IR 05000354/1985055

Insp Rept 50-354/85-55 on 851104-15.No Violation Noted.Major Areas Inspected:Preoperational Test Procedure Review & Verification,Preoperational Test Witnessing & Startup Test Program

ML20138M293
Person / Time
Site:	Hope Creek
Issue date:	12/09/1985
From:	Briggs L, Eselgroth P, Wink L NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I)
To:
Shared Package
ML20138M292	List: IR 05000354/1985055 ML20138M286
References
50-354-85-55, NUDOCS 8512200351
Download: ML20138M293 (9)

Text

.,

~

.

,

. . . -

,

. .

n r P

s U.S. NUCLEAR REGULATORY COMMISSION

,1

REGION I

Report N /85-55 3

.

'

t Docket N , .s ,

,

License N CPPR-120 Priority --

Category B

,-

Licensee: Public. Service Electric & Gas Company

,,

, 80 Park Plaza - 17C

' Newark, New Jersey 07101 ,

. -

-

Facility Nume: Hope Creek Generating Station

_ ,

InspectionJt: "

Hancock's Bridge, New Jersey

.

.

Inspe'c tion Conduc3ed: November 4 _1_5, 1985

.

f .

i Inkectors: r _

M~

L! Brig'fs, Lsad Reactor Engineer fl .

'_

h

,

, Ipate

\ r

+ .

> / kW L.' Wink, Reactor En ineer 6) l h0 Idpte h

s

^

.Ap oved by: ., ..

-

P.'Eselg'roth', Chief, Tes~t Programs section, b ,

/

'-

08, DRS  % ,

'd/te

,

Inspection Summary:

Inspection on November 4-15, 1985 (Report No. 50-354/85-55)

Areas Inspected: Routine, unannounced inspection (40 hours4.62963e-4 days <br />0.0111 hours <br />6.613757e-5 weeks <br />1.522e-5 months <br />) by two region-based inspectors including followup of a previous inspection finding, pre-

. operational test.ptbcedure review and verification, preoperational test wit-

nessing,~ witnessing if miscellaneous tests and maintenance, startup test program,4 QA/QO interf ace with preoperational test program, plant tours, and independent ve'rificatio ,,

,

'

Results: 'Noviolationswereidentified.] '_

t

',

3 7

. 1

.

'

.

. s,

• W8 *A

.

g

' - Ns *

G512200351 851217 L PDR ADOCK 05000354 G '

PDR -

. -

-

~ v.

l m--

. . - - . .. _ _ . _ _ ._

-

i e

DETAILS

1.0 Persons Contacted C. Adkinson, Colt Diesel Engine Representative

• A.' Barnabei, Principal Quality Assurance (QA) Engineer

• V. Blenx, Construction Manager / Assistant Project Manager

< .W. Brigman, System Test Engineer, Nuclear Instrumentation R. Donges, Lead QA Engineer M. Farschon, Power Ascension Manager

• A. Giardino, Manager, Station QA

• W. Goebel, QA Engineer

• Griffith, Principal 0A Engineer

• Indico, Project Startup (SU) Director C. Jaffee, Startup Engineer D. Moon, Power Ascension Test Coordinator C. Moore, System Test Engineer (STE), Residual Heat Removal

• L. Piccirelli, QA Engineer W. Schell, Power Ascension Test Director D. Smith, STE, Station Service Water C. Sullivan, Startup Test Design and Analysis (STD&A) Engineer D. Wood, Startup Engineer L. Zull, Lead STD&A Engineer Other NRC Personnel

• J. Lyash, Resident Inspector The inspectors also contacted other personnel of the licensee's operating, technical and QA/QC staf * Indicates those present at exit meeting on November 15, 1985.

.

2.0 Followup of Previously Identified Item (Closed) Unresolved Item 354/85-36-01, Licensee to determine where and how all rod blocks are tested. The inspector determined by review of preoper-ational test procedures (PTP) and discussions with the -STE that all rod blocks except the shutdown rod block were incorporated (to be tested) in several PTP's. The licensee issued change notice No. CN-1 to PTP-SF-1A,

. Reactor Manual Control System, on November 12, 1985, to test the shutdown rod block circuitry. This item is close .0 Preoperational Test Procedure Review 3.1 Scope The PTP's listed below were reviewed in preparation for test wit -

nessing, for technical and administrative adequacy and to assure that planned testing is adequate to satisfy regulatory guidance and license !

commitments. They were also reviewed to verify licensee review and

- . __ ._

, - _-

- .

t

,, approval, proper format, test objectives, prerequisites, initial conditions, test data recording requirements and system restoratio EA-1 Station Service Water System, Revision 0, October 18, 1985 9 i 3.2 Discussion

.

