ML20136E699
Text
1 From:
Mark Millerf 8
~
To:-
WND2.WNP3(LAW) / M /d 4/f /L/ X'/f_>
f Date:
11/19/96 5:32am
Subject:
SHERON'S ST. LUCIE VISIT -Reply i
Got your E-mail, but the agenda wasn't attached. Could I get one from you tommorow at the SMM?
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e 9703130298 970306 PDR FOIA BINDER 96-485 PDR
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i WEEKLY BRANCH CHIEF STATUS REPORT BRANCH 3 SIGNATURE Kerry D.'Landis DATE 11/22/96-
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PLANT' ISSUES / EVENTS:
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-a)
St Lucie - Both units operated at'100%-for the entire week, b)
- Turkey' Point -'Both units operated at 100% for the entire week.
.j c);
Crystal River - FPC revised plans to remain shutdown until. the end o'f February.1997.
SIGNIFICANT INSPECTION FINDINGS / INITIATIVES:
a). -. Crystal River - The.SALP board reconvened on 11/22/96-for further deliberations. The
~SALP'may be signed out today.
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' b):
- Crystal River - The Chairman of the restart panel. Mr Johns Jaudon was or) site this l
week for meetings with the licensee.
were in the areas of timely activation of r.ntial multiple violations.
St Lucie - The EP inspection identified pote The violations c)-
esponse facilities, training of response perso'nnel, and corrective actions.
The enforcement panel. determined this week that
. these violations will be the topic. of an enforcement conference on 12/10/96.
NRC l
. questioned FP&L this' week whether or not their emergency plan requires that each Lresponder has to have participated in a site specific drill prior to being placed on
.the. responder list.
After a conference call. FP&L agreed to. provide NRC a submittal
' by 11/20/96 to clarify their position on this issue.
This week NRC granted an extension on this commitment'until the week of 11/15/96.
- d).
St Lucie-The licensee reported a possible design weakness in that the DC control power for the turbine driven AFW pump will not automatically transfer to an alternate
-source upon loss of a'DC bus. The Headquarters AE team is following up on this issue.
e)-
No. new -FSAR discrepancies were identified this week.
NRC PERSONNEL ISSUES / STATUS:
a)-
Credit Hours' authorized: None
.b)
LA solicitation of-interest was issued for another Crystal River RI position.
ISSUES / ACTIVITIES EXPECTED NEXT WEEK:
The Headquarters AE team inspection has completed one week and will resume the. week of 12/2/96.
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- WEEKLY BRANCH CHIEF STATUS REPORT.
r BRANCH 3
~ SIGNATURE Kerry D: Landis DATE 11/27/96 ELANT ISSUES / EVENTS:
a)-
Si. Lucie:- Both units operated at 100% for the entire week.
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- b)
Turkey Point - Both units operated at 100% for the entire week.
c)
Crystal River - FPC' revised plans.'to remain shutdown until March 1997, SIGNIFICANT INSPECTION FINDINGS / INITIATIVES:
a)
Crystal R1ver - The SALP board ' reconvened on 11/22/96 for further deliberations. The
_t SALP was issuad on 11/25/96.
The results were: Oper.ations - 3. Maintenance - 2.
i
- Engineering - 3. and Plant Support - 2.
There has been Media interest from the Tampa Tribune. ST Petersburg Times, and Financial Firms, t
b)
No new FSAR discrepancies were identified this week.
l NRC PERSONNEL ISSUES / STATUS:
a) ~
Credit Hours authorized: None l
b):
Crystal River RI position was posted via RI developement program.
ISSUES / ACTIVITIES EXPECTED NEXT WEEK:
. 1.
Crystal River - SALP Presentation 12/2/96 (Tim Martin Attending) 2.
Crystal River - Restart Panel Meeting on Site 12/3/96 1
[
3i Crystal River - EFW and IPAP F/U Inspection (3 Inspectors)
~
, 4.
_ Crystal River - Safeguards Inspection (3 Inspectors) 5.
St. Lucie - AE-Inspection Team On. Site 12/3-13/96 i
6.
-St. Lucie - B. Sheron Visit 12/2-4/96 i
7.
St. Lucie - Requalification Program Inspection 12/2-6/96 i
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EXECUTIVE OVERVIEW OF ST. LUCIE VISITING OFFICIAL: Brian Sheron, Acting Associate Director for Technical Review Office of Nuclear Reactor Regulation DATE OF VISIT:
December 2-4,1996 PLANTS:
St. Lucie Units 1 and 2 ENCLOSURE:
Plant Performance Assessment Backaround Information for St. Lucie The St. Lucie Nuclear plant is located on an 1110 acre site on Hutchinson Island, which is a natural bf rrier island. The plant is comprised of two nearly identical units designed by Combustion Engineering. The non-nuclear, or steam plants, were designed by Ebasco Services. Each unit is capable of generating approximately 900 megawatts of electric power.
Cooling is provided by seawater, drawn from and returned to the Atlantic Ocean.
Unit 1 was placed in commercial. operation in December 1976, and Unit 2 began commercial operation in August 1983. The reactors are refueled at approximately eighteen month intervals.
The next refueling (Unit 21 is scheduled for April 1997.
St. Lucie Unit 1 currently has a lifetime capacity factor of 75%. Over the years, the unit has achieved many world and U.S. records associated with plant availability and capacity factor. In 1992, Unit 1 set a world record for pressurized water reactors for consecutive days on line. The unit had operated 502 days non-stop before being removed from service for refueling. St. Lucie Unit 2 also had an outstanding performance record. In 1987-1988, Unit 2 set a FPL record for contmuous operation of 427 days and had the number one capacity factor of any nuclear plant in the world. However, declining performance at the St. Lucie Plants wa' noted in th4 ast SALP 1
period which ended January 6,1996, particularly in th'e areas Operation anc(MainiM The y
reason for this decline is discussed below under " Current Concern There have been a large number of management changes at St. Lucie in the last year. Since December 1,1995,8 managers have been changed (Services Manager, Licensing Manager, Outage Manager, Training Manager, Nuclear Material Management Superintendent, Steam Generator Replacement Project Manager, Operations Manager, and System & Component Engineering Manager), and in addition a new site vice president, Art Stall, reported in May of this year.
I I
SALP Ratinas Functional Area Ratino This Period Ratina last Period Operations
'2 1
Maintenance 1
Engineering 1
1 Plant Support 1
1 CURRENT STATUS Both St. Lucie Units are currently operating at 100% of rated power.
QJlRRENT CONCERNS l
/
Since kuly 1995)there have been a series dehthat lead to questions about the plant's overall performance. These events and several other.recent deficiencies involving weak procedures, a general lack of proc.edural compliance, equipment f ailures, and personnel errors clearly indicated that the plant's past high level of performance has declined. These deficiencies highlighted weak management involvement in day to day operation of the plant; weak operator performance during routine evolutions; procedure inadequacies; weak corrective actions; lack of attention to detail; decline in equipment performance; and poor maintenance. As a result of this declining perforrnance, the NRC has held bi-monthly meetings with FPL management to review the status of the licensee's performance improvement initiatives. The licensee undertook a number of efforts to reverse this declining performance. A number of manaDement changes were also made in response to the
' declining performance. The NRC continues to closelyElonitor the plant's performance to determine the effect of these corrective activities.
There has been a significant increase in the number of afFIgsli5n6at St. Lucio. There were a total of 43 allegations in FY96, compared to 16 in FY95. This increase could be related to the FPL downsizing (13% in the last year), although there has not been a corresponding increase at Turkey Point. A significant allegation was made recently relating to the St. Lucie Emergency Preparedness program. The alleger also provided a copy of his concerns to the licensee and to the local press.
The NRC performed a special inspection in response to this allegation. Violations of NRC requirements identified during this inspection will be discussed at an Enforcement Conference currently scheduled for December 1_0,1996.
There has also been a large number of violations at St. Lucie, with three Level ill violations since August 1995 involving: Inoperable Power Operated Relief Valves @DRVsDdue to inad uate Post Maintenance Testing (8/4/95)@verdilution Event (1/22/96); and inadequat 0.59 Evaluation (7/12/96).
Due to a large number of steam generator tubes bein emoved from service as a result of tube degradation, the licensee is scheduled to replace th nit team generators beginning in October 1997. The replacement SGs are already completed and are due_toJrfive_on. site in June 1997. The SGs were built by Babcock & Wilcox industries. Unit 2 SGs have not experienced the same level of degradation as Unit 1 and there are currently no plans to replace these SGs. A 2.206 Petition from Mr. Thomas Saporito was submitted on June 12,1996, as a result.of the large number of plugged tubes in St. Lucie Unit 1. The Petition requested > among cther actions, that St. Lucie Unit 1 be restricted to 50% power. A Director's Decision which denied the request was issued November 18, 1996.
On two occasions in July and August, the licensee discovered instances of tampering. The
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tempering consisted of placing a glue-like substances in a number of padlocks, doorlocks, and keylock switches. No safety systems were disabled as a result of the tampering, but the equipment was located inside vital areas of the plant. The licensee implemented augmented security measures and conducted an intense investigation, but was unable to identify the individual (s) responsible.
The NRC dispatched a special inspection team to the site to review the licensee's actions. The tearn determined that the licensee's actions were appropriate, although some deficiencies were
- noted, t
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WRC - SNARED INFORMATION NETWORK.
DATE: 01/09/97 CIPS - MASTER INSPECTION PLANNING SYSTEM 14:35 BANNER PAGE PAGE:
1
- REGION: 2
' REPORT CLASSIFICATION: FACILITY MIP REPORTS
' REPORT DESCRIPTION: STL (MIP FROM 1/1/93 - 11/22/96)'
REPORT FORMAT SELECTED BY PROGRAM ELEMENT SY PROCEDURE
- X BY FUNCTIONAL AREA BY CO/EMPMASIS/ DISCRETIONARY REPORT BREARDOWN SELECTION CRITERIA
- SITE (A=ALL) : STL
- ORGANIZATION : ALL
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- UNIT MAME: ST LUCIE 1 DOCKET NUMBER:
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- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYOMD LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR OFFICIAL USE ONLY.
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BY FUNCTIONAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
5 UNIT NAME: ST LUCIE 1 DOCKET NUMBER:
050-00335 REPORT FROM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
SALP END DATE: /-/
PROCEDURE STS: ALL ORG CD: ALL
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2.00 94013 71707
-20*
010 MONTHLY RESIDENT AF 2200 58E M
M
.00 2.00 93020 40500
-01 012 EFFECTIVENESS OF LILP TEE CrdTR CO 2230 AHI M 06/17/96 C
%.00 33.50 96008 71707
-01 012 PLANT OPERATIONS CO 2230 AMI C 01/31/ %
M 42.00 69.00 96004 03/30/M 71707
-02 012 PLANT OPERATIONS CO 2230 AHI C 02/29/96 M
42.00 137.50 96008 06/08/96 71707
-03 012
- PLANT OPERATIONS CO 2230 AMI C 03/31/M M
42.00 47.00 96009 07/06/96 71707
-04 012 PLANT OPERATION?
CD 2230 ANI C 04/30/96 M
42.00 59.00 96011 08/03/96 71707
-05 012 PLANT OPEkia a,e5 CO 2230 AMI C 05/31/96 M
42.00 86.00 96015 09/07/96-71707
-06 012 PLANT OPERATIONS CD 223J AMI C 06/30/%
M 42.00 31.50 960:7 71707
-07 012 PLANT OPERATIONS CO 2230 AHI M 07/31/ %
M 42.00
.00 71707
-08 012 PLANT OPERATIONS CD 2230 AMI N 08/31/96 M
42.00
.00 71707
-09 012 PLANT OPERATIONS CO 2230 AMI N 09/30/%
M 42.00
.00 71707
-10 012 PLANT OPERATIONS.
CO 2230 AHI N 10/31/ %
M 42.00
.00 40500
-01 011 SAFETY ASSESSMENT CD
~2200 S8E C 07/01/95 C
%.00 28.00 94024 03/04/95 40500
-02*. 011 SAFETY ASSESSMENT CO 2200 RKP C
C
.00 48.00 95012 01/06/%
40500
-05*
011 SAFETY ASSESSMENT CO 2230 AHI M
C
.00 2.50 96001 71001
-01 011 LIC OPERATOR REQUAL PRGRM EVALU CO 2330 LGL P 09/26/94 C
48.00 37.50 94019 10/08/94 71707
-01 011 MONTHLY RESIDENT CO 2200 SBE C 01/31/94 M
39.00 47.00 94001 01/29/94 71707
-02 011 MONTHLY RESIDENT CO 2200 SSE C 02/28/94 M
39.00 153.50 94009 03/26/94
^ 71707
-03 011 MONTHLY RESIDENT CD 2200 SSE C 03/31/94 M
39.00 65.00 94013 05/28/94 71707
-04 011 MONTHLY RESIDENT CD 2200 SBE C 04/30/94. M 39.00 83.00 94015 07/30/94 71707
-05 011 MONTHLY RESIDENT CO 2200 S8E C 05/31/94 M
39.00 56.50 94018 08/27/94
~
71707
-06 011 MONTHLY RESIDENT CD 2200 SBE C 06/30/94 M
39.00 85.00 94020 10/01/94 71707
-07 011 MONTHLY RESIDENT CO 2200 SBE C 07/31/94 M
39.00 97.00 94022 11/05/94 71707
-05 011 MONTHLY RESIDENT CD 2200 SBE C 08/31/94 M
39.06 112.50 94024 12/03/94 71707
-09 011 MONTHLY RESIDENT CO 2200 SBE C 09/30/94 M
39.00 162.00 95001 03/04/95 71707
-10 011 MONTHLY RESIDENT CD 2200 SBE C 10/31/94 M
39.00 31.00 95007 04/01/95 71707
-11 011 MONTHLY RES10ENT CO 2200 SBE C 11/30/94 M
39.00 40.50 95009 04/29/95 71707
-12 011 MONTHLY RESIDENT CO 2200 SBE C 12/31/94 M
39.00 63.00 95010 06/03/95 71707
-13 011 MONTHLY RESIDENT CO 2200 SBE C 01/31/95 M
39.00 34.50 95014 07/29/95 71707
-16 011 MONTHLY RESIDENT CO 2200 SBE C 02/28/95 M
39.00 126.50 95015 f"116/95 71707
-15 011 MONTHLY RESIDENT Co 2200 SEE C 03/31/95 M
39.00 91.50 95015 m/28/95
- - DENOTES UNPLANNED PROCEDURE
+ - DENGTES GREATER THAN 45 DAYS 85 YOND LAST TARGET DATE INFORMATION ON THIS PAGE 15 FOR 0FFICIAL USE ONLY.
e
FACILITY CIP REPORTS MASTER INSPECTION PLANNING SYSTEM STL CIP FROM 1/1/93 - 11/22/M )
BY FUNCTIONAL AREA DATE: 01/09/97 TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
7 UNIT NAME: ST LUCIE 1 DOCKET NUMBER:
050-00335 REPORT FRCM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP, CYCLE ID: ALL SALP START DATE:
/ /
SALP END DATE:
/ /
PROCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: OPS NAME: Operations SALP RATING :
1 PROC ID PERICD TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRQ PtND HRS ACTL HRS IR # COMPLTN DT 71707
-16 011 MONTHLY RESIDENT CO 2200 SBE C 04/30/95 M
39.00 73.50 95021 01/06/ %
71707
-17 011 MONTHLY RESIDENT CO 2200 SBE C 05/31/95 M
39.00 78.00 95022 01/06/96 71707
-18 011 MONTHLY RESIDENT CO 2200 SBE C 07/01/95 M
39.00 75.00 96001 02/17/96 71710
-01*
011 ESF SYSTEM WALKDOWN CO SBE N 06/30/94 5
10.00
.00 71710
-02*
011 ESF SYSTEM WALKDOWN CO SBE N 12/31/94 5
10.00
.00 71710
-03 011 ESF SYSTEM WALEDOWN C0 SBE N 07/01/95 5
10.00
.00 93702
-01 011 PROMPT ONSITE REPNSE EVNT Co 2200 SBE-M 07/01/95 M
54.00 13.00 94012 40500
-01 010 SAFETY ASSESSMENT CO 2200 SBE C - 10/30/93 C
40.00
.00 40500
-02*
010 SAFETY ASSESSMENT CO 2200 SBE M
C
.00 1.50 93018 71707
-06 010 MONTHLY RESIDENT CD 2200 SBE C 10/31/92 M
.00 2.00 92024 01/02/93 71707
-07 010 MONTHLY RESIDENT Co.
2200 SBE C 11/30/92 M
.00 27.00 93002 01/30/93 71707
-08 010 MONTHLY RESIDENT Co 2200 SBE C 12/31/92 M
.00 49.00 93005 03/06/93 71707
-09 010 MONTHLY RESIDENT CO 2200 SBE C 01/31/93 M
39.00 43.00 93007 04/03/93 71707
-10 010 MONTHLY RESIDENT to 2200 SBE C 02/28/93 M
39.00 101.30 93012 05/22/93 71707
-11 010 MONTHLY RESIDENT.
CO 2200 SBE C 03/31/93 M
39.00 120.50 93015 08/28/93 71707 010 MONTHLY RESIDENT CO 2200 SBE C 04/30/93 M
39.00 38.50 93020 09/25/93 71707
-13 010 MONTHLY RESIDENT CO 2200 SBE C 05/31/93 M
39.00 86.00 93023 10/23/93
. 71707
-14 010 MONTHLY RESIDENT CO 2200 SBE C 06/30/93 M
39.00 40.00 93024 01/01/94 71707
-15*
010 MONTHLY RESIDENT CO 2200 SBE N 07/31/93 M
39.00
.00 71707
-16*
010 MONTHLY RESIDENT CO 2200 SBE N 08/31/93 M
39.00
.00
- 71707
-17 010 MONTHLY RESIDENT CO 2200 SBE N 09/30/93 M
39.00
.00 71707. 010 MONTHLY RESIDENT CD 2200 SBE N 10/30/93 M
39.00
.00 71710
-01 010 ESF SYSTEM WALKDOWN CD SBE C 10/31/92 S
.00 18.50 93012 05/22/93 71710
-02 010 ESF SYSTEM WALKDOWN CO SBE C 04/30/93 S
20.00 14.50 93024 01/01/94 71710
-03 010 ESF SYSTEM WALKDOWN CD SBE N 10/30/93 20.00
.00 93702
-01 010 ONSITE EVENT FOLLOWUP CO 2200 SBE M 10/30/93 M
54.00 5.00 93012 2515/118-01 011 SERVICE WATER SYS OP PRGMNCE IN GT 2350 PEF C 01/02/94
.00
.00 SEE 91-201(C) - PILOT PROGRAM (11/91) 92702
-02*
010 CORCTVE ACTNS VIOL & DEV OA 2200 BRC M
R
.00 1.00 93029 40500
-04*
011 SAFETY ASSESSMENT OR 2200 NBE M
C
.00 2.00 95015 40500.
-02*
012 EFFECTIVENESS OF LICENSEE CONTR Rt 2250 MOB M
C
.00 35.00 96017 71001
-02*
012 LIC OPERATOR REQUAL PRGRM EVALU Rt
'2330 AOM M
C
.00 6.50 %004 71707
-19 012 PLANT OPERATIONS RI 2230 AH1 M 07/05/97 M
.00 40.50 96008 71715
-01 012 SUSTAINED OPS OBSERVATION RI 2330 G0H M 09/09/96 40.00 15.00 96004
- - DENOTES UNPLANNED PROCEDURE
+ - DENGTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
FACILITY C.IP REPORTS MASTER INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL CIP FROM 1/1/93 - 11/22/96)
BY FUNCTIONAL AREA -
TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
8 UNIT WAME: ST LUCIE 1.
DOCKET NUMBER:
050-00335 REPORT FROM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL
'SALP START DATE: / /
SALP END DATE: / /
PROCEDURE STS: ALL ORG CD: ALL.
SALP FUNCTIONAL AREA: OPS NAME: Operations SALP RATING :
1 PROC ID PERIOD TITLE /CDPMENTS IPE PRI ORG EMP STS TARGET DT FR0 PLND HRS ACTL MRS IR 8 COMPLTN DT 92901
-01*
012 FOLLOWUP - PLANT OPERATIONS RI 2230 EDL M
.00 23.00 96015-40500
-03*
011 SAFETY ASSESSMENT RI 2200 KDL M
C
.00 147.00 95015 71707- -19 011 MONTMLY RESIDENT RI 2200 SBE M 07/01/95 M
150.00 118.50 95004 92701
-01 011 OPEN ITEM FOLLOWUP RI STC M 05/29/95
.00 7.50 94012 92901
-01*
011 FOLLOWUP - PLANT OPERATIONS RI 58E C
.00 15.50 95004 03/04/95 92901
-02*
011 FOLLOWUP - PLANT OPERATIONS RI 2230 AMI M
.00 21.00 95022 93702
-02 011 PROMPT ONSITE REPNSE EVNT RI 2200 S8E N 07/01/95 M
.00
.00 -
93804
-01*
011 PRA TEAM RI 2350 57C N 05/29/95' 40.00
.00 40500
-03*
010 SAFETY ASSESSMENT RI 2200 STR M
C
.00 2.00 93018
~71707
-19 010 MONTMLY RESIDENT RI 2200 SBE P 09/30/93 M
100.00 140.70 93015 05/01/93 71707
-21*
010 MONTHLY RESIDENT RI 2200 LIT M
N
.00 23.00 93024 71710
-04*
010 ESF SYSTEM WALKDOWN RI MEA M
S
.00 22.50 93024 92701
-01*
010 OPEN ITEM FOLLOWUP RI SSE M
.00 56.50 93012 92702
-01*
010 CORCTVE ACTNS VIOL & DEV RI 2200 S8E M
R
.00 11.50 93005 93702
-02*
010 ONSITE E % FOLLOWUP RI 2200 MEA M
M
.00 7.00 93015 71707
-22*
012 PLANT OPEaATIONS RR 2230 J7M M
M
.00 4.00 96016
-93702
-01*
012 PROMPT ONSITE REPNSE EVNT RR 2230 AJ8 M
.00 43.00 96008 71707
-21*.011 MONTHLY RESIDENT RR 2260 NRM M
M
.00 4.00 96001 93702
-03*
011 PROMPT ONSITE REPNSE EVNT RR 2200 AMI C
M
.00 47.50 95015 93702
-04*
011 PROMPT ONSITE REPNSE EVNT RR 2230 AMI C
M
.00 9.50 95022 01/06/96 2515/120-01 011 STATION BLACKOUT S?
