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FLORIDA POWER GN LXGflT COMPANY

'T.

LUCIE PLANT UNIT (Il T

'PREOPEIU\\TYOÃIIL TENT PROCEDURE RO.

0010180 REVISION 0

1.

TITL'E: POWER ASCENSION SEQUENCING DOCUMENT Poorer Resources (R.

H. Cantex)

Feb.

11 76 3.

REVIEWED BY:

A 4.

SUBCOMMITTEE REVIEW BY:

5A REVIEIIED BY FRG OII:

~~ANANNA~N~A FOR 19 19+~

6.

APPROVED BY:

7.

REVXSION REVIEWED

. Y FRG ON:

19 8.

APPROVED BY:

9.

TEST CONDUCTED BY:

PLANT MANAGER0.

RESULTS REVIEWED BY:

FOR

'll.

TEST RESULTS REVXEWED BY:

12.

TEST RESULTS REVIEWED BY FRG, DEFICIENCIES CORRECTED, AND ACCEPTANCE RECO~AH KNDED 19 13.

- RESULTS ACCEPTED AtiD APPROVED BY:

Plant Manager 19 THIS DOCUMENT IS NOT CONTROLLED. BEFORE USE, VERIFY INFORMATIIIN WITH A CONTROLLED DOCUMENT FLORIDA POWER AND LIGHT CO.

POWER RESOURCES ST. LUCIE PLANT DATE VERIFIED DATE VERIFIED DATE VERIFIED DATE VERIFIED DATE VERIFIED DATE VERIFIED INITIAI INITIAI-INRIAI INIIIAI

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f.A PLORIDA POWER

& LIGHT COMPANY ST. LUCIE PLANT UNIT NO.

1 PREOPERATIONAL TEST PROCEDURE TRANSMITTAL Signature below signifies receipt of draft/issue/completed copy of preoperational procedure number:

0010180 REV 0 titled:

POWER ASCENSION SE UENCING DOCUMENT Por Ebasco Date For CE Date Por Westinghouse Date THIS DOCUMENT IS NOT CONTROLLED. BEFORE USE, VERIFY INFORMATION WITH A CONTROLLED DOCUMENT FLORlDA POWER AND LlGHT CO.

POWER RESOURCES ST. LUCIE PLANT DATE VERIFIED DATE VERIFIEO OA'IE VERIFIED DATE VERIFIED DATE VERIFIEO DA'IE VERIFIED INITIAI INITIAL INITIAI It(lTIAI INITIAL INITIAI Transmitted By'-

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Title:

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FLORIDA POWER

& L'IGHT ST. LUCIE PLANT UNIT PREOPERATIONAL TEST PROCED A

Page 1 of 24 Revision 0

,[J)LIPMlIIIIIA'All/IML'f NO.THfA DOCUMENT 'IS NOT CONTROLLED. BEFORE USE,

~EARP

'6.'I $

T Y/ITH A CONTROLLED DOGUh1ENT

'R AND. LIGHT'CO.

POICIJER RESOURCES ST. LUCIE PLANT POWER ASCENSION SEQUENCING DOCUMENT 2.0

~Pur oee:

-The purpose of this procedure is to prov from low power to full power while obtai design parameters and demonstrate confor INITIAL INITIAI IIIITIAI IIIITIAL Sa1y-PP+ress-yexSarmanee-det 8%8-veri DATE VERIFIED DATE VERIFIED DATE VERIFIED DATE VERIFIED ihgE glUU5HD ance wx.

x ec naca Specifications.

It also demonstrates with reasonable assurance that the plant is capable of withstanding the accidents and transients analyzed in the FSAR.

3. 0

References:

3.1 Florida Power

& Light Company', St. Lucie Plant Unit 81 Final Safety Analysis Report (FSAR) 3.2 Standard Tech Specs App.

A&B St. Lucie Unit 81 3.3 Preoperationel Test Procedures SteamBypass Valve Test preop'//0810080

,Main Generator Excitation System Initial Operation preop 80910085 Turbine Overspeed Trip Test preop 82100087 Simulated CEA Ejection Test '50% Po~er preop I/0110087 Generator Trip with Shutdown'utside Control Room preop f/1400093 20% Power Trip

& Auto Transfer Test preop I/0910081 Partial Loss of Flow preop I/0120081 Power Defect Measurement - preop I'I3200084 Total Loss of Flow/Natural Recirc.

T'est preop 80120084 Loss of Offsite Power - preop

//2100091 Secondary Sampling Syst. Initial Startup

& Funct.Test preop

/I1730080 Generator Trip - preop II2100089 Turbine Trip preop I/2100090 Automatic Control System Checkout preop I'/1400084 Static CEA Drop Test preop

//0110088 Dynamic CEA Tnsertion Test preop 80110089

. 10% Load Reduction - Turbine Runback Test preop

//0110090 Turbine Generator/NSSS Acceptance Run-preop II2100082 Power Range Sub-channel calibration preop:IlI3200080 3.4 Operating Procedures Nuclear

& QT Power Calibration OP I'I1200051 Reactor Startup OP 80030122 Load Follow Guidelines. - OP 80030123 Calibration of Fixed Incore Detector Alarm Setpoints OP 83200050 Incore-Excore Flux Monitor Correlation iI1200021 At Power Surveillance of Moderator Temperature Coefficient OP 83200057 Fast Recovery to Criticality Following a Reactor Trip OP 80030220 Effluent Monitor Tests C77 A

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Revision 0

PREOPERATIONAL TEST PROCEDURE NO.

0010180 POWER ASCENSION SEQU'ENCINC DOClPiENT

3. 0 Ref erences:

(Cont. )

3.5 Chemical and Radiochemical Analysis, preop

//3400081 3;6 Radiation Survey and Shielding Effectiveness, preop 83300081 4.1 Low power physics testing has been successfully completed as defined by Facility Review Group (FRG).

Verified by Date

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. -. ".'4:.2.-'.;,9."iq.,Silled,ta capacity. or: ma/cup-,is"gn progress Verified by Date 4.3 Holdup tanks are at minimum level or processing is in progress in preparation for receiving large quantities of liquid waste due to borations and dilutions.

Verified by 'ate

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Page 3 of'4 Revision 0

PREOPERATIONAL TEST PROCEDURE NO.

0010180 ONER ASCENSION SEQUENCING DOCE1ENT

5. 0 Instrumentation:

As specified in appendices to this procedure, pre-start check off list, and the minimum instrumentation list as applicable.

NOTE:

Prior to performing any appendix, verify that the instrumentation section is signed off.

'"'..".': ". 6;0 " Relapsed S s'tern"Status':"

'".-':.: '-"'.-":~: ":.",-'".'":.'.".-"'.':.",':. ").

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.::"'-'.1 6.2 The reactor is critical with CEDS in manual control made All CEA groups are full out with the exception oi group 7 controlling.

Power level is.less than 10

.% power, as seen by the WR.log,channel.s,.

Verified by Date

'I RCS temperature is being maintained at 532Fby RCP heat and operation of turbine bypass valves or atmospheric dump valves, Verified by Date 6.3 6.4 Pressurizer pressure control is maintaining RCS pressure at 2250 psia Verified by Pressurizer level control is maintaining normal level.

Date Verified by Date 6.5 Steam generator level is being maintained within the normal operating band.

Verified by Date

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PREOPERATIONAL TEST, PROCEDURE NO.

0010180 POWER ASCENSION SEQUENCING,DOCÃfENT 7.0 S ecial 1faterials and E ui ment:

As specified in appendices to this procedure.

8.0 Tem orar Connections:

As specified, in appendices,to,this.

procedure..'...

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9.0 Limits'and Precautions:

'"'.1 As spdcified in appendices to this procedure, applicable operating procedures

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9.2'teps of this procedure are to be'performed in order except as noted.>

Chemical and Radiochemical analysis and radiation and shielding effectiveness, and APD and SA baseline monitoring may be performed at any time during the specified plateaus.

9.3 Checks for. unexpected radioactivity in process systems and effluents shall be made in accordance with chemistry procedures throughout power ascension test program.