'

3. PTP-EA-J s

'-

~The procedure was reviewed by the inspector using the refer-e  ! ences and P and ID's listed in Attachment A? The inspector

, had several questions concerning the procedure'and the method

-> and intent of the test which were discussed with the system test engineer (STE) and resolved with one exception. The exception involved the proper criterion tb verify adequate net, positive suction head (NPSH) for the station service water pumps. As written, the test demonstrates that the available NPSH under normal operating conditions exceeds the pump's

'

requirement of 20 f In accordance.with FSAR Section 9.2.1.5,

<g the test must demonstrate that the available NPSH is at least 35 ft. at the design low low water level for the pump suctio '

Discussions with the STE did not resolve this concern. The licensee, during a subsequent discussion, agreed to revise the procedure to document acceptable pump NPSH value i>

7 Portions of the station service water system will be tested during other preoperational test PTP-SV-1, Remote Shutdown Panel, checks the ability to operate portions of the system from the remote shutdown panel. This procedure was reviewed during inspection 85-35. System operation during LOCA and

loss of-power conditions will be verified in PTP-BB-3, Inte-grated ECCS LOP, while operation during Reactor Building high ,.

radiation will be tested in PTP-SM- These procedures have ~/~

not yet been approve DTP-EA-001 and DTP-EA-002, which are still being written, will confirm design flow rates-through

the heat exchangers and the ability of the station servi,ce water system to supply water to various other systems. s

.

3.3 Findings

, The result of the procedure review discussed in Paragraph 3. remains unresolved (354/85-55-01) pending licen,see action to modify the procedure to demonstrate adequate NPSH under design conditions and subsequent NRC revie .~

.

(

If-

)

f I

i e - - y --,y e

. _ . .. - - .--

.

.,

4.0 Preoperational Test Witnessing 4.1 Scope Testing witnessed by the inspector included the observations of overall crew performance stated in Paragraph 3.0 of Inspection Report 50-354/85-1 .2 PTP-BC-1 The inspector observed portions of the jockey pump testing for the Residual Heat Removal System conducted as part of PTP-BC-1. Testing was conducted in accordance with the criteria of Paragraph 4.1 above with full QA coverage during the portions witnessed by the inspecto .3 PTP-SE-3 The inspector witnessed a portion of the Nuclear Instrument Flow '

Comparator Channel A testing being conducted under PTP-SE-3, Power Range Monitoring. All testing observed satisfied the criteria of

' Paragraph 4.1 abov .4 Findings No violations were identifie .0 Witnessing of Miscellaneous Testing and Corrective Maintenance 5.1 Recalibration of High Pressure Coolant Injection (HPCI) Discharge Pressure Instrument The inspector witnessed the final data taken on PT 4772, HPCI discharge header pressure instrument. Testing was being conducted under Test Package Release (TPR) BJC-0139. Instrument calibration data met established acceptance criteri .2 Corrective Maintenance on Robertshaw Valve The inspector observed the examination and cleaning of a six inch Robertshaw valve used to control jacket cooling water flow which stuck in the maximum coolfaC position during the performance of DTP-KJ0003, Preliminary aus Initial Loaded Testing of 'C' Emergency Diesel Generator (EDG). Testing was being conducted under vendor guidance. The valve was disassembled and visually inspected under Startup Deficiency Report (SDR) KJ-1200. There were no visual defects. The valve was cleaned and reinspected and was being reas-sembled at the completion of this inspection on November 15, 1985.

.

. . - , - - - - - - . - - . - .n -4 , ,

- . . . . . - -. . - - --.

.

.

Proper valve. function will be verified during a subsequent NRC review of EDG test results and observation of EDG preoperational testin .3 Preliminary Electrical Checks of 'A' EDG Voltage Regulator The inspector observed a portion of DG1AG400 Static Exciter Voltage Regulator testing being conducted under TPR KJE-0276 and GTP-15, Re-vision 3, Digital Control Circuit Checkou Testing was being con-ducted to ensure proper electrical circuit connection and operation prior to performance of vendor testing. Vendor testing of 'A' EDG will be conducted under DPT KJ-000 .4 No unacceptable conditions were identifie .0 Startup Test Program 6.1 Scope The inspector met with the Power Ascension Manager to discuss the status of procedural development to support the startup program, the administrative controls to be employed to govern testing, compliance with the FSAR and regulatory guides and the qualifications and train-ing of test personne In addition, the station administrative pro-cedures listed below were reviewed to verify the licensee has deve-loped administrative controls which will assure that the startup test

program will be prepared, performed and evaluated in accordance with regulatory requirement SA-AP.ZZ-022, Control of Calibrated Measuring and Test Equip-ment, Revision 1, April 26, 198 SA-AP.ZZ-032, Revisions and Changes to Station Procedures, Revision 2, October 2, 198 .2 Discussion 6. Procedure Status The Power Ascension Manager provided the inspector with a complete listing of all procedures developed for startup testing. The listing includes a total of 124 procedures,

.111 startup procedures and 13 tuneup procedures. As of November 5,1985,71-(64%) of the startup procedures and 13 (100%) of the tuneup procedures had been formally approved. The remaining 40 startup procedures have com-pleted the initial review process and are awaiting formal approva .