2320 MTS C 07/08/95
.00 18.00 94006 2515/115-01* 010
. VERIFICATION PLANT RECORD SI 2200 C 10/30/93 4.00
.00 A00'L 10 HRS FROM 92-18 NOT SHOWN (RITS INITIALS: SBE)
TOTAL: 2,304.00 3,441.50
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTEh GREATER THAN 45 DATS BEYONO LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE 0'N L Y.
2 e
m y
3 i.-.,
FACILITY CIP REPORTS.
MASTER INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL (MIP FRCM 1/1/93 - 11/22/96)
BY FUNCit0NAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
9 UNIT NAME:'ST LUCIE 1-DOCKET NUMBER:
050-00335 REPORT FROM DATE: 01/01/1993 kiPORT To DAT5: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
SALP END DATE: / /
PROCEDURE STS:. ALL ORG CD: ALL SALP FUNCTIONAL AREA: PLTSUP WAME: Plant s@ port SALP RATING :
1 PROC ID PERIOD TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRG PLMD HR$ ACTL HR$ IR # COMPLTN DT 81502 01* 012 FITNESS FOR DUTY PROGRAM AF 2350 LKS P
.00 11.50 96019 10/26/96 81700
-02*
012 PnYSICAL SECURITY PROGRAM AF 2350 LKS P
C
.00 2.50 96019 10/26/%
82701
-02 012 OP STATUS OF EP PROGRAM AF 2340 JWK C 10/28/M C
00 168.50 96018 11/02/96 81022
-01*
011 SECURITY ORGANIZATION AF 2340 WJT C
.10 20.00 94021 10/01/94 81034
-01*
011 SECURITY PROGRAM AUDIT AF 2340 WJT-C
.00 18.00 94021 10/01/94 81038
-01*
011 RECOROS AND REPORTS AF 2340 WJT C
.00 18.00 94021 10/01/94 81070
-01*
011 ACCESS CONTROL - PEOPLE AF 2340 WJT M
.00 6.00 94021 81072
-01*
011 ACCESS CONTROL - PACKAGES AF 2340 WJT C
.00 1.00 95008 04/01/95 81502
-01*
011 FITNESS FOR DUTY PROGRAM AF 2340 WJ1 C
.00 9.00 94022 11/19/94' 81502
-02*
011 FITNESS FOR DUTY PROGRAM AF 2340 WJT M
.00 4.00 S011 81601
-01*
011 -
SAFEGUARDS CONTINGCY PLAN AF 2340 WJT C
.00 1.00 95008 04/01/95 81700
-02 011 PHYSICAL SECURITY PROGRAM AF 2350 WJT M
C
.00 4.00 5011 64704
-01 012 FIRE PROTECTION PROGRAM CO 2350 PEF C 01/07/96 0
.00
.00
- COMPLETED CYCLE 11 71750
-01 012 PLANT SUPPORT ACTIVITIES to 2230 AMI M 07/05/97 Y
.00 27.00 96015 81700
-01 012 PMTSICAL SECURITY PROGRAM CO 2350 PEF P 07/05/97' C
.00 29.50 96005 10/26/M 82301
-01 012 EP EXERCISE FOR PWR RK CO 2340 KF8 C 02/05/M Z
90.00 39.00 96002 02/10/96 82302
-01 012 REVIEW ENER OBJ & SCENARIO PWR CD 2340 WNS C
Z
.00
- 4.00 96002 02/10/ %
83750 012 OCCUPATIONAL RADIATION EXPOSURE CO 2340 WGR M 01/27/97 C
.00 12.50 96004 84750
-01 012 RAD WSTE TRTMNT & EFL & ENVR MN CD 2340 'JGR M 11/04/96 C
75.00 16.50 96017 86750
-01 012 SLD RDWSTE MNGMNT & 1RANS RAD M CO 2340 KF8 M 11/04/96 C
14.00 2.00 96017 64704
-01 011 FIRE PROTECTION Co 2350 58E M 07/08/95 0
12.50 4.00 95012 NOT DONE CY 10 71750
-01 011 PLANT SUPPORT ACTIVITIES CD 2200 AMI C-Y
.00 5 00 94018 08/27/94 71750
-03*
011 PLANT SUPPORT ACTIVITIES CD 2200 RKP C
Y
.00 8.00 95001 03/04/95 71750
-04*
011 PLANT SUPPORT ACTIVITIES CO 2200 AMI C
Y
.00 65.50 95010 01/06/M 71750
-05*
011 PLANT SUPPORT ACTIVITIES CD 2230 AJ8 C
Y
.00 1.00 5011 01/06/96 71750 06* 011 PLANT SUPPORT ACTIVITIES to 2230 AMI M
Y
.00 3.50 96001 81700
-01 011 PHYSICAL SECURITY PROGRAM Co 2350 DxM C 08/22/94 C
42.00 31.00 94002 04/01/95 82301
-01 011 EP EXERCISE CO 2340 KF8 C 02/07/94 Y
27.00 52.50 94004 02/12/94 1'.70 94001 82301
-02*
011 EP EXERCISE CO 2340 GWS M
Y,
.00 9
82302
-01 011 EP SCENARIO CO 2340 KF8 C 02/07/94 Y
6.00 3.00 94004 01/22/94 82701
-01 011 EP PROGRAM Co 2340 KF8 M 08/22/94 C
17.50 18.50 95003
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
~
o
.m m
l FACILITY EIP REPORTS MASTER INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL F.IP FROt 1/1/93 - 11/22/96) 87 FUNCTIONAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
10 UNIT NAME: ST LUCIE 1 DOCKET NUMBERr 050-00335 REPORT FROM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
SALP.END DATE: / /
PROCECGE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: PLTSUP NAME: Plant s@ port SALP RATING :
1 PROC ID PERIOD TITLE / COMMENTS IPE PRI CRG EMP STS TARGET DT FRQ PLND HRS ACTL NRS IR 8 COMPLTN DT 83750
-01 011 OCCUPATIONAL EXPOSURE CO 2340 WGR M 11/13/94 C
52.50 61.50 94007 84750
-01 011 EFFLUENTS, WATER CHEM & CM CD 2340 COR P 07/01/95 C
52.50 19.00 94016 07/23/94 84750
-02*
011 EFFLUENTS, WATER CHEM & CM CO 2340 CoR P
C
.00 16.50 95006 04/08/95 84750
-03*
011 EFFLUENTS, WATER CHEM & CM CO 2340 CoR C
C
.00 20.20 95019 10/21/95 86750
-01 011 SOLID RADWASTE& TRANSPORT CO 2340 WGR P 07/01/95 C
14.00 3.00 94016 07/23/94 86750
-02*
011 SOLID RADWASTER TRANSPORT CO 2340 CoR P
C
.00 2.00 95006 04/08/95 6660
-03*
011 SOLID RADWASTES TRANSPORT CO 2340 CoR-C-
C
.00 10.00 95019 10/21/95 81700
-01 010 PHYSICAL SECURITY PROGRAM CO 2350 DxM C -09/13/93 C
5e.00 21.50 93006 04/17/93 82301
-01 010 EP EXERCISE CO 2340 KF8 C 06/23/93 Y
27.00 55.50 93016 06/26/93 82302
-01 010 EP SCENARIO CO 2340 KF8 M 06/23/93 Y
6.00 3.00 93016 84750
-01 010 EFFLUENTS, WATER CHEM & CM CO 2340 TCD C 07/12/93 C
52.50 29.00 93017 10/16/93 84750
-02*
010 EFFLUENTS, WATER CHEM & CM CO 2340 coa C
C
.00 7.50 93027 11/20/93 86750
-01 010 SOLID RADWASTE& TRANSPORT CO 2340 TCD C 07/12/93 C
14.00 6.00 93009 10/16/93 86750
-02*
010 SOLID RADWASTE& TRANSPORT CO 2340 CoR C
C
.00 3.00 93027 11/20/93 71750
-02*
012 PLANT SUPPORT ACTIVITIES RI 2250 VRM M
Y
.00 2.00 96008 81502
-02*-
012 FITNESS FOR DUTY PROGRAM RI 2410 WJT C
.00 28.00 96010 06/29/96 92904
-01*
012 FOLLOWUP - PLANT SUPPORT RI 2230 AMI M
.00 6.00 % 006 64704
-02*
011 FIRE PROTECTION Rt 2350 RKP C
0
.00 12.00 95012 07/01/95 64704
-03*
011 FIRE PROTECTION RI 2350 RKP C
0
.00 2.00 95014 07/08/95 71750
-02*
011 PLANT SUPPORT ACTIV! TIES RI 2200 STR M
Y
.00 A-50 96001 81810
-01*
011 PHYSICAL PROTECTON OF SGI RI 2340 WJT C
.00 4'.00 95008 04/08/95 82301
-03*
Olt EP EXERCISE Rt 2340 RKP M
Y
.00 3.00 95010 92904
-01*
011 FOLLOWUP - PLANT SUPPORT Rt AHI C
.00 15.50 94013 92904
-02*
011 FOLLOWUP - PLANT SUPPORT Rt AHI C
.00
.50 95004 03/04/95 64704
-01 010 FIRE PROTECTION RI 2350 GRW N 09/20/93 0
19.00
.00 83729
-01 010 OCPTNL EXP CTRL EXT OUTGS RI 2340 WGR C 04/19/93 40.00 44.00 93013 04/24/93 64704
-02*
012 FIRE PROTECTION PROGRAM RR 2350 HAM C
0
.00 1.00 96008 06/08/96 81601
-01*
012 SAFEGUARDS CONTINGCY PLAN RR 2350 DET M
.00 42.00 96016 92904
-02*
012 FOLLOWUP - PLANT SUPPORT RR 2340 KFB M
.00 24.50 96016 81601
-02*
012 SAFEGUARDS CONTINGCT PLAN RT 2350 DET M
.00 10.00 96016 2515/133-01 012 49 CFR PRTS 100-179 & 10 CFR PR 51 2340 FNW N 11/04/ %
25.00
.00 2515/123-01 011 IMPLMNT REVISED 10 CFR PART 20 SI 2340 WGR C 05/30/95 17.50 14.00 95011 06/03/95 2515/112-01 010 L EVAL CHGNS ENVRNS AT RX SI
~2200 SBE C 03/31/93 40.00 5.00 93028 11/13/93 2515/116-01 010 ACCESS AUTHORIZATION SI 2350 DET C 02/08/93 19.50 52.50 93004 02/13/93 TOTAL:
719.50 1,133.90
- - DENGTES UNPLANNED PROCEDURE
- - DENOTES GREATER THAN 45 DAYS BEYONO LAST TARGET DATE l
INFORMATION ON THIS PAGE IS FOR 0FFiCIAL USE ONLY.
I l
FACILITY CIP REPORTS MASTER INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL (MIP FROM 1/1/93 e 11/22/96)
BY FUNCTIONAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE
~
PAGE:
11 UNIT NAME " ST LUCIE 1 DOCKET NUM8ER:
050-00335 REPORT FROM DATE: 01/01/1993~
kEPORT TO DATE: 11/22/1996 SALP CTCLE ID: ALL.
SALP START DATE: I /
SALP END DATE: / /
PROCEDURE STS: ALL
'ORG CD: ALL SALP FUNCTIONAL AREA: SACV-0 NAME: Safety Assessment /ouality Verification - Operational SALP RATING :
1-PROC ID PERIOD' TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRQ PLMD NRS ACTL HRS' IR # COMPLTN DT 92702
-02*. 011 CORCTVE ACTNS VIOL & DEV OA 2200 BRC M
R
.00 4.00 94006 92700
-02*
012 ONSITE LER REVIEW RI 2320 MGT M
a
.00 36.00 96004 90712
-01*
011 IN OFFICE LER REVIEW RI 2200 58E M
R.
.00 2.00 94005
- 92700
-01*
011 ONSITE LER REVIEW RI 2200 GUM M
a
.00 12.00 96006 92702
-01*
011' CORCTVE ACTNS VIOL & DEV RI 2200 58E M
R~
.00 2.00 96005'
. 92700.
-01*
012 ONSITE LER REVIEW-RR 2230 ANI M
R
.00 142.00 96004 90712
-02*.
011 IN-OFFICE LER REVIEW RR 2200 RKP M-
'R
.00 11.00 95022 92700
-02*
011 ONSITE LER REVIEW RR 2200 RKP M
R
.00 9.00 96024 TOTAL:
.00 218.00
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DATS BEYOND LAST TARGET DATE INFORMATION ON TNIS PAGE IS FOR 0FFICIAL USE ONLY.
m O
e 6
b S
t-
}
-m m
-_m,--
4
~~,
FACILITY CIP REPORTS -
MASTE2 INSPECTION PLANNING SYSTEM
. DATE: 01/09/97
' ETL LCIP FROM 1/1/93 - 11/22/96)
Bf FUNCTIONAL' AREA
... TIME: 14:35:54.
SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
12 -
- +
. UNIT NAME: ST LUCIE 1-DOCKET NUMBER:
050-00335 REPORT FROM DATE: 01/01/1993I REPORT TO DATE: 11/22/1996L
. SALP CTCLE ID: ALL; SALP START DATE: -/ /
PROCEDURE STS: ALL ORG CD: ALL
' SALP FUNCTIONAL AREA: ENG -
NAME: Engirwering (as of 07/18/93)
SALP RATING.:'-
1 PROC l'D PERIOD-TITLE / COMMENTS IPE PRI ORG EMP-STS TARGET DT FR0 PLND MRS ACTL MRS IR # CINLYN DT
- 37550
-02*
012 ENGINEERING AF 2320 JWY M
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.00 20.00 95022.12/16/95
- 37550
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C-
.00 64.50 94015.
-38703
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- COMMERCIAL GRADE DEDICATION AF 2320 JRN M
.00 39.00 95017 i
' 92903-
-02*.011-FOLLOWUP - ENGINEERING AF 2320 JRN M
.00 5.00 96001-92720
-01*
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.00 11.00 93021 09/25/93 37550
-05' 012 ENG'INEERING' CO 2320 JWY M
C
.00 153.50 96017 37551
-01 L 012 ONSITE ENGINEERING -
CO 2230 ANI C 02/29/96 8
9.50 43.00 96004 06/08/96-
- 37551
-02 012 ONSITE ENGINCERING CD 2230 AMI-C 04/30/96 - B 9.50 18.00 96011 08/03/M 37551
-03 012 DNSITE ENGINEERING CO 2230 AMI C 06/30/96 8
9.50 '
33.50 96009 09/07/96 37551
-04: 012 ONSITE ENGINEERING CD 2230 AMI M' 08/31/96 - 8 9.50 5.00 96017 37551-
-05 012
. ONSITE ENGINEERING CO 2230 ANI N.10/31/%
8 9.50-
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- }
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-01 011' ENGINEERING CO 2320 C2C C 04/20/95 C-166.00 128.50 95005 04/29/95 -
37550
-04*
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- C
.00 2.00 96001=
37551-' -01 011 ONSITE ENGINEERING CO 2200 58E C 06/30/94 3
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-02 011
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B
- 9.50
.00 95004 03/04/95 37551
-03 011 ONSITE ENGINEERING CO 2200 58E N 10/31/94 B
9.50 46.50 95005
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-04 011 ONSITE ENGINEERING CO 2200 58E N 12/31/94 8
9.50
.00 37551
-05 011 ONSITE ENGINEERING CO 2200 SSE N.02/28/95 8
9.50
.00 37551
-06 011 ONSITE ENGINEERING-CO 2200 58E N 04/30/95 B
9.50
.00 37551- -07 011-ONSITE ENGINEERING CO 2200 S8E N 07/01/95 8
9.50
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30.00
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40.00 56.00 93025 11/06/93 90712
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.M
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-01*
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-03 011' ENGINEERING RI 2320 JRN M 12/11/95 C
.00 5.50 95012-37551
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011 DESIGN CHANGES & MODS RI 2320 STR-M C
.00 1.00 94013
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DATS BEYOND LAST TARGET DATE r
L r
INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE o N L.Y.
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FACILITY CIP REPORTS MASTER JNSPECTION PLANNING SYSTEM CATE: 01/09/97 STL (;IP FROM 1/1/93 - 11/22/96)
BY FUNCTIONAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
-13 IMIT NAME: ST LUCIE 1 DOCKET NUMBER:
050-00335 REPORT FROM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE:
/ /
SALP END DATE: / /
PROCECURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: ENG NAME: Engineering (as of 07/18/93)
SALP RATING :
1 PROC ID PERICD TITLE /COPMENTS IPE PRI ORG EMP STS TARGET DT FRQ PLND HRS ACTL HRS IR # COMPLTN 0T 38703
-02*
011 COMMERCIAL GRADE DEDICATION tl 2310 RGU M
.00 77.00 95017 92903
-01*
011 FOLLOWUP - ENGINEERING RI 2320 AMI M
.00 17.50 94020 37700
-03*
010 DESIGN CHANGES & M005 al 2320 NBE C
C
.00 2.00 93010 04/24/93 37700
-04*
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C
.00 2.00 93015
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-01*
010 INSTAL & TEST MODS tl 2200 MEA C
C
.00 38.50 93012 05/22/93 50001
-Ot*
010 STEAM GENERATOR REPLACEMENT INS RI 2350 BRC M
.00 14.50 93029
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~
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.00 21.00 96016 08/24/96 90713
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- 2200 RKP M
.00 3.00 95009 2515/124-01 012 SEISMIC ADEQUACY OF MECH & ELEC SI 2350 PEF C 08/01/96
.00
.00 CLOSED PER D. DORMAN, NRR: LPM (08/01/%); HQ TO PERFORM AUDITS AND CLOSE SIMS ITEM: USI A-46 2515/109-01 011 MOV TESTING - GL 89-10 SI 2350 CZC M 05/02/94 40.00 43.30 94011 91-18(M) (PL HRS = 80 / ACT = 79.20 ?CY9l 2515/109-01* 010 MOV TESTING - GL 89-10 SI 2350 FAJ M 10/04/93 40.00
.00 91-18M (PL HRS = 80 / ACT = 79.20) ?CY 9l TOTAL:
565.50 1,199.50
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER TRAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR OFF1CIAL USE ONLY.
o FACILITY MIP REPORTS MASTER INSPECTION PLANNING SYSTER DATE: 01/09/97 STL (MIP FROM 1/1/93 C 11/22/96)
'8Y FUNCTIONAL AREA.
TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
,14 m
. UNIT NAME: ST LUCIE 1 DOCKET NUN 8ER:
050-00335 REPORT FRCM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
SALP END DATE: / /
PROCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: MAINT NAME: Maintenance SALP RATING :
1 PROC ID PERIOD TITLE /COMENTS IPE PRI ORG EMP STS TARGET OT.FRQ PLND HRS ACTL HRS IR # COMPLTN DT 61726
-31*
012 SURVEILLANCE OBSERVATIONS AF 2230 AMI M
8
.00 3.50 96004 62700
-11 012 MAINTENANCE PRACTICES AF 2310 P
.00 13.00 96006 05/11/96 62703
-50 012 MAINTENANCE OBSERVATION AF 2310 WP8 C
M-
.00
'1.00 96006 62703 71 012 MAINTENANCE OBSERVATION AF 2310 WPB C
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.00 3.00 96009 07/06/ %
62703 2 012 MAlWTENANCE OBSERVATION AF 2310 WP8 M
M
.00 28.50 96015 62iT3
-21*
010 MAINTENANCE OBSERVATION AF 2200 MEA M
M
.00 1.00 93012
- 61726
-01 012 SURVEILLANCE OBSERVATIONS Co 2230 AMI C 02/29/96 8
10.00 20.50 96008 06/08/96-61726
-02 G12 SURVEILLANCE OBSERVATIONS CD 2230 ANI M 04/30/%
B 10.00 -
2.00 96011 61726
-03 012 SURVEILLANCE OBSEltVATIONS CO 2230 ANI N 06/30/96-8 10.00
.00 61726
-04 012 SURVEILLANCE OBSERVATIONS CO 2230 AMI N 08/31/96 8
10.00
.00 61726
-05 012 SURVEILLANCE OBSERVATIONS CD 2230 AMI N 10/31/96 8
10.00
~.00 61726
-11 012 SURVEILLANCE OBSERVATIONS CO 2310 HJC N 03/25/ %
8 40.00
.00 61726
-12 012.