9.4 RCS leakage shall be monitored in accordance with tech specs throughout power ascension test program.

9 5

Power, level increases should be made in accordance with the following guidelines:

Category I*- Initial increase a) All rods out (ARO) b)

by boration/dilution control c) <3%/hour instantaneous (except during turbine roll)

<10%/day average Category II Subsequent increases a)

Group 7 rods 69 inches "b) <10%/hour instantaneous c) continuous operation at or above that power for a nominal 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .(24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months may be reduced with concurrence of CE

& FP&L)

Power level increase shall not exceed the limits of OP 0030123 Load Follow Guidelines.

9.6 General instrument response checks shall be made during initial increases in power.

(Using App. A & 3)

Deviations to this order may be made with approval of the FRG,

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PREOPERATIONAL 'I'EST PROCEDURE NO. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCE1ENT 10.0 Acce tance Criteria:

10.1 As specified in appendices to this procedure.

FSAR >al<<s <<

FQ (2.71) and FAH (2.02) are not exceeded (Step 12.61)

""' "ll.0 'Records 'Re uired:

'1.1 A copy of this procedure and all appendices completed during this test, with each sign-off initialed and dated by a Florida Power

.& Light Company designated witness shall be retained in the plant.,

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I Page 6 of 24 PREOPERATIONAL TES

T. PROCEDURE

NO. 0010180, REV.,O POWER ASCENSION SEQUENCING DOCUMENT NOTE 1:

Data should be taken IAW Appendix A & Appendix 3 every four (4) hours throughout this procedure while the reactor is at power.

'.",,4",<'".'."i'".",..":

NOTE"'.2!."All'"power~"'levels.ment'i'on'edare"react'or".power"'unlesh~o'ther'wise,';-'.""'oted.

NOTE 3:

Special test exceptions 3.10.1 3.10.5 may be invoked for the foglowing technical soecifications:

3.'1".3.i '

'.1.3.5 3.1.3.6 3.2.2

3. 2.3 NOTE 4:

The following abbreviations ar'e used in the procedure.

IAW in accordance with ARO all rods out HZP hot zero power OP Operating procedure APD amplitude probability distribution SA spectrum analysis NZC moderator temperature coefficient PDIL power dependent insertion limit SAF shape annealing f'actor IVM internal vibration monitoring (inclu'des APD

& SA)

ASI axial shape index NPS Nuclear Plant Supervisor FQ Nuclear heat flux factor F

H hot channel factor

~H NOTE 5:

Increasing or decreasing turbine load should be done IAW OP 0030124 Turbine Startup - Zero to Full Load.

NOTE 6:,

During initial ascensions to power maximum use should be made of Turbine Load Limit Control.

NOTE 7:

Throughout this procedure power levels are nominal + 3%, pressures are nominal + 15 psi, temperatures nominal +,2 F.

Once an initial value is reached within these ranges, every effort should be made to remain at that initial value.

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PREOPERATIONAL TEST PROCEDURE NO. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCUMENT 12.0 Detailed Procedure:

12.1=

Increase power to a nominal 5/ IAW OP 0030123 and do radiation survey and shielding effectiveness IAW Preop 3300081.

Verified by Sate

'2.2 Commence increasing power to a nominal 14/

IAW OP 0030123.

During this increase, perform turbine bypass valve test IAW

,.Preop

.0810080,.

NOTE:

During this increase, use"Appendix A

..,.and B;.for'.instrument..checks to"determine adequate "inst'. r'esponse.

Verified by Date 12.3 Start up turbine IAW OP 0030124 Turbine Start up Zero to Full Load take date XAW Preop 210086 Xnitial Turbine Roll 9 1800 rpm.

Verified by Date

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12.4 Hold power at 14/ and perform the following tests:

12.4.1 Main Generator Excitation System initial operation IAW Preop 0910085.

Verified by

~Date 12.4.2 Turbine Overspeed Trip Test IAW Preop 2100087.

Verified by Date NOTE:

In order to achieve 90 MWe on the generator for the 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .run called for in 4.1 of Preop

2100087, the reactor power may have to be increased.

If this is the case, then immediately prior to performing overspeed trip, decrease reactor power to <15/ as read on 3 out of 4 channels on the RPS.

This is because if 2 channels read >15/

power on the RPS',

a turbine trip will cause a

reactor trip.

Care should be taken to avoid this situation.

12.5 Put turbine back on the line IAW OP 0030124.

Verified by Date 12.6 Increase power to 20/ IAW OP 0030123.

Verified by Date

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age 8 of 24 PREOPERATIONAL TFST PROCEDURE NO. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCUHENT 12.0 Detailed Procedure:

(cont.)

12.7 Hold power at 20% and perform the following:

12.7.1 Calorimetric using DDPS or.

OP 3200020 Primary System Manual Calorimetric at beginning and end of hold.

Verified by End

.,, Verified by

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12.7'.'2

'Nuclear and hT cal'ibrat'ion" IAW'OP

'and end':of"hold.

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~'ateDate 120005'1 at b'eginnin'g "'

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Begin End Verified by Verified by Date Date 12.7.3 Snapshot log IAW of hold.

at beginning and end Begin Verified by Date End Verified b Date 12.7.4 Chemical and Radiochemical analysis IAW Preop 3400081.

Verified by Date 12.7.5 Radiation survey and shielding effectiveness IAW

'reop 3300081.

Verified by 12.7.6 APD.and SA baseline monitoring.

Verified by Date 12.7.7 Establish equilibrium Xenon and perform Preop 3200080 Power Range Sub-channel Calibration.

Verified by Date NOTE:

,Take end data called for in 12.7.1, 12.7.2 and 12.7.3 at this point..

12.8 Trip reactor IAW Preop 0910081 20% Power Trip and Auto Transfer Test.

Verified by Date

e age 9 of 24 PREOPERATIONAT. TEST PROCEDURE NO. 0010180, REV 0 POWER ASCENSION. SEQUENCING DOCUHENT 12.0 Detailed Procedure:

(cont.)

12.9 After trip and before returning to critical perform preliminary adjustment of incore alarm setpoints IAW OP 3200050 (Use snap-shot log from 12.7.3).

Verified, by Date 12", 10 Return to critical, HZP, IAW OP 0030122 Reactor Startup.

Verified by Date.

12.11 Return to 20% power IAW bP 0030123 (Category'II of Section 9.5

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t Verified by Date ERG approval to ascent to 50%.

Verified by Date 12.12 Increase power to 30% IAW OP 0030123 (Category I of Section 9.5 of this procedure).

Verified by Date 12.13 Hold power at 30% to satisfy Section 9.5 of this procedure and perform the following at the beginning and end of hold:

'I 12.13.1 Calorimetric using DDPS or OP 3200020 Begin End

.Verified by Verified by Date Date 12.13.2 Nuclear and AT power calibration IAW 1200051.

Begin End 12.13.3 Snapshot log IAW Begin End Verified by Verified by Verified by Verified by Date Date I

Date Date 12.14 Increase power to 40% IAW OP 0030123 of this procedure).

Verified by (Category I of Section 9.5 Date

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PREOPERATIONAL TEST PROCEDURE NO.. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCIRKNT 12.0 Detailed Procedure:

(cont.)

12.15 Hold power at 40% to satisfy Section 9.5 of this procedure and perform-the following at the beginning and end of hold.

.-=.'.12..15,1 Ca3orjmetric using~DDPS'!ox'OP."3200020'~.

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Begin Verified by Date End Ve'rified by Date 12.15.2 Nuclear and AT power calibration 'IAW-OP'1200051.'","Begs

'" "Veiified by'

'ate'nd 12.15.3 Snapshot log IAW Begin Verified by Verified by Date Date End Verified by Date 12.16 Increase power to 50% IAW OP 0030123 (Category I of Section 9.5 of this procedure).

Verified by Date 12.17 Hold power at 50% and perform the following:/

12.17.1

. Calorimetric using DDPS (if available) and OP 3200020 at beginning and end of hold.

Begin Verified by Date End Verified by Date t

12.17.2 Nuclear and AT power calibration IAW OP 1200051 at beginning and end of hold.

Begin End Verified by Verified by

=

Date Date 12.17.3 Snapsho't log IAW hold.

at beginning and end of Begin End Verified by Verified by Date Date

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Page ll of 24 PREOPERATIONAL TEST PROCEDURE NO, 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCUHENT 12.0 Detailed Procedure:

(cont.)

12.17 (cont.)