I I

l

, ,_ _

_ _ _ _ __ , _ _

.

.

6. Compliance With the FSAR and Regulatory Guides The Power Ascension Manager stated that a review was being made of Regulatory Guides 1.68, 1.68.1 and 1.68.2 to insure compliance. The inspector requested that the licensee provide a listing to identify which startup tests would satisfy particular items of regulatory guidance. The Power Ascension Manager stated that a listing would be available shortly and would be made available for NRC revie . Qualification and Training of Testing Personnel The inspector discussed with the Power Ascension Manager the administrative controls that would be used to insure that testing personnel have a combination of education, training and experience commensurate with their functional level of responsibility. The Power Ascension Manager stated that a draft administrative procedure had been developed to govern the qualifications and training of testing personnel but that a final decision had not been made whether to use that procedure or to qualify personnel using the Station Admini-strative Procedure, SA-AP.ZZ-014, Qualification and Train- i ing of Station Personne The Power Ascension Manager stated that, whichever method was employed, testing person-nel would be qualified to ANS-3.1 as stated in the FSA . SA-AP.ZZ-022 The inspector reviewed the procedure to verify that controls had been established for special test equipment ir.:luding:

listing of controlled equipment, calibration requirements, calibration history, controls for storage and issuance and requirements for recording test equipment used in particu-lar tests. This will permit identification of affected tests if test equipment is found to be out of calibratio . SA-AP.ZZ-032 The inspector reviewed the procedure to verify that controls had been established governing revisions of approved proce-dures and that measures had been established to govern changes (both major and minor) to test procedures during the conduct of testin .3 Findings No unacceptable conditions were identifie I

.

.

7.0 QA/QC Interface with Preoperational Test Program The inspector reviewed recent QA surveillance report (QASR) regarding different activities of the licensee's startup group. The following QASR's'were reviewed:

--

QASR-5375, Witnessing of retest for test exception No. 25 of PTP-BH-1, Standby Liquid Control System. Surveillance conducted on November 1, 1985. Retest was performed to verify correct operation of green stop light on HS-41008 after the logic module was replaced. Retest was satisfactor QASR-5486, Witnessing of portions of Detailed Test Procedure (DTP)

KJ-0004, completed on November 10, 1985. The QA inspector witnessed eight QA mandatory witness points. All results were satisfactor QASR-5487, Witnessing of torquing of 'B' EDG silencer inspection cover, completed on November 10, 1985. The QA inspector noted the torque wrench serial number and calibration due date. Work was conducted under SDR KJ-1194 and General Work Procedure MDZZ-042. Results were sati sf actor QASR-5446, Witnessing of loss of air / power to four RHR system valves, completed on November 7, 1985. All valves failed to their correct positio .1 Findings No unacceptable conditions were note .0 Plant Tours 8.1 Discussion The inspector made several tours of various areas of the facility to observe work in progress, housekeeping, cleanliness controls and status of construction and preoperational test activitie .2 Findings No violations were observe .0 Independent Verification The inspector performed an independent visual inspection of the six inch Robertshaw valve disk and body as discussed in Paragraph 3.2 of this report.

__

• ,

.

,

,

10.0 Unresolved Items Unresolved items are matters which require additional information in order to determine if they are acceptable, violations or deviation The unresolved item identified during this in pection is discussed in Paragraph 3.2.1 of this repor .0 Exit Interview A management' meeting was held at the conclusion' of the inspection on November 15, 1985, to discuss the scope and findings as detailed in this report (see Paragraph I for. attendees). No written information was provided to the licensee at any time during the inspection. The. licensee indicated that no proprietary information was contained within the scope of this inspectio ,

l l

l l

.--

i

.

,

.

ATTACHMENT A

-

Hope Creek Generating Station FSAR 14.2.12.1.12 EA - Station Service Water 9p -

Hope Creek Generating Station FSAR 9.2.1 - Station Service Water System

-

P&ID Service Water Drawing No. M-10-1, Sh. 1 of 3, Rev. 9

-

P&ID Service Water Drawing No. M-10-1, Sh. 2 of 3, Rev. 10

-

P&ID Service Water Drawing No. M-10-1, Sh. 3 of 3, Rev. 7

-

P&ID Circulating Water Drawing No. M-09-1, Sh. 1 of 2, Rev. 9

-

P&ID Safety Auxiliaries Cooling Reactor Building Drawing No. M-11-1, Sh. 1 of 3, Rev. 10

-

P&ID Circulating Water Hypochlorination Drawing No. M-24-0, Sh. 3 of 3, Rev. 6

-

P&ID Plant Leak Detection Drawing No. M-25-1, Sh.1 of 3, Rev. 4