SURVEILLANCE OBSERVATIONS Co 2310 PEK N 06/24/96 8
40.00
.00 61726
- 13 012 SURVEILLANCE OBSERVATIONS CO 2310 BRC N C5/20/M 8
40.00
.00 61726
-14 012 SURVEILLANCE OBSERVATIONS CO 2310 WP6 N 09/16/ %
8 40.00
.00 62703
-02 012 MAINTENANCE OBSERVATIONS CO 2230 ANI C 02/29/96 M
7.50 24.50 96004 03/30/ M 62703
-03 012 MAINTENANCE 08SERVAfl0NS CO 2230 ANI C 03/31/96 M
7.50 25.50 96006 05/11/ %
62703
-04' 012-MAINTENANCE OBSERVATIONS Co-2230 ANI C 04/30! %
M 7.50 16.00 96006 06/08/96 62703
-05 012 MAINTENANCE OBSERVATIONS CD 2230 AMI C 05/31p%.
M 7.50 14.50 96009 07/06/ % -
62703
-06 012 MAINTENANCE OBSERVATIONS CO 2230 ANI ' C 06/30/96 M
7.50 21.50 96011 08/03/ % -
62703
-07 012 MAINTENANCE OBSERVATIONS CO 2310 WPB M 01/27/97 M
.00 22.50 % 015 62703
-08 012 MAINTENANCE OBSERVATIONS Co.
2230 AHI N 08/31/%
M 7.50
.00 62703
-09 012 MAINTENANCE OBSERVATIONS CO 2230 AMI N 09/30/96 M
7.50
.00 62703
-10 012 MAINTENANCE OBSERVATIONS CO 2230 ANI N 10/3t/ %
M 7.50 '
.00 62703' 20 012 MAINTENANCE OBSERVATION CO 2310 WP6 N 03/25/%
M 40.00
.00 62703
-21 012 MAINTENANCE OBSERVATION CO 2310 WP8 4 06/24/%
M 40.00
.00 6270)
-22 012 MAINTENANCE OBSERVATION CO 2310 WPB N 05/20/ %
M 40.00
.00 62707
-01 111 2 MAINTENANCE OBSERVATION CO 2230 J7M M
M
.00 2.00 96017 73753
-01 012 INSERVICE INSPECTION CO 2310 HOC C 07/05/97 C
00 12.00 96006 73753
-02 012 INSERVICE INSPECTION Co 2310 HJC C 05/06/96 C
40.00 31.50 96008 05/18/M 61726
-01 011 SURVEILLANCE OBSERVATION Co 2200 SOE C 02/28/94 8
10.00 4.50 94001 01/29/94 61726
-02 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 04/30/94 8
10.00 13.00 94009 04/02/94 61726
-03 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 06/30/94 8
10.00 1.00 94012 04/23/94 61726
-04 011 SURVEILLANCE OBSERVATICM CO 2200 SBE C 08/31/94 8
10.00 2.00 94013 05/28/94 61726
-05 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 10/31/94 8
10.00 4.00 94015 07/30/94
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYONO LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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FACILITY CIP REPORTS MASTER INSPECTION PLANNING SYSTEl DATE: 01/09/97 STL GIP FROM 1/1/93 - 11/22/96)
BY FUNCTIONAL AREA TIME: 15:35:54 SCRTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
15 UNIT MAME: ST LUCIE 1 DOCKET NUMBER:
050-00335 REPORT FROM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START OATE:
/ /
SALP END DATE:
/ /
PRCCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: MAINT NAME: Maintenance SALP RATING :
1
~
PROC ID PERIOD TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRQ PLND ftRS ACTL HRS. IR # CCMPLTh DT 61726
-06 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 12/31/94 8
10.00 8.00 94018 08/27/94 61726
-07 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 02/28/95 B
10.00 5.50 94020 10/01/94 61726
-08 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 04/30/95 B
10.00 20.00 94022 11/05/94 61726
-09 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 07/01/95 8
10.Q0 5.00 94024 12/03/94 61726
-11*
011 SURVEILLANCE OBSERVATION CO 2200 AMI C
B
.00 8.00 95001 61726
-12*
011 SURVEILLANCE OBSERVATION CO 2200 AMI C
B
.00
.00 95004 03/04/95 61726
-13*
011 SURVEILLANCE OBSERVATION CO 2200 BFR C
B
.00 6.00 95010 06/03/95 61726
-14*
011 SURVEILLANCE OBSERVATION CO 2200 RKP C
B
.00 2.00 95009 04/29/95
,61726
-15*
011 SURVEILLANCE OBSERVATION CO 2200 AMI C
B
.00 3.50 95012 07/01/95 61726
-16*
011 SURVEILLANCE OBSERVATION CO 2200 RKP C
B
.00 6.00 95014 07/29/95 61726
-1T*
011 SURVEILLANCE OBSERVAft04 CO 2200 RKP C
B
.00 5.00 95015 09/16/95 61726
-18*
011 SURVEILLANCE OBSERVAtt0N CO 2232 RKP C
B
.00 11.00 95018 10/28/95 61726
-19' 011 SURVEILLANCE OBSERVATION CO 2230 AJ8 C
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.00 15.00 95021 12/02/95 61726
-20*
011 SURVEILLANCE OBSERVATION CO 2230 AJS C
B
.00 6.00 95022 01/06/96 61726
-21*
011 SURVEILLANCE OBSERVATION CD 2230 AJS C
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.00 1.00 5011 01/06/%
61726
-22*
011 SURVEILLANCE OBSERVATION CO 2230 AJB M
B
.00 4.00 % 001 62703
-01 011 MAINTENANCE OBSERVATION CO 2200 SBE C 01/31/94 M
7.50 4.00 94001 01/29/94 62703
-02 011 MAINTENANCE OBSERVATION CO 2200 SBE C 02/28/94 M
7.50 29.00 94009 03/26/94 62703
-03 011 MAINTENANCE OBSERVATION CO 2200 SBE C 03/31/94 M
7.50 8.00 94013 05/28/94 62703
-04~
011 MAINTENANCE OBSERVATION CO 2200 SBE C 04/30/94 M
7.50 11.50 94015 07/30/94 62703
-05 011 MAINTENANCE OBSERVATION CO 2200 SBE C 05/31/94 M
7.50 3.50 94018 08/27/94 62703
-06 011 MAINTENANCE OBSERVATION CO 2200 SBE C 06/30/94 M
/.50 11.00 94020 10/01/94 62703
-07 011 MAINTENANCE OBSERVATION CO 2200 SBE C 07/31/94 M
7.50 25.50 94022 11/05/94 62703
-08 011 MAINTENANCE OBSERVATION CO 2200 SBE C 08/31/94 M
7.50 20.50 94024 12/03/94 62703
-09 011 MAINTENANCE OBSERVATION CO 2200 SBE C 09/30/94 M
7.50 42.00 95001 03/04/95 62703
-10 011 MAINTENANCE OBSERVATION CD 2200 SBE C 10/31/94
'M 7.50 43.00 95010 07/01/95 62703
-11 011 MAINTENANCE OBSERVATION CO 2200 SBE C 11/30/94 M
7.50 4.50 95014 07/29/95 62703
-12 011 MAINTENANCE OBSERVATION CO 2200 SBE C 12/31/94 M
7.50 15.50 95015 09/16/95 62703
-13 011 MAINTENANCE OBSERVATION CO 2200 SBE C 01/31/95 M
7.50 13.00 95018 10/28/95 62703 011 MAINTENANCE OBSERVATION CO
'2200 SBE C 02/28/95 M
7.50 7.00 95021 12/02/95 62703
-15 011 MAINTENANCE OBSERVATION CO 2200 SBE C 03/31/95 M
7.50 7.00 95022 01/06/96 62703
-16 011 MAINTENANCE OBSERVATION CO 2200 SBE C 04/30/95 M
7.50 1.00 $011 01/06/96 62703
-17 011 MAINTENANCE OBSERVATION CD 2200 SBE M 05/31/95 M
7.50 16.50 96001 62703
-18 011 MAINTENANCE OBSERVATION Co 2200 SBE N 07/01/95 M
7.50
.00 73753
-01 011 ISI - OBSERVATIONS CO 2310 JVL C 07/01/95 C
16.00 30.00 94405 11/26/94
- - DENOTES UNPLANNED PROCEDURE
+ - DEN 0iES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON TMIS PAGE IS FOR 0FFICIAL USE ONLY.
m
m..
4.
FACILITY MIP REPORTS.
MASTER. INSPECTION PLANNING SYSTEM BATE: 01/09/97
, STL (MI? Fo0M 1/1/93 11/22/M )
~BY FUNCTIONAL AREA -
TIME: 14:35:54 l
SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
16-
, UNIT WARE: ST LUCIE'1.
- DOCKET NUN 8ER:
050-00335 REPORT FROM DATE: 01/01/1993:
REPORT TO DATE: 11/22/1996'
.SALP CYCLE 10: ALL
- SALP START DATE:
/ /'
- SALP END DATE: / /'
PROCEDURE STS:.ALLi ORG CD: ALL.
SALP FUNCTIONAL AREA: MAINT-NAME: Maintenance SALP RATING t
'1
- PROC. ID '. PEtt001 TITLE /CCMMENTS IPE PRI ORG EMP STS TARGET DT FRG PLND NRS ACTL NRS IR S COMPLTE DT
! 61726 1 ' 010
' SURVEILLANCE 00 SERVAT 104 CO 2200 SSE.
C 12/31/92-
-8 00 -
- 16.50 93005 03/06/95:-
l 61726
-05 010
. SURVEILLANCE OBSERVATION CO 2200 SSE C 02/28/93 8
10.00 9.50 93007.06/03/93 s
61726 606 010-SURVEILLANCE OBSERVATION CO %
2200' SOE C 06/30/93 8
10.00 28.50 93012 05/22/93-61726 07 010 -
SURVEILLANCE 00SERVATION CO 2200 $8E C 06/30/93-
.8 10.00
-28.50 93015 08/28/93 ~
61726- 010
. SURVEILLANCE 00SERVATION CO 2200 SOE C 08/31/93 8
10.00-9.00 93020 09/25/93 -
~617262 -09 010 SURVEILLANCE OBSERVAT10N
-CO 2200 SOE C 10/30/93 8-10.00 10.00 93023 11/27/93 61726 -
-12*
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-SURVEILLANCE OBSERVATION CO 2200 58E C
8-00.
9.00 93024 01/01/94 62703.-06 010-MAINTENANCE OBSERVATION CO 2200 SOE C -10/31/92 M
00 4.00 92024 01/02/93 62703
-07 010 MINTENANCE OBSERVATION CO 2200 SOE
-C 11/30/92 M
00 45.00 93002 03/06/93 62703. -08 010 MAINTENANCE OBSERVATION CO 2200 : SOE C 12/31/92-M:
.00
'19.50 93007 04/03/93 62703-
-09' 010.
MAINTENANCE OBSERVATION.
CO 2200 SOE ' C :01/31/93 M
7.50 65.00 93012 05/22/93 62703
-10 010~
MAINTENANCE OBSERVATION CO
- 2200 SSE C 02/28/93 M
T.50 47.50 93019 08/28/93 62703
-11 010 MAIN:ENANCE 08SERVATION CO 2200 SSE C 03/31/9'.
M 7.50 33.50 93022 10/23/93-62703
-12.' 010 ' ' MAINTENANCE OBSERVATION CO 2200 SOE C 06/30/93 M
7.50 11.50 93024 01/01/96.
62703. -13 010 MAINTENANCE OBSERVATION CO 2200 SSE N 05/31/93 M
7.50
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-14 010' MAINTENANCE OBSERVATION -
CO 2200 SOE N- 06/30/93 M
7.50
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7.50 00 62703'
-16 010 MAINTENANCE OSSERVATION
'CO 2200 58E. ~ N 08/31/93 M
-7.50 00
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-17 010 MAINTENANCE 00$ERVAT10N CO 2200 SSE N 09/30/93 M
7.50 00 t,
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.00
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73753
-01 010 ISI - CBSERVATIONS CO 2310 NOE C 04/19/93 C
32.50 25.00 93010 04/24/93 62706
.-02 012-MAINTENANCE RULE INSPECTION PRO 04 2310 BRC N 09/16/96 40.00
.00 -
62700
-01 012 MAINTENANCE PRACTICES RI 2310 RCN P 05/06/96 40.00 27.50 96006 05/11/96-62700
-02 012 MAINTENANCE PRACTICES RI 2310 NJC N- 05/20/96 40.00
.00 -
62700
-03.
012 MAINTENANCE. PRACTICES' Rt 2310 NJC N 08/19/96 40.00 100 62700
-04 012 MAINTENANCE PRACTICES RI 2310 N 06/15/96
- - 40.00
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.00 4.00 96006 92902
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-EROSION / CORROSION PRGMS RI 2310 RMN C
00 21.50 96405 11/26/94.
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00 20.00 94405 11/26/94.
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00 2G.00 96405 11/26/94 57070
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00
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.00 29.00 96405 11/26/96
+
- - DENOTES UNPLANNED PROCEDURE
+ - OtWOTES GREATER THAN 45 DAfS BEYOND LAST TARGET DATE
~
4
-INFORMATION ON THIS PAGE IS FOR 0 F F I C I A L -- U S'E ONLY.
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' UNIT NAME: ST LUCIE 1 DOCKET NUMBER:
050-00335 REPORT FROM DATE: 01/01/1993-REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
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PROCEDURE STS: ALL
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39.00 74.50 94020 10/01/94 71707
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39.00 44.50 94024 12/03/94 71707
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39.00 147.50 94025 03/04/95 71707
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39.00 29.50 95007 04/01/95 71707-
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39.00 41.50 95009 04/29/95 71707
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-M 39.00 63.00 95012 06/03/95 71707
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39.00 79.50 95015 09/16/95
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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MASTER INSPECTION PLANNING SYSTEM
- DATE: 01/09/97:
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BY FUNCTIONAL AREA
' TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE ~
PAGE:
22
-UNIT NAME: ST LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FROM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996-SALP CYCLE ID: ALL SALP START DATE: / /
SALP END DATE: / /
PROCEDURE STS: ALL DRC CD: ALL SALP FUNCTIONAL AREAt OPS NAME: Operations
.SALP RATING :
1 PROC 10 PERIOD' TITLE / COMMENTS IPE PRI ORG EMP STS TARGET OT FRG PLND HRS ACTL (1RS IR # CD4PLTN DT
. 71707
-15 011 MONTHLY RESIDENT CD 2200 SBE C 03/31/95 M
39.00 66.00 95018 10/28/95~
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.00 100.00 93002 03/06/93 71707
-08 010 MONTHLY RESIDENT CO 2200 58E C 12/31/92 M
.00 48.60 93007 04/03/93 71707
-09 010 MONTHLY RESIDENT CO 2200 SBE C 01/31/93-M 56.00
' 80.50 93012 05/22/93-71707
-10 010 MONTHLY RESIDENT CO 2200 $8E C 02/28/93 M
56.00 117.00 93018 08/28/93 71707- 010 MONTHLY RESIDENT CO 2200 58E C 03/31/93 M
'56.00 36.00 93020 09/25/93 71707
-12 010 MONTHLY ~ RESIDENT CO 2200 S8E C 04/30/93 M
56.00 95.50 93023 10/23/93 71707
-13 010 MONTHLY RESIDENT CO 2200 SSE C 05/31/93' M
56.00 39.00 93024 01/01/94 71707
-14 010 MONTHLY RESIDENT CO 2200 SBE N 06/30/93 M
56.00
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56.00
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-16 010 MONTHLY RESIDENT CO
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56.00
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.00 6.50 96004 71707
-19 012 PLANT OPERATl0NS RI 2230 AMI N 07/05/97 M
.00 31.20 96008
- - DENOTES UNPLANNED PROCEDURE
+, DENOTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL 'USE ONLY.
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MASTE2 INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL C.lP FROM 1/1/93 - 11/22/96)'
BY FUNCTIONAL AREA flME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
'23 UNIT NAME: ST LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FROM DATE: C1/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
SALP END DATE: / /~
PROCEDURE STS: ~ALL
' ORG CD: ALL
= SALP FUNCTIONAL AREA: OPS NAME: Operations SALP RATING :
1-FROC ID PERIOD TITLE / COMMENTS
-IPE PRI ORG EMP STS TARGET DT FRG PLMD HRS ACTL HR$ IR # COMPLTW DT 71715
-01*,012 SUSTAINED OPS OBSERVATION RI 2330 AOM M
.00 15.00 96004' 92901
-01*~012.
FOLLOWUP - PLANT OPERATIONS' Rt 2230 EDL M
.00 20.00 96006 40500-
-03*
011 SAFETY ASSESSMENT Rt 2200 KDL M
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.00 115.00 95015
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-01*
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.00 60.00 96009 03/05/94' 71707.-. -19 011.-
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.00 13.00 95004 03/04/95 92901
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2515/120-01 011 STATION BLACKOUT SI 2320 MYS C 07/08/95
.00 15.00 94006 2515/115-01 010 VERIFICATION PLANT RECORD SI 2200 C 10/30/93 4.00
.00 AD0'l 10 HR$ FROM 92-18 NOT SHOWN (RITS INITIALS: SBE)
TOTAL: 2,206.00 3,278.80
- - DENOTES UNPLAf.NED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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. 24 UNIT NAME: ST LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FROM D' ATE: 01/01/1993 REPORT TO DATE: 11/22/1996-
. SALP CYCLE 10: ALL
.SALP START DATE: / /
SALP END DATE: / /
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. PROC ID PERitX)
TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRQ PLND HRS ACTL HR$ IR # C(MPLTW DT'
. 81502
-01*
012 FITNESS FOR DUTY PROGRAM AF 2350 LKS P
.00 3.50 96019 10/26/96 81700
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.00 2.50 96019 10/26/96 82701
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011 ACCESS CONTROL - PACKAGES AF 2340 WJT C
.00 1.00 95006 04/01/95 81502
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'-01*
011 SAFEGUARDS CONTINGCY PLAN AF 2340 WJT C
.00 1.00 95008 04/01/95 64704
-01*
012 FIRE PROTECTION PROGRAM Co 2350 PEF.
C 01/07/ %
0
.00
.00 COMPLETED CYCLE 11 71750
-01 012 PLANT SUPPORT ACTIVI!!ES CD 2230 ANI M 07/05/97 Y
.00 21.00' 96014 81700
-01 012 PHYSICAL SECURITY PROGRAM Co 2350 PEF P 07/05/97 C
.00 11.00 96019 10/26/ %
B2301-
-01 012 EP EXERCISE FOR PWR RX CO 2340 JWK C
2
.00 40.00 96002 02/10/96 82302.
-01 012 REVIEW EXER OBJ & SCENARIO PWR Co 2340 WNS C
Z
.00 4.00 96002 02/10/96 83750
-01 012
.0CCUPATIONAL RADIATION EXPOSURE CO 2340 KFB M 07/05/97. C
.00 13.50 96009 84750
-01 012 RAD WSTE TRTMNT & EFL & ENVR MN CO -
2340 KFs M 07/05/97 C
.00 16.50 96017 86750
-01 012 SLD RDWSTE MNGMNT & TRANS RAD M CD 2340 KFB M 07/05/97 C
.00 2.00 96017 64704
-01 ' 011 FIRE PROTECTION CO 2350 SBE M 07/01/95 0
12.50 4.00 95012 71750
-01 011 PLANT SUPPORT ACTIVITIES CO 2200 ANI C
Y
.00 6.50 94018 08/27/94
- 71750
-03*
011 PLANT SUPPORT ACTIVITIES Co 2200 RKP C
Y
.00 13.00 95001 03/04/95 71750
-04*
011 PLANT SUPPORT ACTIVITIES CO 2200 ANI C
Y
.00 74.50 95014 01/06/96 71750
-05*
011 PLANT SUPPORT ACTIVITIES CD 2230 AJS C
Y
.00 1.00 5011 01/06/96
- 71750
-06*.
011 PLANT SUPPORT ACTIVITIES CO 2230 ANI M
Y
.00 8.50 96001 81700 101 011 PHYSICAL SECURITY PROGRAM CO 2350 DXM C 07/01/95 C
42.00 20.00 94002 02/12/94 81700
-02*
Ot1 PHYSICAL SECURITY PROGRAM CO 2350 WJT C
C
.00 12.00 95008 04/01/95 82301
-01 011 EP EXERCISE CO 2340 KF8 C 07/01/95 Y
27.00 52.50 94004 02/12/94 82301
-02*
011 EP EXERCISE CO 2340 GWS M
Y
.00 30.50 95010 82302 011 EP SCENARIO Co 2340 KF4 C 07/01/95 Y
6.00 3.00 94004 01/22/94 82701
-01 011 ~ OCCUPATIONAL EXPOSURE CO 2340 WGR M 07/01/94 C
52.50 47.00 94007 EP PROGRAM CD 2340 KFB M 07/01/95 C
17.50 18.50 95003 83750
-01 011 84750
-01 011 EFFLUENTS, WATER CHEME CM CO 2340 COR P 07/01/95 C
52.50 18.00 94016 07/23/94 8475C
-02*
011 EFFLUENTS, WATER' CHEM & CM Co 2340 CQR P
C
.00 16.50 95006 04/08/95 84750
-03*
011 EFFLUENTS, WATER CHEM & CM CO 2340 CoR C
C
.00 20.20 95019 10/21/95 86750* -01 011 SOLID RADWASTES TRANSPORT CO 2340 CQR P 07/01/95 C
14.00 3.00 94016 07/23/94 86750
-02*
011 SOLIO RADWASTEE TRANSPORT CO 2340 CQR P
C
.00 2.00 95006 04/08/95 86750
-03*
011 SOLID RADWASTE& TRANSPORT CO 2340 COR C
C
.00 10.00 95019 10/21/95
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE O N L Y..