12.17.4 Radiation survey and shielding effectiveness

.IAW Preop 3300081." ":

Verified by Date

12. 17. 5 "12.17. 6 Chemical and radiochemical analysis IAW Preop 3400081.

VerifXed by

Date'"'

Reset incore alarm setpoints IAW OP 3200050 (Use snap-shot log taken at beginning of 50% hold).

Verified By Date 12.17.7 Calculate total radial peaking factor (Fr) IAW OP 3200054 using snapshot log taken at beginning of 50% hold.

Verified by Date 12.17.8 APD and SA base line monitoring.

Verified by Date 12.17.9 Establish equilibrium Xenon concentration

& distribution and induce free Xenon oscillation to measure SAF's IAW preop Verified by Date 12.17.10 Input measured SAF's (from 12.17.9) into the NIS IAW Preop 3200080.

Verified by Date 12.17.11 Dilute group 7 rods to 100 + 3 inches while maintaining reactor power constant.

Verified by Date 12.17.12 Establish equilibrium Xenon concentration and distribution for measurement of MTC.

Verified by Date

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PREOPERATIONAL TEST PROCEDURE NO. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCUMENT 12.0 Detailed Procedure:

(cont.)

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'I 12.17 (Cont.)

12.17.13 Perform at power determination of MTC and power

'coefficient',IAW.

OP,3200051."'erified by Date 12.17.14 Maintain power constant and dilute group 7 to

" 100/ PDIL,- establish equilibrium Xenon and"perform simulated.

CEA 'e'jection test" IAW'Preop 0110087.'erifi'ed"by Date 12.17.15 Borate group 7 to ARO while maintaining 'reactor power constant.

Verified by Date NOTE:

At this point, take end data called for in 12.17.1, 12.17.2 and 12.17.3.

12.17.16 Perform generator trip with shutdown outside control room IAW Preop 1400093.

Verified by Date 12.18 Return to critical, HZP, IAW OP 0030122 Verified by Date 12.19 Return to 50% power IAW OP 0030123 (Category II of Section 9.5 of this procedure.

Verified by Date FRG approval to ascend to 80%.

Verified by Date 12.20 Increase power to 60% IAW OP 0030123 (Category I of Section 9.5 of this procedure).

Verified by Date

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Page 13 of 24 PREOPERATIONAL'PROCEDURE NO. 0010180, 'REV.'

POWER ASCENSION SEQUENCING DOC!MENT

12. 0 Detailed Procedure:

(cont.)

12.21 Hold power at 60% to satisfy Section 9.5 of this procedure and perform the following at beginning and end of hold.

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12.21.1 Calo'rimetric using DDPS or'P3200020.'egin Verified by Date

.,.3.2.21.2

. Nuclear and AT Begin

,Verified by Date J'

power calibration IAH OP 1200051....

Verified by

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Date End Verified by 12.21.3 Snapshot log IAW Date Begin End Verified by Verified by Date Date 12.22 Increase power to 70% IAM OP 0030123 (Category I of Section 9.5 of this procedure).

Verified by 12.23 Perform APP A of Preop 0110090 10% Load Reduction Runback Test at a nominal 70% Power.

- Turbine Verified by Date 12.24 Hold power at 70% to satisfy section 9.5 of this procedure and perform the following at the beginning and end of hold.

12.24.1 Calorimetric using DDPS or OP 3200020 Begin End Verified Verified Date Date 12.24.2 Nuclear and AT power calibration IAM of 1200051, Begin End Verified Verified Date Date

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Page 14 of 24 PREOPERATIONAL PROCEDURE NO. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCEKNT 12.0 Detailed Procedure:

(cont.)

12.24 (cont.)

..:'.12.,24:,3

': Snapshot-1'og

'IAM..'".'.:: "'.

Verified by 5:

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'- 12;25 Commehceincreasirig':power

'to 80% IAM 003'0123(Cat'egory"I'of

, Section,9.5. of this procedure)'.

At 75%, perform turbine control.-,

valve tests IAN'ection 8.1 of Preop 0030150.

Verified by 12.26 Hold power at 80% and perform the following:

NOTE: The 80% plateau has one scheduled trip (partial loss of flow test preop 0120081).

If no inadvertent trips occur at the 80% plateau then Specil Test Procedure 0700080A S/G Feedwater Hammer Test shall be performed following the scheduled trip. If any unscheduled trip occurs at the 80% plateau, the NPS shall determine if conditions enable the performance of the water hammer test.

If so, it will be done at that time and a power defect test shall be done following the partial loss of flow trip.

12.26.1 Calorimetric using DDPS or OP 3200020 at beginning and end of hold.

Begin Verified by Date End Verified by Date 12.26.2 Nuclear and AT power calibration at beginning and end of hold.

Begin Verified by Date End Verified by Date 12.26.3 Snapshot log IAW hold.

at beginning and end of Begin Verified"by Date End Verified by Date

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Page 15 of PREOPERATIONAL PROCEDURE NO. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCEKNT 12.0 Detailed Procedure:

(cont.)

12.26.4 Chemica1 and radiochemical analysis IAW Preop 3400081.

Verified by 12.26.5 APD

& SA base line monitoring Verified.by

.i,,:..

Date.

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l NOTE: If water hammer test has been performed go to step

'2'.26.6 If water hammer test has cot"been'erformed',"

go to 12.26.7.

Ensure end data of 12.26.1, 12.26.2, and 12.26.3 ha-been taken prior to trip.

12. 26. 6 Establish equilibrium Xenon concentration in preparation for power defect measurement and 'prepare for. rapid return to critical IAW 0030220.

Verified by Date 12.26.7 Perform partial loss of flow IAW Preop 0120081.

Verified by Date NOTE: If water hammer test has been performed go to 12.26.8 followed by 12.28.

If water hammer test has not been performed go to 12.26.9, followed by 12.27.

12.26.8 Perform rapid return to critical IAW 0030220 and perform power defect measurement IAW Preop 0120081.

Verified by Date 12.26.9 Perform S/G water hammer test IAW Special. Test Procedure IAW 0700080 A.

Verified by 12.27 Return to critical HZP IAW OP 0030122.

Date Verified by Date

I I

I

V'

~

~',,age 16 of 24 PREOPERATIONAL PROCEDURE NO, 0010180 q

REV, 0

POWER ASCENSION SEQUENCING DOCUMENT 12.0Detailed Procedure'.

(cont.)

12:28 Return to 40%1AW OP 80030123 (cat. II of sect.

9.5).

Verified by Date

"" 3.'2.'29'e'r'form",to'th1'-loss'f"'flow/natura1"'"ci'rc".: ':t:e'st=XAW 'p'reop'f012008'4".':,

Verified by Date 12..30 Return to critical and raise power to 20% (cat.

XX of sect, 9,5)

Verified by Date H'

~

.12..31 perform loss. of off-site power IAW Preop

<~2100091 12.32 Return to critical HZP, IAWOPII0030122.

FRG approval to ascend )

98%.

Verified by Verified by 12.33 Return to 80% in accordance with OP //0030123 (cat XI of sect.

9.5).

Verified by Da te NOTE:

Prior to reaching 85% reinstate tech specs

.suspended in Not e 3.

12,"3p Increase power to 90%

XAW OP /I0030123 (cat I o. 'sect.

9.5)

Verified by Date 4

12~35 Hold power at 90%" and perform the following at the beginning and end,of hold:

12.35.1 Calorimetric using DDPS or OP tI of hold.

Begin Verified by End Verified by 12.35.2 Nuclear 6 hT power calibration IAW OP /I1200051.

Begin

, Verified by End Verified by at beginning and end Date Date Date Date 12,35'

'Snapshot log IAW Begin End Verified by Verified by Date Date W

12.q6. Check ASI calibration XAW Op //1200021 and incore alarm setpoints

'OP f/3200050.

Verified by Date

C l

~ 'o I

~,

i'

~

Page 17 of 24 PREOPERATIONAL PROCEDURE NO. 0010180, REV.

0 POWER ASCENSION SEQUENCING DOCUMENT 12.0 Detailed Procedure (cont.)

12. 37 Increase power 98% (cat I. sect.

9.5).

Verified 'by;.

~

Date.:

~

r

12. 38'old power >

98%

and perform the following at the begiPning and end of hold:

...,,....,,...,12. 38. 1'Calorimetr'ic.using:.DDPS..or, OP. C...

.:,. at,,beginning,and:.end of hold.'Begin

" '., *;." 'Verified'by '::

.. '. '- '.;.Date End

~

Verified by Date 12 3822 Nuclear

& ZLT pover calibration IAH OP //1200051.

Begin Verified by End Verified by.

Date Date 12.38,3 Snapshot log

, IAg Begin End Verified by Verified by Date Date Verified by 34 Date

12. 40 Perform radiation survey '& shielding effectiveness IAHpreo~~i~.

Verified by Date

12. 4j Effluent monitors testing MV chemistry procedureo.

Verified by Date 12.

42-Baseline monitoring for APD and SA.

Verified by Date 12.43 Maintain power const.

and dilute group 7 rods into 100 + 3 inches in preparation for ETC measurement IAM Step 8.1 thru 8.4 of OP 3200051.

Verified by Date 12.44 Establish equilibrium Xenon concentration and distribution in preparation for for MTC and power coefficient measurement.

NOTE:

This vill take approximately 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Verified by Date 12.45 Perform MTC Test and power coefficient measurement IAM OP 3200051.

Verified by Date

t

~

Page 18 of 24 PREOPERATIONAL TEST PROCEDURE NO. 0010180,

REV, 0

POWER ASCENSION SEQUENCING DOCRKNT 12.0 Detailed Procedure:

(cont.)

12.46 Borate ARO while maintaining reactor power constant.

Verified by Date

'2.'4'7" prepare 'for rapid'r'etu'rn:to'*cr'i'ticaX 'for poeer:def'act Xenon follow test,:..

IAW OP r'/0030220.

Verified by Date NOTE:

Take end data 'of 12;38.'l, 12.38.2 and 12.38;3 at this'oint.'2.

48 Perform turbine trip IAW preop 82100090.

Verified by Date

12. 49 Perform rapid return to critical, HZP IAW OP Verified by Date Verified by 12, 51 Return power 2 98% IAW OP g0030123Verified by Date Date 12 52Perform generator trip IAW 82100089.

NOTE: This test may be performed out of sequence.

Verified by Date 12.53 Return to critical, HZP, IAW OP 80030122 Verified by Date 12..54 Return to 25% Ig< OP 80030123.

Verified by Date 12,55'erform automatic control system checkout IAW Verified by preop f31400084.

Date

12. ~ Return to 50% power IAW OP 80030123.

Verified by Date

12. 57 Establish equilibrium xenon.

Verified by 12, 58 Perform static CEA drop test IAW preop 80110088::

Verified by Date Date

~,

0 Page 19 or 24 PREOPERATIONAL TEST PROCEDURE Np.

0010180,REV.

0 POWER ASCENSION SEQUENCING DOCUMENT 12.0 Detailed Procedure:

(cont.)

12; 59 Perform dynamic CEAinsertion test IAW preop

/>0110089.

Verified by 12.. 60.,Return.to

. 85% IA" 0P'<~~00;012~..."

~ ~....,,. "..., '....,.

Date 12;61 Analyze snapshot logs between steps 12.15.3 and 12.35.3 inclusive to verify FSAR limiting valves for Fp and FAH.

~ "%

~

~ '

Verifie'd by

'Date 12.62 Perform lp% Load Reduction Turbine Runback test IAW preop 801.:CC".C.

Verified by Date 12.63 Return to 98%

IAW OP //0030123.

Verifi'ed by Date 12.64 Perform turbine generator/NSSS acceptance/run IAW preop ij2100082.

Verified by Date

~ 5

~

PREOPERATXONAL TEST PROCEDURE NO.

0010180 0

Page 20 Revision 0

13.0 Deviations from Procedure:

'a l

P V

I I'I' y

I

'REOPERATlONAL TEST PROCEDURE NO. 0010180 R'evis'ion 0

~

APPENDIX "A" LINEAR PO>1ER RANGE SAFETY HETERS

~

CEA POSITION Channel Sub A Heter Reading 0/

A Sub B

c/r Sub A c/

~ ~

~

. Sub" B'"""

Sub A Sub B.

0/

c Sub A Sub'.

fo 7'

~.'.c ( '

0 0

LINEAR POWER RANGE CONTROL HETERS Sub A c/r P2 Sub B

Sub A Sub B

/0 0/

0/

T-avg Calorimetric Generator Power c/r TR-1121 OF oF Chemical Boron Conc.

Time

& Date of Analysis Boronometer Boron Conc.

PPH PPM Snapshot ID No.

R.P.S.Readings Time AT Power Nuclear Power T-hot T-cold Date ASI Internal ASI External Verified by

r

, J

~

R P

APJ'ENDXiY f3 Page 22 of 2/t i">SS Tf'EST,J)ATA Rf'COftf)

Sfte+t

$ of 34 DATE:

TXiifL':

Channel Lover

(%) (lfeter I,over)

U oec

(%

(heter U

er)

(T Pfm /

{DVf)

NIJC Pt~f; (/) '{f)rif, Teold (oP)'D'Pif)

Tf>ot (oP) (D~~f)

ASX

(

Y )

NIJC PHR Pot:

Set:

/.T PHR Pot Set W-.DE R:eCH Cb nnels CONTROI. CHANNEI" SUBCHANNEL Left (lover)

C-A tC Q

e/

Rough t {upper)

<</

/<<

VCT TBIiP {TX-222S) op LETDOMR PLQti (PX-R?0?

CPN PRESSURIZER

.PRHSS) UR~Esia PX-1102A PX-1102ff PI-l102C PX-1102D VCT LEVEL (LXC-$226)

CHAI<GING PLOII (PX-2212

'1"i4/J.O~~si a PX-1102A PX-11028 PX-1102C PX-1102D

<</

GPH PRHSSURI7iHR I HVEI? /

I.R-1110 LIC-lllOX LXC-.L3,0Y RCP CURRiiirr, rmPeree Ai~fff 101 Alllf 105 AMI 107 Alfff 113

~

0 L

t APPEADXX" 8 '

SSS TJ.'iT J)A'J'A 1'I',CORI)

Sheet 2 of 3 (Cont'd)

J)ate STEAlf GEJ"ERATOR DIPPEREdTIAI, PRESSURJ'.

g>sid STEAN GEP<ERATOR lA STEAff GJ'.NERATOR 18 RCS PLOW

.P....PJ)X-1103,A

. PDl-1101A

. PDX-1101A....

-'.':,.i-;;:; ';":PDI?1106"-':::".';:-". --.: ':.:: -:IPDI-,I1'?02k'!.'-:::::.":X 0::i'"':::..':::PDI-'1/0'l0

-.i";:::Ã-'.1':"'DI-'11010

'DI-11010

'DI-1101C'DX-1101D PDX-1101D PDX-1101D

?I-"1111X '; ':

OP

?1-11212 p

TX-1111Y op TX-1121Y Op Tl-ll028 TX-1102C TI-1102D Op op h, g TX-11028 TX-ll020 TX-1102D RCS,TJMERATURE, P

J Tff j...Loop lA....,,

Tn

, LqoI7 18

'" TX-il?O2A'.'"": 'i' 'X-'liO2A' '

Qp op oy TR-1115 Tf(-1125 Tcold - I.oop 1A2 0

TX-1102A T3'-l.1020 cold J.ooP 1A1 TX-11028 TX-1102D op op Loop 181 TX-1102A TI-jj 020 Scold Loop 182 TX-11028 TX-1102D op op op ffalceup Hater Plo?r Totalizer (PQX-2210X)

Boric Acid Plow Totalizer (I'QX-2210Y)

Process Radiation Monitor (RR-2202)

Boron Concentration Recorder (AR-2203)

Boron Concentration (I,AB)

Time of Sample Gal.

COJJPUTER POILUS:

Gal.

Calorimetric CPff Power pm pm JME CEA GROUP POSXTXON ItiCJIHS-I'XTHDRAMAT.

7 2

3 7

5 Pl 7 I2 6

7 7

~ CHA7-1, CEA 7-59

~

~,,

~,

e APPilNDIY '

l'eSSS TI'.ST DATA lit'; ORD (Collt d)

Page 24 of 24 Sheet 3 of 3 Date E'1-3013A PX.-8023A LX-9013A LI-9023A P1-803.38 PX-80238 LX-901313 Ll-90238 Pi-8013C,..."...,.