4 J.4 a.m-m.
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~ ^
~ FACILITY YIP REPORTS'
. INLSTE2 INSPECT 10It PLANNING SYSTEM -
. DATE: 01/09/97 -
~
- STL C;IP FRWI 1/1/93. i11/22/96)
-8Y FUNCTIONAL AREA TipE: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PME:
' 25
~
LUNIT NAME! ST LUCIE 2 '
DOCKET IRDIBER:
050-00389L REPORT F904 DATE: 01/01/1993~. AEPORT TO DATE: 11/22/19961
. SALP, CYCLE 10:' ALLi
'SALP START DATE: :/ /
SALP END DATE: ' /- /.
PROCEOt2E STS: ALL
'ORG CD: ALL i SALP FUNCTIONAL AREA: PLTSUP
. IIAIE: Plant supnort.
l SALP RATING :
l' PROC 10 PERI (B TITLE /ColeqENTS' IPE. PRI :ORG.- EMP.'STS, TARGET DT FRe PLMD NRS ~ACTL NRS It'# CWWDLTN DT!
$1700~
01 010
.PNYSICAL SECURITY PROGRAM CO 2350 DIst C-09/14/92 '. C
.00 21.50 93006 04/17/93e i 82301 - -01:. 010 EP EXERCISE ~
CO
' 2340 KF8 - C- 05/26/93 Y-c 27.00 ;
67.50 93016 06/26/93.
- 82302 ' -01
- 010 EP SCENARIO:
CO '
2340LKF8 M 05/26/93 - Y..
6.00 -
. 3.00 93016 --
.84750- l 010 sEFFLUENTS, WATER CNEMS CM CO 2340 'TCD
- C
- 84750'.-02* 010
-EFFLUENTS, WATER CNEMS CM CO 2340 Cet C.10/30/93:
C~
.52.50 '
28.00 93009 10/16/93-
~
'C-
..00 6.00 93027 11/20/93 -
.86750
-01.
010 SOLIO RADWASTES TRANSPORT CO
'2340 TCD C 10/30/93-C 14.00 6.00 93009 10/16/93 -
86750
-02*.010-
.SOLIO RADWRSTES TRANSPORT CO -
2340~Com.'.
C C
.00 '
.3.00 93027 11/20/93L i
71750 '
-02*, 012 PLANT SUPPORT ACTIVITIES RI 2250 VRM -
M-Y-
'.00 2.00 96008 i
- 929041
-01*
012 '
FOLLOWUP.- PLANT SUPPORT RI 2230 AJ8 M
.00 4.00 96006
'64704'
-02*.011.
FIRE PROTECTION
- RI
~2350 IttP C
0
.00 12.00 95012 07/01/95 64704
- 71750 ~ -03*- 011' FIRE PROTECTION-RI 2350 RKP - C' O-
.00 2.00 95014 07/08/95 -
-02*
011 PLANT SUPPORT ACTIVITIES RI 2200 -STR-M
-Y
.00 5.50 94020 82301
-03*
011J EP ENERCISE RI 2340 RKP M-Y'
.00 :
13.00 95010
-92904-
-01*
011 FOLLOWUP - PLANT SUPPORT RI ANI
' C
.00 9.00 95004 03/04/95 j
64704
.-01*
010 - 1 FIRE PROTECTION RI 2350 'GRW N 09/20/93 - 0
'19.00
.00 -
i 82301.
-02*
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RI 2340 MEA ' N Y
.00 7.00 93015
- 837:!9
--01' 010
- 0CPTNL EMP CTRL EXT GUTS $
RI 2340 2R$
C 04/26/93
-40.00
- 57.00 93001 04/24/93 :
64704-
-02*
012; FIRE PROTECTION PROGRAM RR.
2350 NAM C
0
.00 1.00 96008 06/08/96-81601'
-01* - 012 SAFEGUARDS CONTIIIGCY PLAN RR 2350 DET>
M~
.00 42.00 96016 -
' 92904'-
-02*
012 FOLLOWUP k PLAlli SUPPORT.
RR 2340 KFs M
.00 24.50 96016 81601-
-02*
012 SAFEGUAROS CONTIIIGCY PLAN RT 2350 DET M
.00 10.00 96016' 2515/123-01 _011 IMPLlesi REVISED 10 CFR PART 20 SI
. 2340 WGR C 07/08/95 17.50 15.00 95011 06/03/95 -
.2515/112-01 010 L EVAL CIIGIls ENVRNS AT RK SI' 2200 58E C 10/30/93
.00 5.50 93028 11/13/93E i
- 2515/116 010 ACCESS AUTNORIZATION SI 2350 DET C 02/08/93 19.50 51.00 93004 02/13/93 t
TOTAL:
419.50.1,048.70 -
- L
- - DENOTES UNPLANNED PROCEDURE
+ - DEIIOTES GREATER TNAN 45 DAYS BEYOND LAST TARGET DATE i
INFORMATI0Il ON TMIS PAGE IS FOR OFFICIAL USE ONLY.
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. FACILITY CIP REPORTS
. MASTER INSPECTION PLANNING STSTEM DATE: 01/09/97 STL CIP FROM 1/1/93 - 11/22/96)
BY FUNCTIONAL AREA ~
. TIME: 14:35:54' SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
26 2
UNIT NAME: ST LUCIE 2 DOCKET NUMBER:
050-00389
. REPORT FROM DATE: 01/01/1993 REPORT TO DATE:_11/22/1996 '
SALP CYCLE ID: ALL --
.SALP START DATE:
/ /
SALP END DATE: / /_
PROCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: SA0V-O NAME: Safety Assessment /ouality verification - Operational SALP RATING :
1 PPOC ID PERIOD TITLE /CapWEENTS IPE PRI ORG EMP. STS TARGET DT FRQ PLND HRS ACTL int $ IR # COMPLTN DT 92702
-01*
011 CDRCTVE ACTMS VIOL & DEV OA 2200 BRC M
R
.00 7.00 94006
~92700
-02*
011 ONSITE LER REVIEW OR 2310 BRC M
R-
.00 6.00 $011 92700
-02*
012 DNSITE LER REVIEW.
RI 2320 MGY M-R
.00 20.00 96004 90712 ' -01*.011 IN-OFFICE LER REVIEW RI 2200 S8E M
R
.00 1.00 96005 92700
-01*
011
'ONSITE LER REVIEW RI 2200 GUM M
R -
.00
'15.50 94006
- 92700 -
-01*
012 ONSITE LER REVIEW RR 2320 STR M
R
.00 26.50 96003 90712
-02*
011 IN-OFFICE LER REVIEW RR 2200 AMI M
R
.00 7.00 95014 TOTAL:
.00 83.00
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER TNAN 45 DAYS BEYONO LAST TARGET DATE INFORMATION 04 THIS PAGE IS FOR 0 F F I C'I A L USE ONLY.
L 4
1n
FACILITY MIP REPORTS MASTER INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL CIP FROM 1/1/93 - 11/22/96)
.'BY FUNCTIONAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
27 UNIT NAME: ST LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FROM DAT": 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
SALP END DATE: / /
PROCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: ENG MAME: Engineering (as of 07/18/93)
SALP RATING :
1 PROC 10 PERIOD TITLE /COPMENTS IPE PRI ORG EMP STS TARGET DT FRQ PLND HRS ACTL hRjn IR f COMPLTN DT 37550
-02*
012 ENGINEERING AF 2320 JVY M
C
.00 53.00 96009 92720
-02*
012 CORRECTIVE ACit0N PROGRAM AF 2310 WPB M
.00 9.00 96007 37001
-01*
011 10 CFR 50.59 SAFETY EVALUATION AF 2320 ccS C
.00 20.00 95022 12/16/95 37550
-02*
C
.00 36.00 94015 38703
-01*
011 COMMERCIAL GRADE DEDICATION AF 2320 JRN M
.00 39.00 95017 92903
-02*
011 FOLLOWUP - ENGINEERING
-AF 2320 JRN N
.00 4.00 96001 92720
-01*
010 CORRECTIVE ACTION PROGRAM AF 2320 STR C
.00 11.00 93021 09/25/93 37550. -01 012 ENGINEERING CO 2320 C2C M 07/05/97 C
.00 36.00 96017 37551
-01 012 ONSITE ENGINEERING CO 2230 AHI C 02/29/96 8
9.50 51.00 96006 06/08/M 37551
-02 012 ONSITE ENGINEERING CD 2230 ANI C 04/30/M B
9.50 27.50 96011 09/07/ %
37551
-03 012 ONSITE ENGINEERING CO 2230 AMI M - 06/30/%
B 9.50 2.50 96017 37551
-04*
012 ONSITE ENGINEERING CO
- 2230 AMI N 08/31/96 8
9.50
.00 37551
-05*
012 ONSITE ENGINEERING CD 2230 ANI N 10/31/96 8
9.50
.00 37550
-01 011 ENGINEERING CO 2320 CZC C 07/01/95 C
126.00 122.50 95005 04/29/95 37551
-01 011 ONSITE ENGINEERING Co 2200 SBE C 06/30/94 8
9.50 3.00 95004 03/04/95 37551
-02 011 ONSITE ENGINEERING CO 2200 SBE C 08/31/94 8
9.50 30.50 95022 01/06/96 37551
-03 011 JNSITE ENGINEERING CO 2200 SBE M 10/31/94 8
9.50 6.00 96001 37551
-04 011 ONSITE ENGINEERING CD 2200 SBE N 12/31/94 8
-9.50
.00 37551
-05 011 ONSITE ENGINEERING CD 2200 SBE N 02/28/95 B
9.50
.00 37551
-06 011 ONSITE ENGINEERING CO 2200 SBE N 04/30/95 B
9.50
.00 37551
-07 011 ONSITE ENGINEERING CD 2200 SBE N 07/01/95 B
9.50
.00 37700
-01 011 DESIGN CHANGES & MODS CD 2320 Czt N 07/01/95 C
30.00
.00 37700
-01 010 DESIGN CHANGES & MODS Co 2320 FAJ C 07/26/93 C
40.00 54.50 93025 11/06/93 90712
-02*
010 IN-OFFICE LER REVIEW Co 2200 STR M
R
.00 1.00 93015 93801
-01*
012 S$FI HT P131 JJU M
.00 8.00 %201 37550
-03*
012 ENGINEERING RI 2320 PJF.
M C
.00 17.00 96011 37551
-10 012 ONSITE ENGINEERING RI 2230 AMI M 07/05/97 8
.00 3.00 96014 92720
-01*
012 CORRECTIVE ACTION PROGRAM RI 2250 MOB M
.00 30.00 96007
~
92903
.-01*
012 FOLLOWUP - ENGINEERING RI 2230 AMI M
.00 10.00 96004 37551
-08 011.
ONSITE ENGINEERING RI 2200 SBE M 07/01/95 B
9.50 15.00 94024 37700
-02*
011 DESIGN CHANGES & MODS RI 2320 STR M
C
.00 1.00 94013 37701
-01*
011 M005 NEEDING NRC APPROVAL RI 2200 JVL M
.00 10.00 94008 37828
-01*
011 INSTAL & TEST MODS RI 2200 SBE M
C
.00 31.00 94009 92903
-01*
011 FOLLOWUP - ENGINEERING RI 2320 AMI M
.00 11.00 95005 37700
-03*
010 DESIGN CHANGES & MODS RI 2320 STR M
C
.00 2.00 93015
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE
- ONLY, i
.-m.
- f FACILITY CIP REPORTS
, MASTER INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL (MIP FROM 1/1/93 - 11/22/96)'
BY FUNCTIONAL AREA
~' TIME: 14:35:54
~
SORTED BT FUNC AREA /IPE/ PROCEDURE PAGE:
' 28 UNIT MAME:'ST'LUCIE 2 '
DOCKET NUMBER:
050-00389 REPORT FROM DATE:. 01/01/1993
-REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL.
SALP START DATE:
/ /
SALP END DATE: / /
PROCEDURE STS: ALL ORG (D: ALL SALP FUNCTIONAL AREA: ENG NAME: Engineering
'(as of 07/18/93)
'SALP RATING':
1 PROC ID PERIOD
. TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRG PLMD HR$ ACTL HR$ IR # COMPLTN CT 37828
-02* _010
- INSTAL & TEST MODS RI 2200 STR P
'C~
.00~
2.00 93012 05/01/93 90712
-01 010 IN-OFFICE LER REVIEW RI 2200 STR-M 10/30/93 R
.00 8.00 9':022 90713
-01*~ 010 PERIODIC & SPECIAL REPORTS RI 2200 S8E M
.00
-2.00 93023 92700-
-01*
010
' ONSITE LER REVIEW RI 2200. SSE
'M R
.00 48.00 93023 92903
-02*
012 '
FOLLOWUP - ENGINEERING RR K270 LMW P
.00 21.00 96016 08/24/96 2515/124-01* 012 SEISMIC ADEQUACY OF MECH & ELEC SI 2350 PEF C 08/01/96
.00 00 CLOSED PER D. DORMAN, NRR: LPM (08/01/%); HQ TO PERFORM ALDITS g'
AND CLOSE SIMS ITEM: USI A-46 2515/109-01 011 MOV TESTING - GL 89-10 SI 2350 CZC M 05/02/94 40.00 43.50 94011 91-18(M) (PL HRS = 80 / ACT = 79.20 ?CY9l 93-01(M) (PL MRS,= 60 / ACT = 70) 2515/109-01 010 MOV TESTING - GL 89-10 SI 2350 FAJ M 01/25/93 40.00 42.00 93027 91-1dlM TOTAL:
399.50 831.00
- - DENOTES UNPLANNED PROCEDURE
+ - DEMOTES GREATER THAN 45 DATS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGs IS,FOR OFFICIAL USE ONLY.
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FACILITY CIP REPORTS MASTER INSPECTION PLANNING SYSTE]
DATE: 01/09/97 STL C.Id FROM 1/1/93 - 11/22/96)
BY FUNCTIONAL AREA' TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
29 UNIT NAME: ST LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FRCM DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATP:
/ /
SALP END DATE: / /
PROCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: MAINT NAME: Maintenance SALP 8tATING :
1 PROC ID PERIOD TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRQ PLND MRS ACTL HRS IR # COMPLTN CT 62703
-21' 012 MAINTENANCE OBSERVATION AF 2350 HAM C
M
.00 16.00 96009 07/06/96 62703
-22*
012 MAINTENANCE OBSE2VATION AF 2230 ARI M
M
.00 8.00 96071 62700
-02*
011 MAINTENANCE PRACTICES AF 2310 JVL M
.00 12.00 95002 61726
-01 012 SURVEILLANCE CBSERVATIONS CO 2230 AMI C 02/29/96 8
10.00 6.00 96006 61726
-02 012 SURVEILLANCE OBSERVATIONS CO 2230 AMI C 04/30/ %
B 10.00 9.00 M008 06/08/96 61726
-03 012 SURVEILLANCE OBSERVATIONS CO 2230 AMI C 06/30/96 8
10.00 9.50 96016 10/12/96 61726
-04 012 SURVEILLANCE OBSERVATIONS CO 2230 AMI N 08/31/96 8
10.00
.00 61726
-05*
012 SURVEILLANCE OBSERVATIONS CO 2230 AHt M 10/31/96 8
10.00
.00 62703
-01 012 MAINTENANCE OBSERVATIONS CO 2230 AMI C 01/31/ %
M 7.50 26.00 96004 03/30/M
'62703
-02 012 MA?NTENANCE OBSERVATICW CO 2230 AMI C 02/29/96 M
7.50 7.00 96006 05/11/ %
62703
-03 012 MAINTENANCE OBSERVATION
.CO 2230 ANI C 03/31/ %
M 7.50 15.00 96008 06/08/M 62703
-04 012 MAINTENANCE OBSERVATION CO 2230 AMI C 04/30/96 M
7.50 6.50 96009 07/06/%
62703
-05 012 MAINTENANCE OBSERVATION CO 2230 ANI M 05/31/ %
M 7.50
.54.50 96011 62703
-06*
012 MAINTENANCE OBSERVATION CO 2230 AMI N 06/30/%
M 7.50
.00 62703
-07*
012 MAINTENANCE OBSERVATION CO 2230 AMI N 07/31/96 M
7.50
.00 62703
-08 012 MAINTENANCE OBSERVATION CO 2230 AMI N 08/31/96 M
7.50
.00 62703
-09*
012 MAINTENANCE OBSERVATION CO 2230 AHI N 09/30/96 M
7.50
.00 62703
-10*
012 MAINTENANCE OBSERVATION CO 2230 AMI N 10/31/96 M
7.50
.00 62707
-01 012 MAINTENANCE OBSERVATION CO 2230 J7M C
M
.00 2.00 96017 73753
-01 012 INSERVICE INSPECTION CO 2310 HOC C 07/05/97 C
.00
.50 96008 05/18/%
61726
-01 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 02/28/94 8
10.00 3.50 94001 01/29/94 61726
-02 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 04/30/94 8
10.00 15.00 94005 03/26/94 61726
-03 011 SURVEILLANCE OBSERVATION CD 2200 SBE C 06/30/94 8'
10.00 1.00 94012 04/23/94 61726
-04 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 08/31/94 8
10.00
.00 94013 05/28/94 61726 05 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 10/31/94 8
10.00 4.50 94015 07/30/94 61726
-06 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 12/31/94 5
10.00 5.50 94018 08/27/94 61726
-07 011 SURVEILLANCE OBSERVATION CO 2200 SBE C 02/28/95 8
10.00 10.00 94020 10/01/94 61726
-08 011 SURVEILLANCE OBSERVATION CO,
2200 SSE
~C 04/30/95 8
10.00 8.50 94022 11/05/94 61726
-09 OIT SURVEILLANCE OBSERVATION CO 2200 SBE C 07/01/95 B
10.00
.00 94024 12/03/94 61726
-11*
011 SugvEILLANCE OBSERVATION CO 2200 RKP C
B
.00 13.00 95004 03/04/95 61726
-12*
011 SURVEILLANCE OBSERVATION CO 2200 AA2 C
B
.00 16.00 95010 06/03/95 61726
-13*
011 SURVEILLANCE OBSERVATION CO 2200 RKP C
B
.00 2.00 95009 04/29/95 61726
-14*
011 SURVEILLANCE OBSERVATION CO 2200 RKP C
B
.00 1.00 95012 07/01/95 61726
-15*
011 SURVEILLANCE OBSERVATION CO 2200.RKP C
B
.00 3.50 95014 07/29/95 61726
-16*
011 SURVEILLANCE OBSERVATION CO 2200 RKP C
B
.00
.00 95015 09/16/95
- - DENGTES UNPLANNED PROCEDURE
+ - DENOTES GREATER THAN 45 DAYS BEYOND LAST TARGET DATE INFORMATION ON THIS PAGE IS FOR OFFICIAL USE ONLY.
1 FACILITY CIP REPORTS MASTER INSPECTION PLANNING STSTEM OATE: 01/09/97 STL (MIP FRCM 1/1/93 - 11/22/96)
~ BY FUNCTIONAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
30 UNIT NAME: ST LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FRON DATE: 01/01/1993 REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL SALP START DATE: / /
SALP END DATE: / /
PROCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: MAINT NAME: Maintenance SALP RATING :
1 PROC ID PERIOD TITLE / COMMENTS IPE PRI ORG EMP STS TARGET DT FRQ PLND HRS ACTL RR$ IR f COMPLTN DT 61726
-17*
011 SURVEILLANCE OBSERVATION CO 2232 RKP C
B
.00 12.00 95018 10/28/95 61726
-18*
011 SURVEILLANCE OBSERVATION CO 2230 AJ8 C
B
.00 21.50 95021 12/02/95 61726
-19*
011 SURVEILLANCE OBSERVATION Co 2230 AJS C
B
.00 12.00 95022 01/06/96 61726
-20*
011 SURVEILLANCE OBSERVATION CO 2230 AJS C.
B
.00 4.00 S011 01/06/ %
61726
-21*
011 SURVEILLANCE OBSERVATION CO 2230 AJS M
8
.00 4.00 96001 62703
-01 011 MAINTENANCE OBSERVATION
. CO 2200 SBE C 01/31/94 M
7.50 4.70 94001 01/29/94 62703
-02 011 MAINTENANCE OBSERVATION CO 2200 SBE C 02/28/94-M 7.50 45.50 94009 03/26/94 62703,-03 011 MAINTENANCE OBSERVATION CO 2200 SBE C 03/31/94 M
7.50 12.00 94012 04/23/94 62703
-04 011 MAINTENANCE OBSERVATION CO.