~..,-. PI-8033C LX-9013C LX-9023C PX-9013D PX-9023D lX-9013D ':

LX-90230 '

I

""""."""SCBA"8tecum.'Fl'hr'PT,'8-"lA),: ':"';::i" '.".,]bIt'1ii,;."~'5Gl;3",;85 eaiii:,Zl'o'y,.(E'1-".08 -';3:8-'."-.'".. ".: -"'.""." 3b'/hj-;;;:

SG1A )'eed glom (E"X-09-1A)

'bjlir SG18 I'eed Eplov e(r"I-09-18 """ '

'1b'/'hd'"'GXA Peed Coarxol Valve {PXC-9011 SG Peedearer Temp (TE-09-SA) oP SG18 Peed Control.Valve (L 1C-9021)

SG Peedvater Press (O'I-

)

psi Time Completed Verified by I~

~

~.

SUBCO~iMXTTHLN RHVXHH BY:

AUTOMATIC CONTROL SYSTEM CHECKOUT, STEQf GENERATOR LEVEL CONTROL, CEA 1

TXTLE:

REGULATENG SYS'g l AUTOMATIC TURBINE CONTROL & LOAD SlGNG TEST Power Resources 2.

PREPARED BY:

'.Sept.

17 lg75 rHVXEt?ED BY:~~

~r" for CE

>9r~

A4u'97$

5.

RHVXH!KD BY I'NSC ON:

6.

'(ZPROVHD BY:

/ ~

a l9+~

V..6 19 7Q

? ~

REVISION RiVXHHED BY, RG ~ ON:

~

APPROVED BY:.

g

. (r"

\\

TEST CO?8)UCTED B

>Pi/KP Plant }Tanatat I J///4+@ /

19+a 10.

RESULTS REVXHITED BY:

for CE 1la S

P V~r"~

W'2

'EST RESULTS RHVXTNHD 33Y.RG D 'PIC ENCXES CORRECTED>

AND ACCEPTANCE lLECOiCKNDHD:

13.

RESULTS ACCEPTED A%) APPROVED BY:

"- Plane

?1anagez

'HIS DOCUMENT 1S NOT CONTROLLED. BEFORE USE, VERIFY INFORMATION WITN A*CONTROLLED DOCUMENT FLORIDA POWER AND LIGHT CO.

POWER RESOURCES ST. LUCIE PlANT BP NIMPMATltIIIIgl.y

~

l DATE VERIFIED DAZE VERIFIED DATE VERIFIED DATE VERIFIED DATE VERIFIED DATE VERIFIED INITIAI INITIAI lallfAI INITIAI INITiAI ltllTiAI AT7AcHHC47 I

r, a

W I

H

~0 ~>4%Igg0 00)y N= RESOuRcES PLORXDA POMER ET LIGHT COMP ST.

LUCIE PLANT UNIT NO.