2200 SBE C 04/30/94 M
7.50 4.00 94013 05/28/94 62703
-05 011 MAINTENANCE OBSERVATION CO 2200 SSE C 05/31/94 M
7.50 24.50 94014 07/30/94 62703
-06 011 MAINTENANCE OBSERVAft0N CO 2200 SBE C 06/30/94 M
7.50 16.50 94020 10/01/94 62703
-07 011 MAINTENANCE OBSERVATION CO 2200 SBE C 07/31/94 M
7.50 2.00 94022 11/05/94 62703
-08 011 MAINTENANCE OBSERVAftON LO 2200 SBE C 08/31/94 M
7.50
.00 94024 12/03/94 62703
-09 011 MAINTENANCE OBSERVATION CD 2200 SBE C 09/30/94 M
7.50 38.00 95004 03/04/95 62703
-10 011 MAINTENANCE OBSERVATION CO 2200 SBE C 10/31/94 M
7.50 7.50 95009 04/29/95 62703
-11 011 MAINTENANCE OBSERVATION.
CO 2200 SBE C 11/30/94 M
7.50 18.00 95010 06/03/95 62703
-12 011 MAINTENANCE OBSERVATION CO 2200 SBE C 12/31/94 M
7.50 8.00 95014 07/29/95 62703
-13 011 MAINTENANCE OBSERVATION CO 2200 SBE' C 01/31/95 M
7.50 7.00 95015 09/16/95 62703
-14 011 MAINTENANCE OBSERVAft0N CD 2200 SBE C 02/28/95 M
7.50 9.00 95018 10/28/95 62703
-15 011 MAINTENANCE OBSERVATION CO 2200 SBE C 03/31/95 M
7.50 53.00 95021 12/02/95 62703
-16 011 MAINTENANCE OBSERVATION CO 2200 SBE C 04/30/95 M
7.50 13.00 95022 01/06/%
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-17 011 MAINTENANCE OBSERVATION CO 2200 SBE C 05/31/95 M
7.50 1.00 $011 01/06/96 62703
-18 011 MAINTENANCE OBSERVATION CO 2200 SBE M 07/01/95 M
7.50 16.50 96001 73753
-01 011 ISI - CBSERVATIONS CO 2310 LJB C- 07/01/95 C
16.25 26.C3 94008 03/12/94 61726
-04 010 SURVEILLANCE OBSERVATION CD 2200 SBE C 12/31/92 B
.00 22.50 93005 03/06/93 61726
-05 010 SURVEILLANCE OBSERVATION CD 2200 SBE. C 02/28/93 8
20.00 8.50 93007 04/03/93 61726
-06 010.
SURVEILLANCE OBSERVATION CO 2200 SBE C 04/30/93 8
20.00 19.00 93012 05/22/93 61726
-07 010 SURVEILLANCE OBSERVATION CO 2200 SBE C 06/30/93 B
20.00 29.00 93015 08/28/93 61726
-08 010 SURVEILLANCE OBSERVATION CD 2200 SBE C 08/31/93 8
20.00 8.00 93020 09/25/93 61726
-09 010 SURVEILLANCE OBSERVATION CD 2200 SBE C 10/30/93 8
20.00 1.00 93022 10/23/93 61726
-12*
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.00 12.50 93023 11/27/93 61726
-13*
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.00 6.00 93024 01/01/94 62703
-06 010 MAINTENANCE OBSERVATION CO 2200 SBE C 10/31/92 M
.00 5.00 92024 01/02/93 62703
-07 010 MAINTENANCE OBSERVATION CO 2200 SBE C 11/30/92 M
.00 70.50 93005 03/06/93 62703
-08 010 MA!NTENANCE OBSERVATION CO 2200 SBE C 12/31/92 M
.00 35.50 93007 04/03/93
- - DENOTES UNPLANNED PROCEDURE
+ - DENOTES CREATER THAN 45 DATS BEYOND LAST TARGET DATE INFORMATION ON THl$ PAGE IS FOR 0FFICIAL USE ONLY.
i
c FACILITY LIP REPORTS'.
' MASTER INSPECTION PLANNING STSTEM DATE: 01/09/97
- STL (ZP FROM 1/1/93 - 11/22/96)
-87. FUNCTIONAL AREA:
TIME: 14:35:54 SORTED 8F FUNC AREA /IPE/ PROCEDURE PAGE!
- 31 UNIT NAME: ST.LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FROM DATE: 01/01/1993-. REPORT TO DATE: 11/22/1996
'SALP CYCLE ID: ALLL :SALP START DATE: / /
SALP END DATE: / /
PROCEDURE STS:.ALL ORG CD: All'
-SALP FUNCTIONAL' AREA: MAINT'
'NAME: Maintenance SALP RATING :
.1
. PROC ID.
PERIOD
' TITLE / COMMENTS IPE PRI ORG EMP STS TARGET 'DT' FRG PLND NRS ' ACTL NRS IR # C0pFLTN DT 62703
-09 010 -
MAINTENANCE OBSERVATION Co 2200 SSE 'C.01/31/93l M
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'33.00 93012 05/22/93 62703
-10 ~010
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'M 15.00 29.50 93018 08/28/93 4.62703- -11 010'
- MAINTENANCE OBSERVATION CO 2200 S8E C 03/31/93 M1 15.00 41.00 93023 10/23/93 62703
-12 010
. MAINTENANCE OBSEPVATION CD 2200 S8E C 04/30/93 M
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-13*
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-15*
010 MAINTENANCE OBSERVATION-CD 2200 SSE N 07/31/93' M 15.00
.00 62703.
-16*
010 MAINTENANCE OBSERVATION CO 2200 58E N 08/31/93 M
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.00 62703'
-17*
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- MAINTENANCE OBSERVATION CD 2200 SSE M 09/30/93-M 15.00
.00 62703 -
-18*
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.00 2.00 93029 62703 012.
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.00 17.00 96004 03/09/96
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.-20*
012 MAINTENANCE OBSERVATION RI 2350 NAM M
M
.00 2.00 96008-92902
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.00 2.00 96011 49001-
-01*
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.00 6.00 96006 03/12/94 61701.
-01 011 COMPLEX SURVEILLANCE RI-
,2310 SGR
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.00 :
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-01*'
011 REACTOR SMUTDOWN MARGlu RI 2230 AJS C
.00 3.00 Soll-01/06/96 61726
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.00 9.00 94012 62700'
-01*
011 MAINTENANCE PRACTICES RI 2310 JVL M-
.00 4.00 96006 62703 ' -19 011 MAINTENANCE OBSERVATION RI 2200 SSE M 07/01/95 M
.00 73.50 96005 62704
+01*
011 INSTRUMENT MAINTENANCE
- RI 2310'ANI M
.00 5.00 96005' 62705
-01*
011 ELECTRICAL MAINTENANCE RI 2310 JRN N
.00' 16.00 96006 73753
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'ISI'- CBSERVATIONS RI 2310 JVL M 07/01/95 C
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- 73755
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. RI.
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011 FOLLOWUP - MAINTENANCE RI 2230 ANI
'M
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-2.50 95018 -
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' COMPLEX SURVEILLANCE RI-2310 LPK M
.00
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010 INCORE/EXCORE DETECTORS RI 2350 PTB N 10/30/93 2.00
.00 61706
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010 CORE THERMAL POWER
- RI
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.00 75.00 93003 02/13/93 61726
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-11*
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.00 -
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.00 5.00 96016 l'
- - DENOTES UNPLANNED PROCEDURE
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.INFORMATION ON'THIS PAGE IS FOR 0FF1CIAL USE oNLY.
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' FACILITY El1P REPORTS-MASTER INSPECTION PLANNING SYSTEM DATE: 01/09/97 STL'(MIP fROM 1/1/93.11/22/96)
.. BT FUNCTIONAL AREA TIME: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
. 32 UNIT NAME: ST LUCIE 2
-DOCKET NUMBER:
050-00399 REPORT FRON'DATE: 01/01/1993
' REPORT TO DATE: 11/22/1996 '
SALP CYCLE.ID: ALL
.SALP START DATE: /1 /
SALD FND DATE: / /
PROCEDURE STS: ALL' ORG CD: ALL SALP FUNCit0NAL AREA: MAINT NAME: Maintenance SALP RATING :.
1
- PROC ID
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- TITLE / COMMENTS IPE PRI CRG EMP STS TARGET DT FRG PLND MRS - ACTL HRS - IR # COMPLTN DT
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011 NUCLEAR UELDING RR 2350 BRC C
.00 46.00 94010 04/09/94 73051
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011 ISI - PROGRAM RR 2310 HJC P
.00 12.00 94010 03/26/94' 73052-
-01*
011 ISI - PROCEDURES' RR NJC P
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.00-1.00 94024
' 2515/126-01 011 EVALUATION OF ON-LINE MAINTENAN SI 2200. KDL C 12/31/94 40.00
.00 94-25(C) 2500/020-01 010 ATWS - 10CFR50.62 51 SSE N 10/30/93 40.00 14.00 93024-2515/110-01 010 PRFMNCE OF S/R CV SI 2310 FAJ C 01/04/93 60.00 46.00 93001 RE0'D ONLY AT NORTH ANNA TOTAL:
814.25 -1,639.20
- - DENOTES UNPLANNED PROCEDURE
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BY FUNCTIONAL AREA tie: 14:35:54 SORTED BY FUNC AREA /IPE/ PROCEDURE PAGE:
33 UNIT NAM : ST LUCIE 2 DOCKET NUMBER:
050-00389 REPORT FRUM DATE: 01/01/1993'
- REPORT TO DATE: 11/22/1996 SALP CYCLE ID: ALL
'SALP START DATE: / /.
-SALP END DATE:./-/.
PROCEDURE STS: ALL ORG CD: ALL SALP FUNCTIONAL AREA: OTHER WAME: Other speclat area for operations (as of 0//18/93)
SALP RATING t 1.
PROC ID PERIOD
. TITLE /C0pWEENTS IPE PRI ORG EMP STS TARGET DT FRG PLND NRS ACTL NRS IR S CCDiPLTN DT-30702'
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. EMPLOYEE CONCERNS PROGRAMS SI 2200 RKP C
.00
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TOTAL:
.00 18.00
- - DENOTES UNPLANNED PROCEDURE
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1 REGION: 2~
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EA-CASE:
ABBR NAME NLNIBER NAE NUMBERS STL ST LUCIE ALL CRGANIZATION:
EMPLOYEES:
s CCDE NAME ID NAME
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- ALL EMPLOYEES **
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REPORT 87 SITE TIME: 14:33:33 PAW :'
'2 SITE:' STL' ST LUCIE UNIT-RPT/ IFS / SEG-NO ITEM REF NOR / SEVERITT SALP REPORT / STS CREATE CLOSEGUT CLSOUT CLS M UP9ATING
. ABOR EA/ WOR s NOV-ID TYPE EA-NOR SUPLMNT ~ AREA EVENT DT DATE PRJ/ACT* ORG NO.EMP INSPECTION REPORTS..
...........t........................................................................................................................
STL2' I 92-024 01 NCV 02/02/93 C 03/05/93 "02/02/93 2230
.92-024 TITLE:
-MISSED TS SURVEILLANCE DUE TO PERSONNEL ERROR
- PROC NUpWER
- 92700 STL1 N 93-001
- P21 90-05 MS C 07/01/93 06/21/93 2230 93-012 TITLE:. BROKEN SWING ARM IN A BORG-WARNER CNECK VALVE-PROC WUMBER: 92701 STL1 :
I 93-001' 01
.URI'
~ 02/23/93 C 03/05/93 04/28/95 2320 95-005 93-001 93-025
.-TITLE:
OPERASILITY DETERMINATION T VALVES PER GL 91-18 PROC NUMBER: 2515/110 001
._ STL2 --
. I 93-001 01 URI 02/23/93 C 03/05/93 04/28/95 2320 95-005 93-001 93-025-
~1 URI 03/02/93 C 03/10/93 11/25/94 2230 94-022-STL1 I 93-002 0
TITLE:
STARTUP STRAINER ISSUES
- PROC NLNWER:
i STL2
- I 93-002 01 URI 03/02/93 C 03/10/93 11/25/94 2230 94-022 STL2 I 93-005 01 VIO
- 4/1 03/31/93 C 04/12/93 12/21/93 2230 93-023 TITLE:
FAILURE TO FOLLOW COOLDOWN PROCEDURE PROC NLSWER:
STL2 I'93-008 01. VIO 4/1 00.3/93 C 06/01/93: 04/08/94 2320
.94-006 TITLE:
FAILURE TO PROVIDE ADEQUATE MEASURES TO CONTROL WELDING PROC NUMBER: 73753 STL1 I 93-012 01 ~ VIO 4/1 MS 06/21/93 C 07/01/93 03/04/95 2230 95-004
' TITLE:
INADEQUATE LPSI PUMP MAINTENANCE PROCEDURE CAUSED INSUF PROC NUMBER: 62703
.STL1 I 93-016 01 IFI 07/23/93 C 07/28/93 03/04/94 2340 94-004 TITLE:
SCENARIO PROBLEMS PROC NUMBER:
STL2 I 93-016 01 IFI 07/23/93 C- 07/28/93. 03/04/94 2340 94-004
~
STL1
, I 93-016 '02 IFI 07/23/93 C 07/28/93 03/04/94 2340 94-004
-TITLE:
PERIODIC PLANT STATUS UPDATES PROC NUMBER:
STL2 I 93-016 02 IFI 07/23/93 - C 07/28/93 03/04/94 2340 94-004
-STL1 I 93-016 03 IFI 07/23/93
-C 07/28/93 03/04/94 2340
- 94-004 TITLE:
EMERGENCY DECLARATIONS OF EMBED 0ED EVENTS PROC NUMBER:
STL2' I 93-016 03 IFI.
07/23/93 C 07/28/93 03/04/94 2340 94-004 STL1 I 93-016 04 IFI 07/23/93 C 07/28/93 03/04/94 2340 94-004 TITLE:
EXERCISE WEAKNESS - FAILURE TO~ ACTIVATE THE EOF IN A PROC WUIRER:
STL2 I 93-016 04 IFI 07/23/93 C 07/28/93 03/04/94 2340 94-004 STL1 N 93-017 LER 93-001-00 01/08/93 C 02/10/93 12/21/93 2230 93-023 TITLE:
FOUR SAFETY INJECTION MEADER ISOLATION VALVES OPEN TO PROC NUMBER:
~
INFORMATION 04 THIS PAGE IS FOR' OFFICIAL USE ONLY.
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,STL1 I 93-018 01-NCV 08/27/93
~C 09/01/93 08/27/93-.2230 93-018 TITLE:
FAILURE TO FOLLOW MOTOR OPERATED VALVE MAINTENANCE PROC PROC NUMER:
-STL1
'I 93-019 01
-IFI 09/27/93 ~ C 10/05/93 12/14/94 2230 94-024-
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FLOOR DRAIN CAPABILITY
- PROC IR5eER:
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STL1 1 93-019 02 NCV 09/27/93 C 10/05/93 09/27/93 2230 93-019.
11TLE:
URANIUM FUEL WEIGHT NONCOMPLIANCE
. PROC WUNBER:
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'STL1 1 93-022 01 VIO
- 4/2 11/22/93 - C 11/30/93 12/14/94
'2230 94-024
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FAILURE TO FOLLOW PROCEDURE FOR UMS VALVES AIR SUPPLY
. PROC NUMBER:
STL2 -
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' 11/22/93 C 11/30/93 12/14/94 2230 94-024 TITLE:
FAILURE TO *ERFORM AND DOCUMENT A 10 CFR 50.59 SAFETY PROC NUMBER:
t STL2 1 93-022 02. ~ VIO 4/2 11/22/93 C 11/30/93 '12/14/94 2230 94-024 STL1 I 93-024 01 VIO 4/1 OPS 01/28/94-C 02/09/94.08/23/94 2230 94-015 TITLE:
FAILURE TO FOLLOW AND MAINTAIN RESIN TRANSFER PROC NUMBER:
STL2 I 93-025 01 IFI 12/01/93 0 12/07/93 2350 TITLE:
REVIEW OPERASILITY OF UNIT 2 MOV MW-08-13 DURING TME
- PROC NUMBER: 37700 STL1 N 93-078 LER 93-002-00 01/28/93 C 03/22/93 12/21/93 2230 93-023 TITLE:
INA8ILITY OF EMERGENCY CORE COOLING SYSTEM VENTILATION PROC NUMBER:
STL2 N 93-082 LER 93-002-00 12/01/93 C 03/22/93 12/21/93 2230 93-023 TITLE:
MISSED SURVEILLANCE 04 REACTOR COOLANT SYSTEM PRESSURE PROC NUMBER:
i STL2 N 93 083 LER 93-001-00 01/08/93 C 03/22/93 12/21/93 2230 023 TITLE:
MISSED SURVEILLANCE FOR SAFETY INJECTION TANK SAMPLING PROC NUMBER:
STL2 N 93-129 LER 93-003-00 02/01/93 C 04/02/93 12/21/93 2230 93-023 TITLE:
DISCMARGE FROM THE SAFETY INJECTION TANKS TO TNE REACTO PROC NUMBER:
STL1 1 93-301 01
-NCV 11/24/93 C 12/02/93 11/24/93 2330 93-301 TITLE:
FAILURE TO FOLLOW PROCEDURES WHICN STATE TNE ACCESS REG.
PROC NUMBER,:
STL1 I 93-301 02-VIO 4/1. OPS' 11/24/93 C 12/02/93 08/31/94 2330 ANI 94-018 l
TITLE:
FAILURE TO FOLLOW PROCEDURAL WRITING CRITERIA PROC NUMBER: 92701 INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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REPORT BY SITE TIME: 14:33:33 PAGE:
4-SITE: STL ST LUCIE UNIT RPT/ IFS / SEQ-NO ITEM REF NBR / SEVERITY SALP REPORT / STS CREATE CLOSEOUT CLSOUT CLTiT UPDATING ABBR EA/ NBR NOV-ID TYPE EA-NBR SUPLMNT AREA EVENT DT DATE PRJ/ACT* ORG NO EMP INSPECTION REPORTS STL1 N 93-305 LER 93-003-00 03/31/93 C 05/26/93 12/21/93 2230 93-023 TITLE:
INADVERTENT START OF THE 1B EMERGENCY DIESEL GENERATOR PROC NUMBER:
STL2 N 93-370 LER 93-006-00 MS C5/13/93 C 06/28/93 01/28/94 2230 93-024 TITLE:
INADVERTENT START OF THE 28 EMERGENCY O!ESEL GENERATOR PROC NUMBER:
STL2 N 93-378 LER 93 007-00 05/21/93 C 06/29/93 04/01/95 2230 95-007 TITLE:
MANUAL REACTOR TRIP AFTER THE SIMULTANEOUS DROPPING OF PROC hiUMBER:
STL1 N 93-379 LER 93-005-00 05/30/93 C 06/29/93 03/04/95 2230 95-004 TITLE:
SHUTDOWN REQUIRED BY TS DUE TO AN UNLATCHED CONTROL ELE PROC NUMBER:
STL1 N 93-725 LER 93-006-00 09/10/93 C 10/15/93 11/25/94 2230 94-022 TITLE:
WASTE GAS RELEASES WITH METEOROLOGICAL INSTRUMENTS OUT PROC NUMBER:
STL2 N 93-999 LER 93-008-00 11/02/93 C 12/09/93 03/04/95 2230 95-004 TITLE:
MANUAL REACTOR TRIP DUE TO HIGN GAS TEMPERATURES IN THE PROC NUMBER:
STL1 I 94-002 01 NCV 03/11/94 C 03/15/94 03/11/94 2340'94-002 TITLE:
STL2
. FAILURE TO PROVIDE COMPENSATORY MEASURES PROC NUMBER: 81700 I 94-002 01 NCV 03/11/94 C 03/15/94 03/11/94 2340 94-002 STL1 I 94-004 01 IFI PLTSUP 03/04/94 C 03/09/94 03/16/95 2340 95-003 TITLE:
DEFINITION OF CONTAINMENT FAILURE PROC NUMBER: 82301 STL2 I 94-004 01 IFI PLTSUP 03/04/94 C 03/09/94 03/16/95 2340 95-003 STL1 I 94-0C4 02 IFI PLTSUP 03/04/94 C 03/09/94 10/18/94 2340 94-020 TITLE:
SITE ACCOLsNTABILITY DRILL PROC NUMBER: 82301 STL2 I 94-004 02 IFI PLTSUP 03/04/94 C 03/09/94 10/18/94 2340 94-020 STL2 1 94-005 01 NCV OPS 03/17/94 C 03/23/94 03/17/94-2230 94-005 TITLE:
MISPOSITIONED PRESSURIZER AUXILIARY SPRAY ISO VALVE PROC NUMBER: 71707 STL1 1 94-006 01 NCV ENG 03/25/94 C 04/08/94 03/25/94 2320 94-006 TITLE:
FAILURE TO REPORT EDG FAILURE AS REQUIRED BY TS PROC NWBER: 62705 STL1 I 94-006 02 NCV 03/25/94 C 04/08/94 03/25/94 2320 94-006 TITLE:
INADEQUATE DESIGN CONTROLS ON UNIT 2 SEQUENCER CHARGING-PROC NUMBER 62705 STL2 I 94-006 02 NCV 03/25/94 C 04/08/94 03/25/94 2320 94-006 STL2 I 94-005 01 VIO 4/1 04/08/94 C 04/12/94 02/17/95 2320 95-002 TITLE:
FAILURE TO FOLLOW CORRECTIVE ACTION PROCEDL*E PROC NUMBER: 37701 INFORMATION ON THIS PAGE IS FOR ' OFFICIAL USE ONLY.
l
ITEM CET*!L REPORTS IIS - INSPECTION FOLLOW-UP SYSTEM DATE: 01/09/97 ETL - 1/1/93 - 11/22/96 (BY SONINN)
REPORT BY SITE TIME: 14:33.33 FAGE:
5 SITE: STL ST LUCIE UNIT RPT/ IFS / SEQ-NO ITEM REF NBR / SEVERITY SALP REPORT / STS CREATE CLOSEOUT CLSOUT CL50UT UPDATING ABBR EA/ NBR NOV-ID TYPE EA-NBR SUPLMNT AREA EVENT DT DATE PRJ/ACa*
ORG NO EMP INSPECTION REPORTS STL2 1 94-008 02 VIO 4/1 04/08/94 C 04/13/94 02/17/95 2320 95-002 TITLE:
INADEGUATE INSPECTION & EVALUATION OF WATERHAMMER EVENT PROC NUMBER: 37700 STL1 I 94-008 03 URI ENG 04/08/94 0 04/13/94 2320 JVL TITLE:
QUALITY LEVEL OF PORY AND SRV DISCMARGE PIPING PROC NUMBER: 37700 STL2 I 94-008 03 URI ENG 04/08/94 C 04/13/94 02/17/95 2320 JVL 95-002 STL2 1 94-009 01 NCV OPS 04/28/94 C 05/02/94 12/14/94 2230 94-024 TITLE:
INCORRECT GRAPPLING CF A FUEL ASSEMBLY PROC NLMBER: 60710 STL2 I 94-009 02 URI 04/28/94 C 05/02/94 12/14/94 2230 94-024 TITLE:
ADEQUACY OF A SINGLE OPERATOR ON THE REFUELING BRIDGE
' PROC NUMBER: 60710 STL2 1 94-009 03 URI 04/28/94 C 05/02/94 12/14/94 2230 94-024 TITLE:
ADEQUACY OF REVIEW AND APPROVAL OF REFUELING CORE ALTER PROC NUMBER: 60710 STL1 N 94-010 LER 93-008-00 11/01/93 C 01/25/94 12/14/94 2230 94-024 TITLE:
INADVERTENT START OF THE 18 CONTAINMENT SPRAY PUMP DUE PROC NUMBER:
STL2 I 94-010 01 VIO 4/1 ENG 04/28/94 C 03/22/% 02/17/96 2310 BRC 96-001 TITLE:
FAILURE TO MEET WELD PREP DIMENSIONAL TOLERANCES ON PROC isUMBER: 50055 STL1 I 94-011 01 VIO 4/1 ENG 06/13/94 0 06/08/94 2350 TiiLE:
INADEQUATE CORRECTIVE ACTION FOR MOVS WHICH STALLED PROC NUMBER: 2515/10?
STL1 1 94-011 02 IFI ENG 06/13/94 0 06/08/94 2350 TITLE:
INADEQUATE RECOGNITION OF MOV TEST PRESSURE AND FLOW PROC NUMBER: 2515/109 STL1 I 94-011 03 IFI ENG 06/13/94 0 06/08/94 2350 TITLE:
LACK OF INSTRUCTIONS OR CUIDANCE FOR TRENDING PROC NUMBER: 2515/109 STL1 I 94 012 01 VIO 4/1 ENG 05/20/94 C 06/08/94 04/29/95 2230 AHI 95-009 TITLE:
INADEQUATE CORRECTIVE ACTION FOR PREVIOUS VIOLATION PROC NUMBER: 61726 STL2 I 94-012 01 VIO 4/1 ENG 05/20/94 C 06/08/94 04/29/95 2230 AHI 95-009 STL1 I 94-013 01 URI ENG 06/27/94 C 07/05/94 07/29/94 2230 94-014 TITLE:
VTM CONTROL WEAKNESSES PROC NUMBER: 37550 STL2 1 94-013 01 URI ENG 06/27/94 C 07/05/94 07/29/94 2230 94-014 STL1 I 94-013 02 DEV PLTSUP 06/27/94 C 07/06/94 03/04/95 2230 95-004 TITLE:
INADEQUATE EMERGENCY SUPPLIES IN CONTROL ROOMS PROC NUMBER: 92902 STL2 I 94-013 02 DEV PLTSUP 06/27/94 C 07/06/94 03/04/95 2230 95.004 INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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ITEM DETAIL REPORTS..
IFS - INSPECTION FOLLOW-SYSTEM.
DATE: 01/09/97
.STL - 1/1/93 - 11/22/96 (BY SONIIMI)
REPORT BY SITE' TINE: 16:33:33-LSITE: STL ST LUCIE PACE:
16:
- UNIT
- RPT/lFS/ SEO-NO ITEM REF NOR / SEVERITY SALP REPORT / 'STS CREATE - CLOSEINT < CLSOUT CLSalf
- WDATING'-
~ ASOR" EA/ NER.NOV-ID TYPE EA-NOR SUPLMNT AREA EVENT DT DATE PRJ/ACT* IRG No EMP INSPECTION REPORTS ~
+
4 STL1 I 94-016'01 URI OPS 07/29/96 C '08/11/96 08/31/M 2230
.STL2
. : USE OF N/A ST OPERATORS IN PROCEDURAL STEPS PROC NLpWER: 71707
- TITLE:
1 M-014 01-URI OPS 07/29/96 - C 08/11/94 08/31/96' 2230 018-
~
STL1-
.I 94-016-~02 NCV MS 07/29/96 C 08/11/94 07/29/94 2230 016
, TITLE:
IN0PERA8tE WRGM DUE TO MAINTENANCE ERROR PROC NLsWER: 62703 STL2-
-I 96-014 02 NCY MS 07/29/96 C 08/11/96 07/29/96 2230 016 i:
STL2
.-I 96-015 01 - V10 6/1 08/23/96 C 09/09/96 12/16/96 2230 96-026
- i TITLE:
FAILURE TO PERFORM TS REQUIRED SMUTD0hMI PROC NLSWER: 71707 STL1
-I 94-019 01 NCV OPS 10/20/96 C 10/21/96 -10/20/96 -2330 94-019 TITLEt FAILURE TO NOTIFY NRC FOR MEDICAL UPDATES PROC NUMBER: 71001 STL2
,-l 96-019. 01
.NCV OPS 10/20/96 C 10/21/96 10/20/96 2330 -
'96-019 1
- STL1
-I 96-019.02 URI OPS 10/20/96 C 10/21/96 03/30/96 2330 96-004 TITLE: JACCEPTA81LITY OF MAINTAINING AN SRO AS AN RO IN REOL PROC NUMBER: 71001
' STL2 1.96-019 02 URI OPS 10/20/96 C 10/21/96 '03/30/96 2330 96-006 STL1 1 96-019 03 IFI OPS 10/20/96 C 10/21/94 03/30/96 2330 96-004 TITLE:
CONFLICTING PROCEDURAL GUIDANCE FOR ACTIVE LICENSES PRCC NUpWER: 71001 STL2 1 96-019 03 IFI OPS. 10/20/96 C 10/21/96 03/30/96 2330 96-006 STL1 1-96-020 01 URI OPS 10/18/96-C 10/31/96 -11/25/96 2230 96-022
?
- TITLE:
1A EDG OPERASILITY CONCERNS AND CONTROL ROOM LOGKEEPING PROC NUMBER: 71707 STL1 N 96-021 LER-93-009-00 11/17/93 Cr 01/26/94 04/01/95 2230
.95-007
'[
' TITLE:
ENGINEERED SAFETY FEATURES ACTUATION DUE TO SPURIOUS PROC WUMBER:
r STL1 I 94-022. 01 VID 6/1 OPS 11/25/96 C 12/15/96 06/29/95 2230
.95-009 TITLE:
INADEQUATE CORRECTIVE ACTIONS TO NRC. VIOLATION PROC NUMBER: 71707 STL1 1 96-022 02.
VIO 4/1 OPS 11/25/96' C 12/15/94 04/29/95-2230 95-009
-TITLE:
IMPROPER MODIFICATION OF CONTROL ROOM LOGS PROC NUMBER: 71707 i
STL1 I 94-022 03 NCY OPS 11/25/96 C 12/15/96 11/25/96 2230 94-022
- TITLE:
WASTE GAS RELEASE WITH METEOROLOGICAL INSTRU OUT OF SVC PROC NUMBER: 71707 e
STL1-I 96-026 01 NCV OPS 12/16/96 C 12/19/96 12/16/94 2230 94-024 TITLE:
FAILURE TO PERFORM TS-REQUIRED PERICBIC PROC. REVIEWS PROC NUMBER: 71707 STL2 1 94-026 01
- NCY OPS 12/16/96 C 12/19/94 12/16/94 2230 94-026
. INFORMATION ON TNIS PAGE IS FOR 0FFICIAL USE O N L Y..
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' ITEM DETAll REPORTS IFS - INSPECTION FOLLOW-UP SYSTEM DATE: 01/09/97 STL - 1/1/93 + 11/72/96 (BY SONINN)
REPORT BY SITE TIME: 14:33:33 PAGE:
7 SifE STL ST LUCIE
' tMIT RPT/ IFS / SEQ-NO ITEM REF NBR / SEVERITY SAlP REPORT / STS CREATE CLOSEOUT CLSOUT CLSOUT
. UPDATING AB8R EA/ N8R NOV-ID TTPE EA-N8R SUPLMNT AREA EVENT DT DATE.
PRJ/ACT*
ORG NO EMP INSPECTION REPORTS STL1 I 94-024 02 - vio 4/1 MS 12/14/94 C 12/19/94 03/04/95 2230 95-004 TITLE:
INADEQUATE PROCESS FOR CHAhGES TO VENDOR TECH MANUALS PROC NUMBER: 71707 STL2 I 94-024 02 VIO 4/1 MS
. 12/14/96 C 12/19/94 03/04/95 2230 95-004 STL1 1 94-025 01 NCV '
ENG 01/20/95 C 01/24/95 01/20/95 2230 94-025 TITLE:
INADEQUATE DESIGN CONTROL PROC NUMBER: 37551 STL1~
N 94-058 LER 94-001-00 01/09/94-C 03/03/94 12/14/94 2230 94-024 TITLE:
MANUAL REACTOR TRIP DUE TO THE LOSS 0F THE 18 STEAM GEN PROC NUMBER:
STL1 N 94-063 LER 94-002-00 01/13/94 C 03/03/94 03/04/95
~2230 95-004 TITLE:
INADVERTENT LOAD SHED OF THE 1 A3 4160 VOLT BUS DUE TO PROC NUMBER:.
STL2 N 94-077 LER 94-001-00 02/17/94 C 03/03/94 04/01/95 2230 95-007
-TITLE:
PRESSURIZER AUNILIARY SPRAY OUT OF SERVICE CAU*ED BY A PROC WUMBER:
STL2 N 94-110 LER 94-002-00 03/16/94 C 04/22/94 03/04/95 2230 95-004 TITLE:
PRESSURIZER INSTRUMENT NO2ZLE WELD CRACKING DUE TO FABR PROC NLMBER:
STL2
- N 94-115 LER 93-005-00 01/12/93 C 04/22/94 03/04/95 2230 95-004 e
TITLE:
HIGN REACTOR COOLANT PLMP VIBRATION RESULTING IN A CONT PROC NUMBER:
STL1 N 94-138 LER 94-003-00' 04/23/94 C 05/05/94 04/01/95 2230 95-007
-TITLE:
AUTOMATIC REACTOR TRIP DURING FUNCTIONAL TESTING OF THE PROC NUMBER:
STL1 N 94 146 LER 94-004-00 04/03/94 C 05/12/94 12/14/94 2230 94 024 TITLE:
AUTOMATIC REACTOR TRIP CAUSED BY CONTROL ELEMENT DRIVE PROC NUMBER:
STL2 N 94-169 LER 94-003-00 04/23/94 C 06/01/94 04/01/95 2230 95-007 TITLE:
AUTOMATIC REACTOR TRIP DURING FUNCTIONAL TESTING OF THE PROC NUMBER:
STL2 N 94-230 LER 94-004-00 06/28/94 C 07/25/94 04/01/95 2230 95-007 TITLE:
PLANT VENT WIDE RANGE GAS MONITOR OUT OF SERVICE PROC NUMBER:
STL2 N 94-278 LER 94 006-00 07/14/94 C 08/22/94 12/03/94 2230 94-024 TITLE:
TRIP CIRCUIT BREAKER FAILURE DUE TO A BROKEN PIECE OF PROC NUMBER:
STL2 N 94-279 LER 005-00 07/08/94 C 08/22/94 12/14/94 2230 94-024 TITLE:
TS 3.0.3 ENTERED WHEN ECCSLC FOR OPERATION WAS NOT MET PROC NUMBER:
STL1 I 94-300 01 IFI OPS 11/17/94 C 11/28/94 10/12/96 2330
% -015 % -004 TITLE:
PROCEDURAL GUIDANCE FOR REMOVAL OF RCPS PRIOR TO 500 PROC NUMBER: 71707 INFORMATION ON THIS PAGE IS FOR OFFICIAL USE ONLY.
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1 ITEM DETAIL REPORTS IFS - INSPECTION FOLLOW-UP SYSTEM DATE: 01/09/97 STL - 1/1/93 - 11/22/96 (BY SONINM)
REPORT BY SITE TIME: 14:33:33 PAGE:
8
$1tEt STL ST LUCIE UNif RPT/ IFS / SEQ-NO ITEM REF NBR / SEVERITY SALP REPORT / STS CREATE CLOSEOUT CLSOUT CLSOUT UPDATING ABBR EA/ NBR NOV-ID TYPE EA-NBR SUPLMNT AREA EVENT DT DATE PRJ/ACT*
ORG NO EMP INSPECTION REPORTS STL2 N 94-332 LER 94-006-01 07/14/94 C 10/11/94 12/03/94 2230 94-024 TITLE:
TRIP CIRCUIT BREAKER FAILURE DUE TO A BROKEN PIECE OF PROC NUMBER:
STL1 N 94-349 LER 94-006-00 10/23/94 C 11/07/94 12/31/94 2230 94-025 TITLE:
CONTAINMENT INTEGRITY CUTSIDE OF FSAR ASSUMPTIONS UNDER PROC NUMSER:
STL1 N 94-376 LER 94-005-00 11/04/94 C 12/15/94 03/30/96 2230
%-004 TITLE:
INADVERTENT CONTAINMENT ISOLAil0N SIGNAL PROC NUMBER:
STL1 N 94-380 LER 94-006-01 10/23/94 C 12/15/94 12/31/94 2230 94-025 TITLE:
CONTAINMENT INTEGRITY OUTSIDE OF FSAR ASSUMPTIONS UNDER PROC NUMPER:
STL1
!95-001 01 VIO 4/1 OPS 02/23/95 C 03/06/95 01/06/96 2230 95-022 TITLE:
FAILLITE TO PERFORM TS-REQUIRED SAMPLING OF THE I AI Sli PROC NUMBER: 71707 STL2 I 95-001 02 VI3 4/1 MAINT 02/23/95 C 03/06/95 05/11/96 2230 96-006 TITLE:
- FAILURE TO FOLLOW PROCEDURE 2-LOI-T-89 PROC NUMBER: 62703 STL N 95-004 LER 94-010-00 11/24/94 C 01/04/95 03/30/96 2230 96-004 TITt
- INADVERTENT B TRAIN ENGINEERED SAFEGUARDS FEATURES ACTU PROC NUMBER:
STL1 N 95-005 LER 94-009-00 11/22/94 C 01/04/95 04/29/95 2230 95-009 TITLE:
INADVERTENT SAFETY INJECTION ACTUATION SIGNAL /CONTAINME PROC NUMBER:
STL2 1 95-005 01 VIO 4/1 ENG 06/05/95 C 06/19/95 02/17/96 2320
%-001 95-005 TITLE:
FAILURE TO IMPLEMENT DESIGN REQUIREMENT SPECIFIED IN PC/M 039-29 PROC NUMBER: 37550 STL1 I 95-005 02 _ Ult!
ENG 06/05/95 C 06/19/95 02/17/%
2320
. %-001 95-005 TITLE: - POWER SUPPLY UPGRADE FOR THE EXISTING STEAM GENERATOR WIDE RANCE PROC NUMBER: 37550 STL2 I 95-005 02 URI ENG D6/05/95 C 06/19/95 02/17/M 2320 96-001 95-005 STL2 I 95-005 03 URI ENG 06/05/95 C 06/19/95 10/28/95 2320 95-018 95-005 TITLE:
INCORE INSTRUMENT WIRING ERRORS.
PROC NUMBER: 37550 STL2 1 95-005 04 NCV ENG 06/05/95 C 06/19/95 04/28/95 2320 95-005 TITLE:
FAILURE TO PROPERLY DOCUMENT A NONCONFORMING CONDITION PROC NUMBER: 37550 STL1 I 95-007 01 NCV OPS 04/19/95 C 05/08/95 04/19/95 2230 95-007 TITLE:
FAILURE TO FOLLOW 5HUTDOWN COOLING OPERATING PROCEDURES PROC NUMBER: 71707 STL1 I 95-007 02 NCV MAINT 04/19/95 C 05/10/95 04/01/95 2230 95-007 TITLE:
FAILURE TO MAINTAIN CONFIGURATION CONTROL OF UNIT 1 ECC PROC NUMBER: 62703
'INFORMATION ON THIS PAGE 15 FOR 0FFICIAL USE ONLY.
ITEM DETAIL REPORTS liS - INSPECTION FOLLOW-Up SYSTEM STL - 1/1/93 - 11/22/96 (BY SONINN)
REPORT BY SITE DATE: 01/09/97-TIME: 14:33:33 PAGE:
9 SITE: STL ST LUCIE UNIT RPT/ IFS / SEO-MG ITEM REF NBR / SEVERITY SALP REPORT / STS CREATE CLOSECUT CLSOUT CLSOUT UF1)ATING ABBR EA/ kBR NOV-10 TYPE EA-NBR SUPL99fi AREA EVENT OT DATE
,PRJ/ACT*
ORG NO EMP INSPECTION REPORTS STL2 I 95-009 01 NCV MAINT 05/19/95 C 06/05/95 04/29/95 2230 95-009 TITLE:
MISSED SURVELLANCE OF UNIT 2 PERSONNEEL AIR LOCK..
PROC NUMBER: 61726 STL1 I 95-010 01 NCV MAINT 06/23/95 C 07/06/95 06/03/95 2230 95-010 TITLE:
MISSED SURVEILLANCE 04 1B EMERGENCY DTESEL GENERATOR.
PROC NUMBER: 61726 STL1 I 95-012 01 NCV MAINT 07/28/95 C 07/31/95 07/01/95 2230 95-012 TITLE:
FAILURE TO INVOKE THE JtiMPER/ LIFTED LEAD PROCESS.
PROC NLMBER: 62703 STL1.
I 95-012 02 NCV PLTSUP 07/28/95 C 07/31/95 07/01/95 2230 95-012 TITLE:
FAILURE TO PROPERLY TAG RADIDACTIVE MATERIALS PROC NUMBER: 71750 STL2 I 95-012 02 NCY PLTSUP 07/28/95 C 07/31/95 07/01/95 2230 95-012 STL1 1 95-015 01 VIO 4/1 OPS 10/16/95 C 10/24/95 01/06/96 2230 95-022 95-015.
TITLE:
FAILURE TO FOLLOW PROCEDURES AND BLOCK MSIS ACTUATION PROC NUMBER: 71707 STL1 I 95+015 02 VIO 4/1 OPS 10/16/95 C 10/24/95 01/06/%
2230 95-022 95-015 TITLE: - TWO EKAMPLES OF FAILURE TO FOLLOW PROCEDURES DURING RCP PROC NUMBER: 71707
. STL1 1 95-015 03 V10 4/1 OPS 10/16/95 C 10/24/95 03/30/96 2230
% -004 % -009 95-015 TITLE:
FAILURE TO FOLLOW PROCEDURE AND DOCUMENT ADNORMAL VALVE PROC NUMBER: 71707
- STL1 I 95-015 04 VIO 4/1 OPS 10/16/95 C 10/24/95 01/06/%
2230 95-022 95-015 TITLE
' FAILURE TO FOLLOW PROCEDURES D'JRING ALIGNMENT OF SHUTDOWN PROC NtMBER: 71707 STL1 I 95-015 05 VIO 4/1 OPS 10/16/95 0 10/24/95 2230 95-015 TITLE:
FAILURE TO FOLLOW PROCEDURE AND DOCUMENT A DEFICIENCY ON PROC NtMBER: 61726 STL1 1 95-015 06 VIO 4/1 MAINT 10/16/95 C 10/24/95 01/06/96 2230 95-022 95-015 TITLE:
FAILURE TO INITIAL MAINTENANCE PROCEDURE STEPS AS PROC NUMBER: 62703 STL1 1 95-015 07 VIO 4/1 OPS 10/16/95 0 10/24/95 2230 95-015 ftTLE:
FAILURE TO FOLLOW PROCEDURES DURING VENTING OF ECCS PROC NUMBER: 71707 STL1 1 95-016 01 EEI 95-180
/1 09/08/95 C 09/13/95 11/13/95 2230 95-016 TITLE:
LTOP INOPERABILITY DUE TO PORV FAILURE PROC NUMBER: 92700 STL2 I 95-016 01 eel 95-180
/1 09/08/95 C 09/13/95 11/13/95 - 2230 95-016 STL1 1 95-017 01 VIO 4/1 ENG 01/05/% 0 01/11/ %
2320 TITLE:
FAILURE TO FOLLOW PROCEDURES FOR MATERIAL CONTROLS-3 EMAMPLES PROC NUMBER: 38703 STL2 I 95-017 01 VIO 4/1 ENG 01/05/ % 0 01/11/96 2320 INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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IFS - INSPECTION FOLLOW-UP SYSTEM-DATE: 01/09/97-
~
'STL 1/1/93 - 11/22/% (sY SoNINN) -
REPORT SY SITE.