PREOPERATIONAL TEST PROCEDURE N

1.0 Title
OATE CUCIE P~R VER!F(ED IRHBRN0QR LRPEL 0&BTR~00AA~
BOX Vol@AD INIIIA~
~@E VER(F)EP INfl~
DATE VERfF/EP INIIIA~
+>E VERIF~EP IlllIIAI t&IB IlelieN AUTOMATIC CONTROL SYSTEM CHECKOUT, STE REGULATXNG SYST&k, AUTOMATIC TURBINE CO T
2. 0 Puruose:
2.1 To demonstrate the capability of the steady state and normal transient operation.
Rl 2.2 To verify that the Peedwater Regulating system for ASB steam generators will give an adequate and stable response during steady state and expected transient condi'tions.
2.3 To verify turb. response to reactor power changes.
3. 0
References:
3.1 PSAR Chapter 14, Table 14.1-2, item 6.
3.2 Regulatory Guide 1.68 section D, item d.
3.3 PSAR chapter 7, page 7.7-6 S/G Control System 3.4 PSAR chapter 10.5 4.;1 Pxeoperational tests of the feedwatex.regulating system have satisfactorily concluded (0700086'nd'700060).
been Date
5.0 Xnstrumentation
5.1 Data processor 5.2 Sequence of events recorder 5.3 Multichannel strip chaxt recorders 6.0 Related S stem Status:
6",1. Th, pganthas bee'n stabilized at approx.
25% generator power for at least 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months , i.n accordance.with, Sequencing Document.
Verified" by Date 6.2 The CEDS,is in the manual sequential control mode.
Verified by Date 6.3 The feedwater regulating system is in '.automatic control.
Verified by Date 6.4 Tavg~contxolling at + 2 P of Tref.
Verified by
6. 5 Turbine generator is in automatic control.
Verified by Date
tpl yY II k
~f lf
Revision 1
7.0" PREOPERATIONAL TEST PROCEDURE H0.,140 4
AUTOMATIC CONTROL SYSTEM& CHECKOUT, STEAN GENERATOR LEVEL CONTROL, CEA.
REGULATXNg SYSTJM AUTOlfATIC TlJRBXNE CONTROL & LOAD SWING TEST S ecial-Materials or E ui ment:
7.1 Multichannel strip chart recorders.
8. 0 Tem oxar Connections:
8.1 The Multichannel strip chart recorders should be connected to the following parameters at their patch panels:
as applicable:
9.0 8.1.1 Pressurizer pressure 8.1.2 Pressurizer level 8.1.3 S/G lA & 13 outlet and turbine inlet pressure 8.1.4 A&3 S/G flows steam and feedwater 8.1.5 A&3 S/G levels 8.1.6 Reactor power level, power range control, channel 1&2 8.1.7 Loop lA & 13 hot leg temp.
8.1 8
One cold leg temp. per loop(lAl, 1A2, 131, 132) 8.1.9 Turbine Fixst stage pressure 8.1.10 Generator Mf Precautions:
9.1 Limit temperature increases in order to prevent tuxbine bypass valve operation.
9.2 Do not exceed a ramp rate of + 5%/min.
9.3 Limit CEA motion and position in accordance with Tech.
Spec 3.1.1.3.6 and Load Follow Guidelines OP 0030123.
9;4 Prior to transfer of CEDS control to automatic, insure that Tavg is within + 1"F of Tref.
9.5 Temperature oscillations, when CEDS is in automatic
mode, should not be allowed to exceed 5 F peak to peak or have a period of less than one minuhe.
Switch CEDS to manual control and return plant equilibrium conditions if this or any other anomaly occurs during the test.
Do not continue with this test until unexpected condition is corrected.
9.6 Avoid input disturbances which could cause the steam genexator level to approach high'r'ow steam~ generator. levelwlarm
.points.
4 9.7 Avoid large disturbances in feedwater flow which could create sig-nificant temperature imbalances within the reactor coolant loops.
9 8 uu"ing power increases
'nsure variable overpowe" trip is being cset.
If i
t th performance of this test, Combustion Enginee=
ng p.ohib t.
load swinging with CEA's, load swinging by that means should nnot be done.
10 All control room recorders should be marked with the following information, 9.
con ro o
1) chart parameters;
2) chart speed;
3) cnart scale;
)
e
4) time date
5) test title and number
Page 3 of'3 Revs.sion 1
PREOPERATIONAL TEST PROCEDURE NO.
140 4
AUTOMATIC CONTROL SYSTEH CHECKOUT, STEQi GENERATOR LEVEL CONTROL, CHA REGULATING SYSTI2f AUTOhfATiC TUPJi3INE CONTROL 6 LOAD SWING TEST 10.0 Acce tance Criteria:
NOTE:
NO SAFETY CRITERIA APPLICABLE 10.1 Steam generator level is controlled in the automatic mode without significant oscillations during steady state operation and after transients.
10.2 Verify the capability of the CEA Regulating System in automatic sequential mode under steady state and normal transient reactor operation.
10.3 Turbine Control System:
No undamped
. or diverging oscillations resulting from the transients of Section 12.42 as seen by turbine first stage pressure and/or generator megawatts.
11.0 Records Re uired:
11.1 A copy of this test, signed and dated by a Florida Power
& Light Company designated witness, shall be retained in the plant files.
11.2 Charts from Multichannel recorder shall be retained in the plant files.
I I
~
Pa~e 4 of Revisionll PREOi TXONAL,THGT PROCEDURE NO, 14 4
AUTOMATXC CONTROL SYSTEH CHECKOUT, STEAN GENERATOR LEVEL CONTROL, CEA.
REGULATXNG SYSTHH, AUTOHATXC TURBXNB CONTROL 6 LOAD SMXNG TEST
12. 0 Detailed Procedure:
NOTE:
During the perfonnance of this test it is expected that some tuning of the RRS and the feedwater regulating system will be necessary.
Repitition of previously completed steps may be required.
During the performance of this test note Tavg-Tref points where slow and fast CHA movements are initiated and record on Data Sheet 1.
12.1. Select RRS to channel l.
Verified by Date 12.2 Verify multichannel strip chart recorders are connected to the following parameters.
Turn on recorders.
12. 2. 1
12. 2. 2
12. 2.3
12. 2. 4
12. 2. 5 12.2. 6
12. 2. 7
12. 2. 8 12.2. 9
12. 2. 10
12. 2.11 12m 2 ~ 12 12.2.13 Pressurizer pressure Pressurizer level S/G 1A steam outlet pressure S/G lA steam flow S/G 1A feed flow S/G 1A level Turbine inlet pressure Turbine first stage pressure Loop 1A hot leg temp.
Loop 13 hot leg temp.
One cold leg temp. per 1'oop Reactor power lev 1 powez range control Ch.
1 Generator IÃ Verified by Date 12.3 Switch !CEDS from manual sequential to automatic sequential control mode.
Verified by Date 12.4 Verify S/G 1A feedwatex flow controller in automatic.
Verified by Date 12.5 Observe operation of the RRS and feedwater regulating system for at least one hour.
Check Tavg Tref
< 2 P and S/G 1A level at 66.5/ + 2/.
Tavg Tref ~
S/G 1A level ~
Verified by Date 12.6 Slowly lower load approximately 2 percent at the rate -of el/2//min.
Verified by Date
~
~
~ 1 I
Page 5'f Revision 1
t PREOPERATXONAL TEST PkOOEONRE NO.
1400004 AUTOMATIC CONTROL SYSTEM CHECKOUT; STEAM GENERATOR LEVEL CONTROL P
CEAL REGULATING SYSTEtt, AUTOMATIC TURBINE CONTROL & LOAD SHING TEST
12. 0 Detailed Procedure:
(cont.)
12.7 Observe operation of the RRS and feedwatex regulating system for at least one hour.
Check Tayg-Tref w 2 F and S/G 1A level is 66.5%+2%.
Tavg Tref S/0 lA level ~
Verified by 12.8 Slowly increase load approximately 2 percent at'he rate of~1/2 %/minute.
Verified by Date 12.9 Observe operation of the RRS and feedwater regulating system for at least one hour.
Check Tavg-Tref ( 2 F and S/G lA level is 66.5% + 2%.
Tavg Tref S/G 1A level ~
Verified by Date 12.10 Turn off strip recorders.
Vexified by Date 12.11 Switch CEDS from automatic sequential to manual sequential control mode.
Verified by Date 12.12 Switch RRS to channel 2.
Verified by Date 12.13 Verify multichannel stxip chart recorders are connected to parameters.
Turn on recorders.
Verified by the following
12. 13. 1
12. 13. 2
12. 13. 3
12. 13. 4 12.13.5 12"; 13".
6'2.13.7 12.13.8 12.13.9 12.13.10 12.13.11
.12'3'2
1.2. 13..13 Pressurizer pressure Pressurizer level S/G 1B steam outlet pressure S/G 1B steam.'flow S/G 1B feed flow S/G 1B4 level Turbine inlet pressure Turbine fixst stage pressure Loop lA hot leg temp.
Loop 1B hot leg temp.
One cold. leg temp. per, loop Reactor power level, power range contxol Ch.
2 Generator Mtl Verified by 12.14 Switch CEDS from manual sequential to automatic sequential control mode.
Verified by Date
l ~
0
<I II 4
t
~
~
Page 6 of
]3 Revision 1
t PREOPERATIONAL TEST PROCEDURE NO.
14000 AUTOMATIC CONTROL SYSTEM CHE(XOUT, STEAtf GENERATOR LEVEL CONTROL, CEA REGULATING SYSTEM, AUTOMATIC TURBINE CONTROL 6 LOAD SHING TEST 12.0 Detailed Procedure:
(cont.)
12.15 feedwater flow controller in automatic, Verified by Verify S/G lB Date R)
Rl 12.16 Observe operation of the RRS and feedwater regulating system for at least one hour.
Check Tavg Tref a 2 F and S/G 1B level at 66.5% + 2%.
Tavg Tref ~
S/G 1B level ~
~
~
Verified by Date 12.17 Slowly lower load approximately 2 percent at the rate of ~ 1/2%/minute.
Verified by
'2.18
-Observe operation of the RRS and feedwatez regulating system for at least one hour.
Check Tavg Tref < 2 F and S/G 1B level is 66.5%+2%.
Tavg Tref S/G 1B level Verified by Date 12.19 Slowly increase load approximately 2 percent
@t the rate of w 1!2%/minute.
Verified by Date 12.20 Obsexve operation of the RRS and feedwater regulating system for at least one hour.
Check Tavg Tref ~ 2 F and S/G 1B level is 66.5% + 2%.
Tavg Tref ~
S/G 1B level 12.21 Turn off strip recorders.
Verified by Verified by Date Date 12.22 Automatic operation of CEDS while diluting and" borating'2.
22. 1 Verify strip recorders are connected as in 12.13 with RRS selected to channel 2 and S/G 1B feedwater control in automatic.
Turn on strip recorders.
Verified by Date 12.22.2 Dilute RCS by approximately 10'pm.
Observe the RRS and feedwatex regulating system response while diluting and verify that Tavg-Tref ~ 2 F and S/G 1B level is 66.5% + 2% at end of dilution.
Tavg Tref S/G 1B level ~
Verified by Date
S
~e I
, ~
Revision t
PREOPERATIONAL TEST PROCEDURE NO.
140008 AUTOMATIC CONTROL SYSTEM CHECKOUT, STEAM GENEBATOR LEVEL CONTROL, CEA REGULATING SYSTEM AUTOMATIC TURBINE CONTROL 6 LOAD SWING TEST
-. 12.0 Detailed Procedure