TINE: 14:33:33L LPAGE:-
It eSITE: STL. ST LUCIE UNIT-RPT/ IFS / SEQ-NO ITEM REF NOR / SEVERITY SALP REPORT / 1 STS CREATE CLOSEOUT CLSOUT' CLSOUT.
UPDATING-
' A85R EA/ NOR WOV-ID TYPE EA-NOR SUPLMNT AREA EVENT DT DATE PRJ/ACT*
ORG NO EMP INSPECTION REPORTS '
t 4...................................................................
- STL1 I 95-018 01 v!O 4/1
. OPS 11/28/95 0 12/07/95 '
2230 95-018
~
' TITLE:
- FAILURE TO FOLLOW PROCEDURES RELATING TO CONTROL OF KEYS PROC NUMBER: 71707
- STL1.
I'95-018 02.
VIO 4/1 OPS 11/28/95 0 12/07/95 2230 018 TITLE:
FAILURE TO FOLLOW CLEARANCE PRuCEDURES.
PROC NUMBER: 71707
~
~ _.
STL2 I 95-018 03 VIO A/1 MAINT 11/28/95 0 12/07/95 2230 95-018 TITLE:
FAILURE TO ADEQUATELY DES!GN A*C TEST THE EMERGENCY FROC IRMBER: 61726
I 95-018-04
- NCV MAINT.11/28/95 : C 12/07/95 10/28/95 2230 95-018-STL2 TITLE:
- INADEQUATE VERIFICATION OF ICI WIRING CONNECTIONS PROC NUMBER: 92902-STL1
- I 95-018 -05 NCV e
MAINT -11/28/95 C 12/07/95 10/28/95 2230
_95-018 TITLE:
MISSED SURVIELLANCE 04 CEA POSITION INDICATION.
PROC NLB40ER: 61726 STL2 I 95-018' 06 NCV
. MAINT. 11/28/95 - C 12/07/95 10/28/95
,2230 95-018 TITLE:
MISSED RCS BORON CONCENTRATION SURVEILLANCE DURING MODE 6 PROC NUMBER: 61726
. STL1 I;95-020.01
. EEI 95-222
/1 ENG 10/26/95 C 11/16/95 11/28/95 2230 96-011 95-020 TITLE:
FAILURE TO TAKE PROMPT CORRECTIVE ACTIONS FOR RELIEF PROC RRMBER: 92700 STL2 1 95-020 01 eel 95-222
/1 ENG ~ 10/26/95 C 11/16/95 11/28/95 2230 96-011 96-020 95-020
~
- STL2 I 95-021 -01 V10 4/1 OPS.
12/08/95 0 12/28/95 2230-95-021' TITLE:
FAILURE TO FOLLOW CLEARANCE ;W3CEDURE'S
- PROC NUMBER:..71707 STL2 1 95-021 '02 v10 4/1 OPS 12/08/95 - 0 12/28/95 2230 95-021
- TITLE:
FAILUPE TO FOLLOW TNE EQUIPMENT CLEARANCE ORDER PROCEDURE PROC NUMBER: 71707 3
1 STL2.
I 95-021 03 VIO -
4/1 MAINT 12/08/95' O 12/28/95 2230 95-021 TITLE:
FAILURE TO PERFORM RCP SYSTEM 90RON SURVEILLANCE
~ PROC NUMBER: 61726
' STL1 I 95-022 01-IFI 01/09/96 0 01/17/ M 2320 71TLE:
COMPLE1 ION OF CERTIFICATION PROGRAM FOR QUALIFIED SAFETY PROC NUMBER: 37001 STL2 I 95-022 01 IFI 01/09/% 0 01/17/M 2320 STL1
- I 95-022 02 NCV OPS 01/09/96 C 02/28/96 01/16/%
2320
'95-022 TITLE:
FAILURE TO PROPERLY IMPLEMENT TEMPORARY CMANGE CONTROLS PROC NUMBER: 71707 STL2 I 95-022 02 NCV OPS 01/09/96 C - 02/28/M 01/16/M 2320 95-022
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' STL1 I 95 022 03 IFI ENG 01/09/96 0 02/28/%
2320 TITLE:
SG LEVEL CNANNEL IN ACCURACEIS DUE TO SENSING LINE BLOCKAGE.
PROC NUMBER: 93702 STL2 I 95-022 03 IFI ENG - 01/09/96 0 02/28/M 2320
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INFORMATION ON TNIS PAGE IS FOR 0FFICIAL USE ONLY.
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.liEit DETAIL REPORTS IFS - INSPECTION FOLLOW-UP SYSTEM DATE: 01/09/97
- STL T/1/93 - 11/22/% (BY SONINN)
REPORT BY SITE
- TIME: 14:33:33 PAGE:
11 SITE: STL - ST LUCIE UNIT RPT/lFS/ SEQ-NO ITEM REF NBR / SEVERITY SALP REPORT / STS CREATE CLOSEQUT' CLSOUT CLSOUT UPDAtlWG ABBA EA/ W84 NOV-ID TYPE EA-NBR SUPLMNT AREA EVENT DT DATE PRJ/ACT*
ORG WO EMP INSPECTION REPORTS SYL1 N 95-061 LER 95-001-00 02/16/95 C 03/21/95 01/06/96 2230 95-022 TITLE:
1A3 4160 VOLT BUS LOAD SHED DURING REPLACEMENT OF FAILE PROC NUMBER:
STL2 N 95-062' LER 93-007-01 05/21/93 C 03/21/95 04/01/95 2230 95-007 TITLE:
MANUAL REACTOR TRIP AFTER THE SIMULTANEOUS DROPPING OF PROC NUMBER:
STL2
.N 95-080 LER 95-002-00 02/21/95 C 03/31/95 06/08/96 2230
% 008
- TITLE
AUTOMATIC REACTOR TRIP 04 LOW STEAM GENERATOR WATER PROC NUMBER:
STL2.
N 95-081 LER 95-001-00 02/21/95 C 03/31/95 06/08/M 2230 96-008 TITLE:
- LOW PRESSURE SAFETY INJECTION PUMP FOUND TO BE INOP PROC NUMBER:
STL1 N 95-088 LER 94-010-01 11/24/94 C 04/25/95 04/29/95 2230 95-009 TITLE:
INADVERTENT B TRAIN ENGINEERED SAFEGUARDS FEATURES ACTU PROC NUMBER:
STL1 4 95-092 LER 94-009-01 11/22/94 C 04/25/95 03/30/96 2230 009 %-004 title:
INADVERTENT SAFETY INJECTION ACTUATION SIGNAL /CONTAINME PROC NUMBER:
STL1 N 95-093 LER 94-008-01 11/04/94 C 04/25/95 04/29/95 2230 95-009 95-009 95-009 TITLE:
INADVERTENT CONTAINMENT 150LAil0N SIGNAL PROC NUMBER:
STL1 N 95-098 LER 93-005-01 05/30/93 C 05/12/95 03/04/95 2230 95-004 TITLE:
SHUTDOWN REQUIRED BY is DUE TO AN tlNLATCHED CONTROL ELE PROC NUMBER:
STL2 N 95-127 LER 95-003-00 04/10/95 C 06/08/95 06/08/ %
2230 95-022 W OO8 TITLE:
MISSED TECHNICAL SPECIFICATION SCHEDULED SURVEILLANCE DUE TO PROC NUMBER:
STL1
'N 95-150.
LER 95-002-00 05/26/95 C 06/27/95 '06/08/ M 2230 022 % -008 95-002 TITLE:
MISSED EMERGENCY DIESEL GENERATOR SURVEILLANCE PROC NUMBER:
STL1 N 95-181 LER 95-003-00 07/08/95 C 08/10/95 10/17/95 2230 95-003 TITLE:
AUTOMATIC REACTOR TRIP DURING TURBINE OVERSPEED SURVEILLANCE PROC NUMBER:
STL1~
N 95-195 LER 95-005-00 08/09/95 0 08/28/95 2230 TITLE:
PRESSURIZER POWER OPERATED RELIEF VALVES (PORV)
PROC NUMBER:
STL1 N 95-1%
LER 95-006-00 08/10/95 0 08/28/95 2320 TITLE:
LOSS OF REACTOR COOLANT INVENTORY THROUGH A SHUTDOWN
. PROC NUMBER:
STL1 N 95-205 LER 95-007-00 08/17/95 0 08/31/95 2230 TITLE:
INADVERTENT CONTAINMENT SPRAY VIA 1A LOW PRESSURE PROC NUMBER:
INFORMATION ON THIS PAGE IS FOR 0FF1CIAL USE ONLY.
g.
- ITEM DETAIL REPORTS IFS + INSPECTION FOLLOW-tp SYSTEM DATE: 01/09/97 STL 1/1/93 - 11/22/96 (BY SONINM)
REPORT BY SITE TIME: 14:33:33 PAGE:
12 SITE: STL ST LUCIE UNIT RPT/ IFS / SEQ-NO ITEM REF NBR / SEVERITY SALP REPORT / STS CREATE CLOSEOUT CLSOUT CLSOUT UPDATING
- A884 EA/ N8R NOV-ID TYPE EA-N8R SUPLMNT' AREA EVENT DT DATE~
PRJ/ACT*
ORG NO EMP INSPECTION REPORTS STL1 N 95-206
'LER 95-004-00 08/01/95- 0 08/31/95 2230 TITLE:
HURRICANE ERIN AT ST. LUCIE PROC NUMBER:
STL1 -
N 95-231 LER 95-003-01 07/08/95 0 10/17/95 2230 TITLE:
AUTOMATIC REACTOR TRIP DURING TURBINE OVERSPEED' PROC NUMBER:
~ STL1 N 95-233 LER 95-006-00 08/28/95 0 10/19/95 2230 TITLE:
HIGN PRESSURE SAFETY INJECTION PUMP OPERATION DURING PROC NLMBER:
~
STL2 -
h 95-254 LER 95-004-00 10/10/95 0 11/07/95 2230
-TITLE:
REACTOR COOLANT SYSTEM INSTRUMENT N0Z2LE LEAKAGE CAUSED PROC NUMBER:
STL1
-N 95-268 LER 95-009-00 10/19/,95 0 11/24/95' 2230 TITLE:
MISSED TECHNICAL SPECIFICATION SCHEDULED SURVE!LLANCE PROC NUMBER:
STL1 N 95-297 LER 95-010-00 11/16/95 0 12/19/95 -
2230 TITLE:
MANUALLLL REACYOR TRIP DUE TO LOW STEAM GENERATOR WATER PROC NUMBER:
STL2 N %-001 LER 95-005-00 11/20/95 0 01/03/%
2230*
%-011 TITLE:
2A [MERENCY DIESEL GENERATOR RELAY SOCKET FAILURES DUE PROC NUMBER:
STL1 I %-001 01 V10 4/1 OPS 03/18/96 0 03/22/%
2320 W 004 W 999 TITLE:
TEMPORARY CHANGES TO PROCEDURES IMPROPERLY CHANGED PROC NUMBER: 40500 STL2 I % -001 01 VIO 4/1 OPS 03/18/%. 0 03/22/96 2320 STL1' I % -001 02 URI MAINT 03/18/96 C 03/22/ % 03/30/96 2320
% -004 % -001 TITLE:
IMPROPER HEALTN PHYSICS PRACTICES.
PROC NUMBER: 62703
. STL1 I W OO1 03 IFI OPS 03/18/ % C 03/22/96 0~/08/96 2320
% -008 6
TITLE:
CONFORMANCE WITN FSAR ASSUMPTIONS ON ECCS LEAKAGE PROC NUMBER: 71707
- STL2 1 % -001 03 IFI OPS 03/18/M C 03/22/96 06/08/ %
2320
% -008 STL1 I 96 003 01 EEI
%-640 -
/1 OPS 02/22/% C 02/28/96 03/28/M 2320
%-003 ilTLE:
OPERATORS FAILED TO FOLLOW PROCEDURES FOR BORON DILUTION PROC NUMBER: 92700 STL2 1 96 003 01 EEI 96 040
/1 OPS 02/22/% C 02/28/96 03/28/ %
2320
% -003 STL1 I %-003 02 EEI
%-040
/1 OPS 02/22/96 C 02/28/% 03/28/ %
2320
% -003 TITLE:
INADEQUATE DESIGN CONTROL OF REACTOR COOLANT SYSTEM BORON PROC NUMBER: 92700 STL2 1 96-003 02 EEI
% -040
/1 OPS 02/22/96 C 02/28/M 03/28/ %
2320 W OO3 STL1 I 96 003 03 EEI 96-040
/1 OPS 02/22/ % C 02/28/ % 03/28/96 2320
%-003 TITLE:
INADEQUAE 10 CFR 50.59 SAFETY EVALUATION OF CHANGE TO PROC NUMBER: 92700 STL2' I W OO3 03 EEI
% -040
/1 OPS 02/22/96 C 02/28/% 03/28/M 2320
%-003 INFORMATION ON THIS PAGE IS FCA 0FFICIAL USE ONLY.
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~ IFS - INSPECTION FOLLOW-UP SYSTEM' DATE:'01/09/97 -
-STL.1/1/93 - 11/22/96 (BY SONINM)
REPORT BY SITE
, TIIE:' 14:33:33 L
' PAGE:
, 13
- , SITE: STL -ST LUCIE,
' UNIT:
'RPT/lFS/ SEO-No ITEM REF NOR / SEVERITY SALP REPORT / STS ' CREATE. CLOSEGUT. CLSOUT CLSOUT
. UPDATING
.A884
- EA/ NOR NOV-ID TYPE EA-NSR ~
SUPLMNT-AREA EVENT DT DATE
...................'............................................................ PRJ/ACT*. ORG NO EMP INSPECTION REPORTS
.STL1 I W OO4 01 VID
. 4/1 OPS
'04/29/96 0 05/08/96
- 2230'
--TITLE:
FAILURE TO FOLLOW PROCEDURES LEAD TO UNIT 1 CONTAINMENT PIG PROC NUMBER: 71707 l
STL1~
.I 96-004
FAILURE TO MAKE REQUIRED LOG ENTRIES PROC WLMBER: 71707 i
STL1 I 96-004 03 VIO 4/1 OPS 04/29/96 0 05/08/96 2230 TITLE:
FAILURE TO FOLLOW PROCEDURES RESULTS IN EMERGENCY DIESEL PROC NUMBER: 71707' STL1 I 96-004 04 VID 4/1 MAINT 04/29/M 0 05/08/96 2230 TITLE:
FAILURE TO A00UATELY REVIEW TEST DATA AND IDENTIFY.
PROC MlmBER: 62703 STL1 1 % -004 05 URI.
OPS 04/29/96
'C 05/08/M 07/12/96 2230 96-012 96-006 TITLE:
CONFIGURATION CONTROL MANAGEMENT PROC NLNWER: 71707 STL2
..I W OO4 05 URI
. OPS 04/29/96 _ C 05/08/96 07/12/96 2230
.W O12
-STL1
~ I WOO 4 U 06 NCV 04/29/96 C 08/12/96' 03/30/96
'2230 96-004 TITLE:
FAILURE TO FOLLOW CONTAMINATION CONTROL PROCEDURES PROC NLMBER:
STL2 I, W OO4 06 ~ NCV 04/29/96 C 08/12/96 03/30/96 ~ 2230
%-004-STL1
'I % -004 07.
'04/29/96 C. 08/12/96' 03/30/96 2230
%-004 TITLE:
INADEQUATE PROCEDURE LEADS TO SWITCMYARD MISALIGNMENT.
PROC NUMBER:
STL1 I W OO4 08 NCV 04/29/96 C 08/12/96 03/30/%
2230 96-004 TITLE:
FAILURE TO LOG AN 005 CEA IN THE EQUIPMENT CUT-OF SERVICE LOG PROC NLMBER:
t STL1-I W OO4 09 URI Et:C 04/29/96 C 11/21/96 03/30/96 2230
% -004 W O15 W O12 l
TITLE:
FAILURE TO UPDATE UFSAR PROC WUMBER: 71707 96-008 96-006 STL2.
I % -004 09 URI-ENG 04/29/96, C 11/21/% 03/30/96 2230 96-004 96-015 W O12 STL1 1 % -004 10 NCV MAINT 04/29/% C 12/18/% 03/30/%
2230 W OO4 TITLE:
. IMPROPER' HEALTH FMYSICS PRACTICES PROC NUMBER: 62703 STL1 I % -005 01 NCV 05/31/ % C 06/05/ % 05/03/96 ' 2350
%-005 '
~
TITLE:
FAILURE TO PROPERLY PROTECT PORTIONS OF THE PROTECTED PROC NUMBER:
STL2 1 % -005 01 NCY 05/31/96 C 06/05/M 05/03/% - 2350
%-005 STL1.
I %-006 01 NCY OPS 06/07/96 C 06/26/96 05/11/96 2230
- W OO6 TITLE:
FAILURE TO CONSIDER FIRE BARRIER OPERABILITY IN ENGINEERING' PROC NUMBER: 71707 STL1 I W OO6 02 NCV MAINT 06/07/ % _ C 06/26/96 05/11/96 b230 W OO6 TITLE:
FAILURE TO DOCUMENT VERIFICATION OF CURRENT PROCEDURE PROC NUMBER: 62703 INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE- 0NLY.
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m ITEM DETill REPORTS' IFS - INSPECTION FOLLOW-UP SYSTEM DATE: 01/09/97 STL - 1/1/93 - 11/22/96 (BY SONINN)
REPORT BY SITE
. TIME: 14:33:33 PAGE:
14 SITE: STL ST LUCIE
' UNIT'
~RPT/ IFS / SEQ-NO ITEM REF N8R / SEVERITY 'SALP REPORT / STS CREATE CLOSE0!JT CLSOUT CLSOUT UPDATING
'AS8R EA/ N8R NOV-ID TYPE EA-NBR SUPLMNT AREA EVENT OT DATE PRJ/ACT*
ORG NO EMP INSPEtit0N. REPORTS STL1
'I 96 006 03 NCV 06/07/96 C 06/26/96 05/11/96 2230
%-006
' TITLE:
FAILURE TO PROMPTLY DOCUMENT A NGJCONFORMING CONDITION.
PROC NLMBER:
.STL2 I 96 006 03 NCV 06/07/M C 06/26/ % 05/11/96 2230
- @ 006 STL1 I 96 006 04 NCV ENG 06/07/96 C 06/26/96 05/11/96 2230 W OO6 TITLE:
UNIT 1 1CW ORIFICE FOUND MISSING PROC WUMBER: 37551
-STL1 1 96 006 05 - VIO 4/1 PLTSUP 06/07/96 0 06/26/ %
2230 TITLE:
FAILURE TO MAINTAIN QUALIFICATIONS OF FIRE BRIGADE MEMBERS
. PROC NUMBER: 92904 STL2-I 96 0 % 05 VIO 4/1 PLTSUP 06/07/96 0 06/26/96 2230 "STL1 I M-008 01 NCV OPS 07/08/96 C 07/18/96 06/08/ %
2230 W OOS TITLE:
FAILURE To MAINTAIN OPERABILITY OF TWO WIDE RANGE NUCLEAR PROC NUMBER: 71707 STL1 I 96-008 02 NCV MAINT 07/08/96' C 07/18/96 06/08/96 2230
%-006 TITLE:
. FAILURE TO VERIFY MAINTENANCE PROCEDURE USED AT WORESITE PROC NUMBER: 62703 STL1 I % -006 03 URI MAINT 07/08/96 0 07/18/96 2230 TITLE:
ADEQUACY OF DOCUMENTATION FOR REPEATED PROCEDURE STEPS.
PROC NUMBER: 62703 STL2 1 96 008 03 URI MAINT 07/08/% 0 07/18/96 2230 STL1 I 96 008 04 NCV MAINT 07/08/96 C 07/18/96 06/08/ %
2230 96-008 TITLE:
FAILURE TO FOLLOW PROCEDURE WHEN PERFORMING IV.