12.22
{cont.)
{cont.)
12.22.3 Borate the RCS by approximately 10 ppm.
Observe the RRS while borating and verify that Tavg - Tref ~ 2 F and S/G 1B level is 66.5%+
2%.
Tavg Tref S/G 13 level ~
Verified by 12.22.4 When plant conditions stabilize turn off strip RRS from channel 2 to channel 1, verify S/G lA on automatic.
multichannel strip recorders as in 12.2.
Turn Verified by Date recorders, switch feedwater controller Connect R]
on strip recorders.
Date
12. 22.5 Dilute RCS by approximately 10 ppm.
Observe the RRS and feedwater regulating system response while diluting and verify that Tavg-Tref ~ 2 F and S/G 1A level is 66.5% + 2% at end of dilution.
Tavg Tref =
S/G 1A level =
Verificd by Date 12.22.6 'orate the RCS by approximately 10 ppm.
Observe the RRS while borating and verify that Tavg - Tref ~ 2 F and S/G lA level is 66.5%+
2%.
Tavg Tref ~
S/G 1A level =
Verified by Date 12.22.7 When plant conditions stabilize, turn off strip recorders.
Verified by.
Date
'2.'23 Stabilize plant conditions at 25% power. Verify that RRS is selected to channel 1 in automatic sequential control mode, S/G 1A feedwater controller is in automatic and multichannel strip recorders are connected as in 12.2.
Turn on strip recorders.
Verified by K2.24 Decrease load by 10% at 1%/minute.
Verified by 12.25 Allow plant to stabilize for about 10 minutes.
Verified by Date Date Date
~
'I lt 4 I 4
Revxsion x
t PREOPERATXONAL TEST'ROCEDURE NO.
1400084 AUTONATXC CONTROL SYSTEH CHECKOqT, STEAM GENERATOR LEVEL CONTROL, CEARG nM vXNG TEST 12.0 Detailed Procedure:
{cont.)
12.26 Xncrease load by 10% at 1/2%/minute.
Ver'ified by
12. 27 Allow plant to stabilize.
Verified by 12.28 Turn off strip recorders.
Verified by 12.29 Switch RRS to channel 2.
Verified by Date Date Date 12.30 Verify,S/G 13 feedv'ater control in automatic' Verified by Date 12.31 Connect strip recorders as in 12.13 and start recorders.
Verified by 12.32 Repeat steps 12.24 through 12.27.
Verified by 12.33 Decrease load by 10% at 5%/minute. Verified by Date Date 12.34 Allov plant to stabilize.
Verified by Date
12. 35 Xncreasc load, by 10% in 5% steps.
CAUTXON:, Allow 10 minute wait between 5% stepset 25% power. Allov 15 mins.
abnve 30% power.
Verified by Date 12.36 Allov'plant to stabilize.
Verified by 12.37 Turn off strip recorders.
Verified by Date
12. 38 Switch HRS to channel 1.
Verified by Date
12. 39 Verify S/G 1A feedwater control in automatic Verified by
12. 40 Connect strip recorders as in 12.2" and'tart
-recorders.
Verified by Date 12.41 Repeat steps 12.33 through 12.37. Verified by 12,42 Automatic Turbine Control Test.
Date 12.42.1 Verify Turbine Control in Automatic and strip recorders connected as in 12.2 or 12.3 and turned on Verified by Date
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I PREOPERATIONAL TEST PROCEDURE NO.
1400084 AUTOMATIC CONTROL SYSTEM CHECKOUT, STEAM GENERATOR LEVEL CONTROL, CEA REGULATING SYSTEM AUTOMATIC TURBINE CONTROL & LOAD SHING TEST
12. 0 Detailed Procedure:
{contd) 12.42
{contd) 12.42.2 Decrease RX power by 10% at 1%/minute.
Verified by Date 12.42.3 Allow plant to stabilize for about 10 minutes Verified by
'ate 12.42.4 Increase Rx power by 10% at 1/2%/minute.
Verified by Date 12.42.5 Allow plant to stabilize.
Verified by Date 12.42.6 Decrease Rx power load by 10% at 5%/minute.
Vexificd by 12.42.7 Allow plant to stabilize Vexified by Date Date 12.42.8 Incxease Hx power by 10% in 5%
steps.
CAUTION:
Allow 10 minute wait between 5% steps at 25% power. Allow )5 minutes above 30% power.
Verified by Date 12.42.9 Allow plant to stabilize.
Verified by Date 12.42.10 Turn off str'p recorders.
Verified by 12.43 A&B feedwater cont.xol,valves.may be placed in the mode test pxogram.
Verified by 12.44 Turbine control may be placed in the mode required for program.
Verified by 12.45 CEDS control may be placed in the mode required for the test program.
Verified by Date required for the Date the test Date Date 12.46 Remove the miltichannel strip recorders.
Verified by 12.47 Repeat.:steps 12.1 thru 12.46 at 50% power.
NOTE: In steps 12.35
& 12.42.8 allow 15 min-wait instead of 10 mins.
Verified by Date Date
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PREOPERATXONAL TEST PROCEDURE NO.
1400084 AUTOMATXC CONTROL SYSTEM CHECKOUT, STEAM GENERATOR LEVEL'ONTROL, CEA REGULATING.SYSTEM AUTOMATIC TURBINE CONTROL
& LOAD SHING TEST
12. 0 Detailed Procedure (contd) 12.48 Repeat;steps 12.1 thru 12.4.6 at 90% power.
NOTE:
Xn steps 12.35 and 12.42.8 allow 15 min. wait instead of 10 min.
Verified by Date 12.49 Verify all acceptance criteria have been met.
Verified by Date
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'REOP
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TIONAL gEST PROCEDURE NO.
14 AUTOMATIC CONTROL SYSTEM CHECKOUT, STEQf GENERATOR LEVEL CONTROL sAND" CL~A REGULATING SXSTEH DATA SHEET NO. l RBS lChannel l a
Tavg) Tref by E initiates slow CEA movement.
Tavga Tref by y initiates slow CEA movement.
Tavg > Tref by initiates f'ast CEA movement.
Tavg <Tref by E initiates fast CEA movement.
RRS Channel 2
Tavg>Tref by E
initiates slow CEA movement.
Targe.Tref by y initiates slow CEA movement.
Tavg>Tref by y initiates fast CEA movement Targe. Tref by y initiates fast CLA movement.
Verified by Date
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PREPPERATXONAL TEST PROCEDURE NO ~ 1L~00084 AUTOMATXC CONTROL SYSTEM CHECKOUT STEAM GENERATOR LEVEL CONTROL, CEA REGULATING SYSTEM AUTOMATXC TURBINE CONTROL & LOAD SHING TEST 13.0 Deviations from Procedure:
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ST.
LUCXE Pt.VIT U:IXT PRI OPERATXONAL. TEST PLI,OCVDteZ RQV2.'i'lon COi GAPA IX
/! k No,.0110090 TXT1,E:
10% LOAD REDUCTXON TURBXNE RUNBACK 2.
PREPARED BY:
R. L. Hayes October 30 1 9 7'5 s: '-'vTL-:en m:
SUBCGlMXTTEE REVXEU BY:
5..
nZVXE~Zm BX PNSC ON:
'OII C4 gi/0'- 7 19$$
19)(
19'7$
'>>~<>>':>>
~~~~ni~
7.
RI-"'V. RXON REVXF IE.D'IIV P'!SC OIl:~Qg+AggQg APPROVED BY
~/r~~JPLViiT. ~LINAGE 9.
TEST CONDUCTED BY:
>>2R zgg 10;.'ESULTS REVXEiPM BY:
FOR
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11'EST RESULTS REVXErr'ED BY 12.
TEST RESULTS REVXP~"'J BY PNSC, DEEXCXENCXES COB'6C'H)QD ACCEPT.QlCZ.
RZCOi~HDED 19 13.
RESULTS ACCEPTED A%) APPROVED BY:'3.ant?b'av.ager 19 c
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FLORIDA POWER
& LIGHT COE'LPANY ST.
LUCIE PLANT PREOPERATIONAL TEST PROCEDURE NO.
0 REVISION 1
Page 1 of 7
1 gIFf'ffFORffATfO;;>,fT f'fEFoffE USF.
FLORrDA PO'/PER AND L'GHT CO POWER RESOURCES PVAffT ST. lg~fE SATE eRfFfES IMTE >~fFfES SATE VERtFfED SATE Vaf(FfED SATE RRfFlE9 SATE VEgFfED if tur ine run a@~~
1.0 Title
10% LOAD REDUCTION TURBINE RUNBACK 2.0
~Pur oee:
The purpose of this procedure is to ver y
-'o determine plant response resulting from a load reduction.'AITIAI IAITIAI AIITIA!
IMITIAI INITIAL AIITIAI 3.0
References:
3.1 B G
& E Power Test Procedures 3.2 St. Lucie Unit /31, FSAR, Chapter 14 4.1 The load dispatcher has been advised of the load reduction.
Verified by Date T
Date 4..2 The.parameters listed in 12.2 have been input to the recorders.
Recorder scales have been selected and pens positioned to monitor the entire transient on scale.
Verified by 4.3 The turbine bypass and atmospheric steam dump valves are operable.
4 Verified by Date 4.4 All test personnel have been briefed.
Verified by
5.0 Instrumentation
Date
.. R 1
Installed plant equipment 6.0 Related S stem Status:
6.1 TRAC I & TRAC II setpoints have been determined App. A.
6.2, Plant is at 80% power level minimum. (gzcept for step 3.2'.j.}-
Verified by u
6.3 Feedwater Regulating System is in operation.
Date Verified by Date 6.4 Atmospheric Steam Dumps
& SBCS are in automatic.
Rl Verified by Date
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PREOPERATIONAL TEST PROCEDURE NO. 0110090, REV.. l.
10% LOAD REDUCTION TURBINE RUNBACK 7.0 S ecial Materials or E ui ment:
None 8.0 Tem orax Connections:
8.1 Temporary jumper to be installed across dropped rod contacts.
8.2 Four'ultichannel recoxders (6 inputs each) to be used to record the transient.
9.0 Limits and Precautions:
9.1 Advise load dispatcher prior to runback.
9.2 Advise plant personnel of start of xunback over Gai-tronics PA system.
Insure personnel are standing clear of secondary safeties, atmospheric steam
dumps, and turbine bypass valves.
9.3 Operations personnel to take necessary action to prevent reactor trip, secondary safeties from lifting or excessive reactor/turbine power mismatch.
Insert CEA's as necessary using motion inhibit bypass.
9.4 Do not remove the temporary jumper runback 'is complete.
The authorize removal.
k 9.5 In the event the runback does not trip the turbine at approximately installed in step 8.1 until turbine Nuclear Plant Supervisor shall
.Rl r
stop at the setpoint, manually 50% power.
NOTE:
The runback cannot be stopped by assuming manual control of the turbine.
Some undershoot should be anticipated.
10.0 Acce tance Criteria:
The turbine runback does occur on a simulated signal.
11.0 Records Re uired:
11.1 A copy of this procedure with each sign-off initialed and dated by a Florida Power 6 Light Company designated witness shall be retained in the plant. files.
11.2 A copy of the. recorder charts shall be attached to this procedure.
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PREOPERATXONAL TEST PROCEDURE NO. 0110090, REV.
1 10% LOAD REDUCTXON TURBINE RUNBACK 12.0 Detailed Procedure:,.
12.1 Perform Appendix A.
(To be performed during initial powex R
increase at
"-70% power)
Verified by Date
12. 2 The following paxameters should be monitored on the recordexs for the duration of the test.
Indicate start and stop times.
Turn recorders to fast speed prior to start.
SG lAl Level Loop lAl THog SG 1Bl Level Loop 1A1 TCold SG lA1 Pressure Loop 1B1 TCold SG 1Bl Pressure Pzr. Pressure SG lAl Steam Flow Pzr. Level SG 1Al Feedwater Flow Turbine 1st Stage Press.
SG 1Bl Feedwater Flow Turbine Xnlet Pressure SG 1Al Feedwater Demand Steam Dump Demand SG 1B1 Feedwater Demand NX Govenor Valve Common Generator
?%le Runback Event Signal Crossover Pressure 12.3 Announce start of the Turbine Runback Test over PA system.
12. 4 Upon obtaining clearance from the load dispatcher, begin countdown at 5 seconds prior to runback (5-4-3-2 START).
12.5 At START, initiate Turbine Runback by placing Terminal No.
13 to Terminal No.
4 on Terminal the CEDS Logic Cabinet (Rod No. 31).
a jumper from Board 1KB-7A in Verified by Date 12i6 Xn the event the runback does not stop at the setpoint, manually trip the turbine at approximately 50% power.
12. 7 Operations personnel perform normal monitoring of plant parameters to ensuxe plant safety.
12. 8 Verify runback lamp on DEH lights when runback is initiated.
Verified by Date
12. 9 Test personnel turn recorders to slow speed when the significant portion of the transient is completed.
Continue to monitor the parameters until plant conditions are again stabilized.
Verified by Date 12.10 Verify runback lamp on DEH goes out when runback is complete.
Verified by Date
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-PREOFERATIONAL TEST PROCEDURE NO. 0110090, REV.
10% LOAD REDUCTION TURBINE RUNBACK Page 4 of 7 12.0 Detailed Procedure cont.
1 12.11 At the direction of the NFS remove. the temporary jumper installed R
in step 12.4.
1 Verified by Date 12 12 Adjust turbine controls to assume contxol of turbine, if not in automatic.
R 1
Verified by 12.13 Input correct position of jumpered CEA to DDPS.
Verified by Date Date 12.14 Evaluate recorded data and verify acceptance criteria are met.
Verified by Date
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PREOPERATIONAL TEST PROCEDURE NO. 0110090,
REV, 1
10% LOAD REDUCTION TURBINE RUNBACK 13.0 Deviations to Procedure:
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PREOPERATIONAL TEST PROCEDURE NO. 0110090, REV. 1" 10% LOAD REDUCTION TURBINE RUNBACK Date PREOPERATIONAL TEST SK%IARY Remarks Preop Test No.
System Engineer
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0 Page 7 of 7 PREOPERATIONAL TEST PROCEDURF NO
9110090, REV.
1 10/e LOAD REDUCTION TURBINE RUNBACK APPENDIX 1.0 Device Prior to the actual runback (approximately 60/ power), determine the arming and resetting points of TRAC I, TRAC II,.and PI S-22-36 turbine 1st.
stage pressure indicator, by slowly increasing power until they arm,.then decreasing power until tl>ey reset.
Arming Resetting TRAC I TRAC II
/,Power Turbine Press.
/ Power Turbine Press.
PIS-22-36 Verified by Date 2.0 Continue power ascension test program.
~ Turbine Runback to be performed at approximately 80/ power.
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Combustion Engineering, Inc.
1000 Prospect HiII Road Windsor, Connecticut 06095
~~~ COMBUSTjON ENGj'NEERjNG T. LUCIE PLAi~3 t
Tel. 203/688-1911 Tete'~9-'33297'RIr PO f7+
o 0(
P.
O. Box 3667 Fort Piex ce, Flox ida 3+50 F-SF-563 November 17, 1975 I(,P)l $, Igg Local Address:
4~L Mr. K. N. Harri s Plant Manager Florida Power 8c Light Co; St. Lucie gj1 Florida Power 8c Light Co.
St. Lucie Plant Unit g 1
CE Contract P'l9367
SUBJECT:
P/0 f0110090, Rev.
0, 10'OAD REDUCTION TURBINE RUNBACK.
Dear Mr. Harris:
The subject pxocedure has been xeviewed. and we submit the following comments for consideration.
6.2 Replace this section with:
>>Plant is at the power level determined in Appendix A.rr 10.0 Add the following:
>>and terminates at approximately 70fo powex."
12.3 Include the following:
>>Ensure that personnel are standing cleax of main steam safety valves, atmosphexic dump valves, turbine control valves and. bypass valves."
12.6 Add the following caution note:
CAUTION: If the runback continues x educing power below 50fo, trip the turbine.
Insert the following NOTE between 12.7 and 12.8.
NOTE:
Except in emergency, do not take any opexator action for at least 60 seconds following the jumper connection.
Place 12.9 before 12.8.
After 12.8 add the following comment:
CAUTION: If Tc ld exceeds 542oF it may be necessary to reduce power with rods.
If necessary, drive rods in MANUAL GROUP mode, starting with Gx'oup 7o
Between 12.12 and 12.13, add the "fdlluwing:
Restore turbine and (if necessary) reactor power "t'o pre'-test 'values.
Zhsure that"%he steam dump system returns to its pre-test configuration.
I L'. H. Smith, Zx.
CZ Site Manager ZZS:VCP cc:
A.
R.z.
C.
P.
R.
dto S.
Zameson Z. >Jalker
6. Tefft P.
Sears B. Dillon K. Ryall
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PHEOPEHATIONAL TEST PROC'.'TB'9 NO. 0110090'EV.
0 10'OAD REDUCTION - TURBINE RUNBACK APPENDIX A 1.0 :Prior to the actual runback (approximately 60fo power),
determine the arming and resetting points of TRAC I, TRAC II, and PIS-22-36 (70fo power contacts).
'1.2 Increase power from approximately 6'y dilution (ARO) and continuously observe the parameters listed below.
As each arms, observe the corresponding parameters and record them below.
'After the last (highest power) parameter has arme'd, commence boration to reduce power.
Continuously monitor the parameters until the lowest one has reset and record them below.
1 3
Increase power 10'bove the lowest resetting.
device and stabilize power.
DViTICE ARMING o Power Turbine Press o Power Turbine Press.
TRAC I TRAC. II PIS-22-36 2.0 Continue power ascension test program.
Turbine runback is to be performed at the power level determined i'n 1.3 above.
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ML18098A046

Contents

Text

Dear Mr. Boyd:

Title:

References:

T. PROCEDURE

1.0 Title

References:

5.0 Xnstrumentation

1.0 Title

References:

5.0 Instrumentation

SUBJECT:

Dear Mr. Harris:

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ML18098A046

Text

Dear Mr. Boyd:

Title:

References:

T. PROCEDURE

1.0 Title

References:

5.0 Xnstrumentation

1.0 Title

References:

5.0 Instrumentation

SUBJECT:

Dear Mr. Harris:

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