PROC NUMBER: 62703 STL1 I W OO8 05 URI ENG 07/08/96 0 07/18/96 2230 TITLE:
LICENSEE IDENTIFIED 11 UTSAR DEFICIENCIES PROC NUMBER: 37551 STL2 I 96-008 05 URI ENG 07/08/ %
0' 07/18/ M 2230 STL1 1 96-008 06 VIO 4/1 OPS 07/08/ % W 07/18/%
2230 TITLE:
FAILURE TO FOLLOW PROCEDURE DURING EDG TESTING PROC NUMBER: 71707 STL1 1 96-009 01 VIO 4/1 OPS 08/05/96 0 08/26/96 2230 TITLE:
FAILURE TO CONTROL OVERTIME PROC NUMBER: 71707 STL2 1 % -009 01 VIO 4/1 OPS 08/05/96 0 08/26/M 2230 STL1 1 96-009 02 vio 4/1 MAINT 08/05/M
- 0. 08/26/96 2230 iITLE:
INADEQUATE PROCEDURE FOR MANAGING OVERTIME.
PROC NUMBER: 71707 STL2 I % 009 02 v!O 4/1 MAINT 08/05/M 0 08/26/M 2230 STL1 I 96-009 03 VIO 4/1. MAINT 08/05/M 0 08/26/96 2230 TITLE:
FAILURE TO TEST THE REACTOR CAVITY PRESSURE RELIEF DAMPERS PROC NUMBER: 62703 STL2 I W OO9 03 - V10 4/1 MAINT 08/05/% 0 08/26/%
2230 INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
a-ITEM DETAIL REPORTS-IFS. INSPECTION FOLLOW-UP STSTEM DATE: 01/09/97.
STL - 1/1/93 - 11/22/96 (8v SONINN)
REPORT SY SITE TIME: 14233:33-PAGE:
~ 15 SITE: STL ST LUCIE UNIT RPT/lFS/ SEO-No ITEM REF NBR / SEVERITY SALP REPORT / STS CREATE CLOSEQUT CLSOUT CLSOUT.
UPDATING A88R -
EA/ NBR NOV-ID TTPE EA-NBR SUPLMNT AREA EVENT DT DATE
.PRJ/ACT*
ORG NO EMP INSPECTION REPORTS STL1 I W OO9 04 VIO 4/1 MAINT 08/05/96 0 08/26/96 2230 TITLE:
FAILURE TO PERFORM ADEQUATE TESTING ON THE REACTOR CAVITY PRESSU PROC NUMBER: 62703 STL2 I W OO9 04 V10 4/1 MAINT 08/05/96 0 08/26/96 2230 STL1
.I % -009 05 NCY MAINT 08/05/96 C 08/26/96 07/06/96 2230 W OO9 TITLE:
FAILURE TO PERFORM PROPER POST MAINTENANCE TESTING OF NCV 25-1 PROC NUMBER: 62703 STL1 I % -009 06 V10 4/1 PLTSUP 08/05/96 0 08/26/M 2230 TITLE:
FAILURE TO CONTROL CONTAMINATED TOOLS IN ACCORDANCE WITN PROC NUMBER: 83750 STL1
. I W O10 01 IFI PLTSUP 07/26/96 0 08/02/96 2350
. TITLE:
FFD STAFF REORG AND CORRECTIVE ACTION PROC NUMBER: 81700 STL2 t %-010 01 IFl PLTSUP 07/26/ % 0 08/02/96' 2350 STL1 I M-011 01 IFI OPS 08/31/96 C 09/25/% 09/07/ %
2230
% -014 % -011 TITLE:
ADEOUACTOF ROOT CAUSE INVESTIGATION FOR UNIT 1 CNARGlWG SYSTEMS PROC NUMBER: 71707 STL1 I %-011 02 NCV PLTSUP 08/31/% C 09/25/96 08/03/M 2230 96-011 TITLE:
FAILURE TO 08TAIN ORIONATOR'S CONCURRENCE DURING STAR CLOSEOUT PROC NUMBER: 40500 STL2 1 96-011 02 NCV PLTSUP 08/31/% C 09/25/% 08/03/M 2230*
W O11 STL1 I %-011 03 NCV MAINT 08/31/96 C 09/25/96 08/03/M. 2230 W O11 TITLE:
FAILURE TO PROPERLY MONITOR FREEZE SEAL PROC NUMBER: 62703 STL1 I W O11 04 Vt0 4/1 ENG 08/31/ %
- 0. 09/25/ %
2230 TITLE:
PRECONDITIONING OF VALVES PRIOR TO SURVEILLANCE PROC NUMBER: 62703 STL2 I %-011- 04 VIO 4/1 ENG 08/31/96 0 09/25/96 2230 STL1 I W O11 05 URI 08/31/96 0 09/25/M 2230 TITLE:
DISCREPANCIES IN AFAS CALIBRATION DATA PROC Mlm8ER:
STL1 1 %-011 06 URI ENG 08/31/ % C 09/25/% 11/25/ %
2230
% -022 % -014 TITLE:
UNIT 1 NI WIRING ERRORS PROC NUMBER: 71707 STL1 I 9 -012 01 NCV ENG 07/26/ % C 10/28/M 09/17/96 2230 W O12 TITLE:
FAILURE TO INCORPORATE SFP MEAT LOAD CALCULATION REQUIREMENTS PROC NUMBER: 37551 STL1 -
I W D13 01 VIO 4/1 ENG 10/16/ % 0 11/07/%
2310 TITLE:
FAILURE TO INCLUDE ALL STRUCTURES, SYSTEMS, AND COMPONENTS PROC WUMBER: 62706 STL2 I W O13 01 VIO 4/1 ENG 10/16/ % 0 11/07/M 2310 STL1 1 96-013 02 VIO 4/1 ENG 10/16/96 0 11/07/ %
2310 TITLE:
FAILURE TO ESTABLISM PERFORMANCE CRITERIA C0fmENSURATE WITN PROC NUMBER: 62706 STL2 I W O13 02 VIO 4/1 ENG 10/16/ % 0 11'/07/ M 2310 NOTE: DEFINITION FOR CNARACTER PRECEEDING REPORT NO: I = INSPECTION REPORT NUMBER, E = EA NUMBER (ENFORCEMENT / NOV ITEM)
N = IFS NUMBER, NUMBER USED TO IDENTIFY NON-INSPECTION ITEMS INFORMATION ON TN!'S PAGE IS FOR 0FFICIAL USE ONLY.
. ~,
ITEM DETAIL REPORTS IFS - INSPECTION FOLLOW-UP SYSTEM DATE: 01/09/97 STL 1/1/93 - 11/22/96 (BY SONINM)
~
REPORT BY SITE TIME: 14:33:33 PAGE:
16
-SITE: STL ST LUCIE UNIT ~
RPT/lFS/ SEQ-NO ITEM REF kBR / SEVERITY SALP REPORT / STS CREAL CLOSEOUT-CLSOUT CLSOUT UPDATING A88R EA/ NBR NOV-ID TYPE EA-NBR SUPLMNT AREA EVENT DT DATE PRJ/ACT* ORG NO EMP INSPECTION REPORTS
' STL1
'I %-013 03 VIO 4/1 ENG 10/16/96 0 11/27/96~
. 2310 TITLE:
FAILURE TO FOLLOW PROCEDURES FOR IMPLEMENTATION OF THE MAINTENAN PEOC NUMBER: 62706
' STL2 I %-013 03 - VIO 4/1 ENG 10/16/96 0 11/27/96 2310 STL1 1 % -013 04 ift ENG 10/16/% 0 12/11/96 2310 TITLE:
FOLLOWUP DN LICENSEE ACTIONS TO PROVIDE PERFORMANCE -
PROC NUMBER: 62706 STL2 I % -013 04 IFI ENG 10/16/96 0 12/11/96 2310 STL2 I 96-014 01 NCY OPS 01/07/M C 10/28/% 09/19/%
2230 96 014 TITLE:
FAILURE TO PERFORM AN ADEQUATE PRE-TURMOVER BOARD WALKDOWN.
PROC NUMBER: 71707 STL1 I M-014 02 URI MAINT 01/07/ M C 10/28/96 10/12/96 2230
% -015 TITLE:
" CONTROL OF M & TE" PROC NLMBER: 62703 STLi I % -014 03-URI PLTSUP 01/07/96 C 10/28/M 10/12/ %
2230
%-015 TITLE:
FAILURE TO PROFERLY ALIGN THE UNIT 1 CONTAINMENT RADIAil0N MONIT. PROC NUMBER: 71750 STL1 I % -015 01 NCY OPS 11/06/% C 11/12/96 10/12/96 2330
%-015 TITLE:
FAILURE TO IMPLEMENT TRAINING BULLETINS IN ACCORDANCE WITH PROC NUMBER: 71001 STL2 I W O15 01 NCV OPS 11/06/96 C 11/12/ % 10/12/96 2330
% 015 STL1 I W O15 02 NCV OPS 11/06/96 C 11/12/96 10/12/ %
2230
% -015 TITLE:
INADVENTENT BTPAS$1NG OF THE WRONG ESFAS SIGNAL PROC NUMBER: 71707
. STL1 I 96 015 03 NCV MAINT 11/06/96 C 11/12/96 10/12/96 2230 96-015 TITLE:
QUALITY CONTROL IDENTIFICATION OF M & TE ISSUES.
PROC NUMBER: 62703 STL2 I W O15 03 NCV MAINT 11/06/ % C 11/12/ % 10/12/96 2230 96-015 STL1 I W O15 04 VIO.
4/1 MAINT 11/06/96 0 11/12/ M 2230 TITLE:
FAILURE TO CONTROL M & TE.
PROC NUMBER: 62703 STL1 i W O15 05 URI E'NG 11/06/% 0 11/12/ %
2230 TITLE:
INADEQUATE DESIGN BASIS DOCUMENTATION PROC NUMBER: 37551 STL2 I % -015 05 URI ENG 11/06/96 0 11/12/96 2230 STL1 I % -015 06 VIO 4/1 PLTSUP 11/06/96 0 11/12/96 2230 TITLE:
FAILURE OF HP TO HAVE PROCEDURE IN MAND DURING REALIGNMENT OF PROC NUMBER: 71750 STL1 I 96-015 07 URI PLTSUP 11/06/% 0 11/12/ %
2340
~ TITLE:
CONTAMINATED 55 GALLON DRUMS INPROPERLY REMOVED FROM RCA PROC NUMBER: 71707
- STL2 I W O15 07 URI PLTSUP 11/06/% 0 11/12/%
2340 INFORMATION ON THIS PAGE IS FOR 0 F F _I C I A L USE ONLY.
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-DATE: 01/09/97.-
' STL
- f/1/93 - 11/22/96 (BY SONINN)
REPORT ST SITE
' TIM: 14:33:33 PAGE:
17 -
SITE: STL ST LUCIE UNITT RPT/ IFS / SEO-MO ITEM REF NOR / SEVERITY SALP REPORT / STS CREATE CLOSEOUTCLSOUT CLSGif LPDATING ASSR
~EA/ NOR NOV-ID TYPE EA-NER
' SUPLMNT AREA EVENT DT DATE
.PRJ/ACT*
ORG NO EMP ' INSPECTION. REPORTS-STL1
'I 96-015 06 NCV -
PLTSUP 11/06/96
'C 11/12/96 10/12/96 2230 96 015
-.T I TLE :
FAILORE TO FOLLOW PROCEDURE DURING PASS OPERATl0N PROC NLMBER: 92901-STL1 I W 0t6 01 VIO 4/3 PLTSUP 09/16/% 0 10/10/96 2340
' TITLE:
FAILURE TO REPORT EVENT TO NRC PROC NUMBER:
STL2 I W C16 01 VIO 4/3 PLTSUP 09/16/96 0 10/10/96 2340 STL1
-!96-016 02 VIO 4/1 OPS 09/16/96 0 11/20/%
2340 TITLE:
FAILURE TO CONTROL OPERATIONS KETS
. PROC NUMBER:
STL2 I E 016 02 VIO 4/1
, OPS 09/16/96 0 11/20/M 2340 STL1 I E 016 03 IFI OPS. 09/16/96 0 10/10/96 -
2340 0
TITLE:
IMPLEMENTATION OF INTERIM PLANT ACTIONS TO DETECT TAMPERING PROC NUM8ER:
STL2 I 96-016 03 IFI OPS 09/16/% 0 10/10/96 2340
- STL1 I W O16 04 URI OPS 09/16/96 0 10/10/96 2340-TITLE:
FSA DESCRIPTION OF INSTALLED INSTRUMENTATION ON UNIT 1 MOT PROC NUMBER:
STL1 1 96 019 01 eel W 458
/1-PLTSUP 11/15/96 0 11/20/96 2350 TITLE:
FAILURE TO PREVENT UNAUTHORIZED UNESCORTED ACCESS TO PROTECTED PROC NUMBER: 81700 STL2 1 % -019 01 EEI 96-458
/1 PLTSUP 11/15/M o 11/20/%
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PROC NUMBER: 81038 STL2 I W O19 02 EEI ' %-458
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MANUAL REACTOR TRIP DUE 10 HIGH MAIN GENERATOR COLD PROC NUMBER:
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CONTAINMENT PARTICULATE AND GASEG.fS MONITOR DUT OF PROC NUMBER:
STL1 N %-089 LER 96 004-00 02/27/96
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2230 TITLE:
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OPERATION PROHIBITED BY TECHNICAL SPECIFICAfl04 DUE TO MISSED PROC NUMBER:
INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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M TRIX REPORTS.
M STER INSPECTION PLANNING SYSTEM.
.DATE: 01/09/97.
' STL (1/1/93 - 11/22/96) (SONINN)
~
' TIME: 14:44:44 PAGE:
- 8
' REGION NO.: 2
~
- F M-SUMERY<
REPORT FROM DATE: 01/01/1993
'TO DATE: 11/22/1996 CRG CODE:
PLANNED AREA 0F CORE EMPMASIS DISCRETIONARY FACILITY CO -.
GT St RI RR RT NT OA OR AF REG NON-REG-
- TOTAL, A80R MGJRS - ' MOURS-HOURS HOURS MOURS MOURS MOURS HOURS NmJRS NOURS MOURS NOURS HOURS
= = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = =
- STL1 3,707.0 0.0 326.0 848.0 0.0 0.0 0.0 40.0 0.0 0.0 - 4,921.0 0.0 4,921.0
- STL2 3,245.7.
0.0 261.0 332.5 0.0 0.0 0.0 0.0 0.0 0.0 ' 3,839.2
. 0.0 3,839.2
.======================================mmmm=============================mm================m.m=
REGULAR 6,952.7..
0.0 587.0 1,180.5 -
0.0 0.0
.0.0 40.0 0.0' O.0 8,760.2 NON-REG 0.9 0.0 0.0 -
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0
==========================================mm==================mmm=========mm================
TOTALS - 6,952.7.
'O.0 587.0 1,180.5 0.0 0.0 0.0 40.0-0.0 0.0 8,760.2-0.0 8,760.2 SECTION h,9hhh hhh.h 1,hhhh INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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MATRIK REPORTS
- MASTER INSPECTION PLANNING SYSTEM
.DATE: 01/09/97 sTL (1/1/93 - 11/27/96) (s0NINN) 87 sALP T3 IPE MATRIK-TIME: 14.44:44-
-.4 PAEE:
9
~~
- NEGION MO.: 2 FAC-
SUMMARY
. REPORT FROM DATE: 01/01/1993 TO DATE: 11/22/1996 ' ORG CODE:,
b ACTUAL.
AREA OF
~
CORE-
-EMPMAsis DISCRETIONARY FACILITY-CO GT sl RI RR RT.
' TOTAL '.
Aoet nouts nouns nouRs nouRs mouns nouRs nouRs nouRs nouRs nouts nouns mouts ~
nouts mm=========== mmmmmmomm==mm.mm===mmum====-=====m-mm=mmm==.
sTL1 4,711.2
' O.0 239.5 1,807.7 426.5 120.0 8.0 '
5.0 2.0 558.5 6,929.5 948.9 7,878.4' sTL2
- 4,327.5 0.0
'250.5 1.392.2 358.0 120.0 8.0 10.0 8.0.
424.5 6,146.0 752.7 6,898.7
= = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = - = = = = = = = =
JREGuLAR
.8,178.0 0.0 448.5 2,765.5 557.0-234.0-16.0 14,0 10.0
-852.5 _13,075.5 :
NON-REG.
860.7 0.0 41.5
-434.4 227.5 6.0 0.0 1.0 0.0 130.5 1,701.6
.======================mm============================================================================
9,038.7 0.0 490.0 3,199.9 784.5 240.0
-16.0 15.0 -
.10.0 983.0 '13,075.5'.1,701.6 14,777.1.
TOTALS,..................................'.......................,..............................
sECTIoM 9,038.7 490.0 5,248.4-INFORMATION ON THIs PAGE Is FOR 0FFICIAL UsE ONLY.
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- o ITEM DETAIL REPORTS IFS - INSPECTION FOLLOW-UP SYSTEM DATE: 01/09/97 STL - 1/1/93 - 11/22/% (8Y SON!NN)
REPORT BY SITE TIME: 10:33:33 PAGE:
19 SITE: STL ST LUCIE UNIT RPT/ IFS / SEO-NO ITEM REF NOR / SEVERITY SALP REPORT / STS CREATE CLOSEOUT CLSOUT-CLSOUT LPDATING ABOR -
EA/ NOR NOV-ID TYPE F4-N8R SUPLMNT AREA EVENT DT DATE PRJ/ACT* ORG NO EMP INSPECTION REPORTS STL1 N W 329 LER W O14-00 10/27/96 0 12/04/96 2230 TITLE:
INVALID ENGINEERED SAFETY FEATURES ACTUATION OF CONTAINMENT PROC NUNBER:
STL1 N W 348 LER 96-011-0*
08/17/96 0 12/04/96 2230 TITLE:
OPERATION PRONI81TED BY TECMICAL SPECIFICATIONS DUE TO PROC NUMBER:
STL1
,N W 356 LER
%-015-00 10/29/96 0 12/05/96 2230 TITLE:
OPERATION PRON!81TED BY TECNNICAL SPECIFICATIONS DUE TG LOSS PROC NUpWEK:
STL1 N 97-009 LER W O16-00 11/22/% - 0 01/02/97
,2230 TITLE:
INSUFFICIENT TESTING AND MAINTENANCE ON 125 VDC BUS CROSS-TIE PROC NUMBER:
NOTE: DEFINITION FOR CNARACTER PRECEEDING REPORT NO: I = INSPECTION REPORT NUMBER, E = EA NUMBER (ENFORCEMENT / NOV ITEM)
N = IFS NUMBER, IRm8ER USED TO IDENTIFY NON-INSPECTION ITETIS TUTAL OPEN ITEMS
==============n 103
- IF ITEM IS OPEN, PROJECTED CLOSE0UT DATE IS REPORTED TOTAL OPEN REPORT SEQUENCES====n 79 IF ITEM IS CLOSED, ACTUAL CLOSE0UT DATE IS REPORTED INFORMATION ON THIS PAGE IS FOR 0FFICIAL USE ONLY.
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PLANT ISSUES MATRIX BY DATE St. Lucie l
SFA DATE TYPE
! SOURCE jID PRIM SEC ITEM APPARENT CAUSEi COMMENTS 11/23/96 POS IR 96-17 N
O 4 dearances audited. Only 1 minor deficiency noted.
340 11/23/96 POS IR 96-17 N
O M
Walkdowns of both uniti AFW and H2 monitoring No deficiencies noted.
339 systems satisfactory.
11/23/93 NEG IR 96-17 N
O Isolated weaknesses observed in dearance process.
Operators not aware of their 338 responsibilities for updating dearance index at times when work control center not manned. Also, one case of failing to transpose initials from a working copy of a dearance to the record copy of the dearance.
11/23/96 VIO iR 96 N E
Review of Total Equipment Database (a design Persorme! errors in picking up the need 348 document) updates for modifications executed during to update.
the last Unit 1 outage revealed that 2 failures to update the database had occurred.
11/18/96 POS IR 96-17 N
M On-hne maintenance of Unit 2 CCW (mid-cyde heat 347 exchanger cleaning) planned and exe'cuted well.
I 11/18/96 NEG 1R 96-17 N
O E
Operators failed to understand that safety-related Engineering had provided operators 346 components served by CCW were inoperable while with evaluations stating that adequate CCW was out of service for maintenance.
cooling was available from a cross connection to the operable CCW train; however, the cross connect would have isolated on a SIAS, FROM: 1/1/93 TO: 11/30/96 Page 1 of 33 08-Jan-97
o O
l SFA DATE TYPE l SOURCE l ID PRIM SEc ITEM APPARENT CAUSEICOMMENTS 11/1/96 POS IR 96-17 N
M On-line maintenance of Unit 1 AFW pump planned 345 and conducted well.
11/1/96 NCV IR 96-17 L
E O
Error found in procedure for shutdown margin Technical error in afgbraic sign 350 calculations, resulting in wrong sign attnbuted to asenbed to reactivity defect when reactivity defect.
transposing it from one worksheet to another.
11/1/96
<D IR 96-17 N
E O
Plant physics curve book found out of date. Reactivity Personnel error in failing to update
~
349 deviation had not been updated per procedura!
curve book.
requirements. Resulted in shutdown margin
, calculationalerrors.
11/1/96 NEG IR 96-17 N
O M
Errors discovered in shutdown margin calculations Weakness in procedural detail 343 due to operator error.
regarding how to account for stuck rod reactivity lead to a miscalculation (conservative).
10/31/96 POS IR 96-17 N
O M
Fulllength control element assembly survei!!ance While performed well, two procedural 342 testing (freedom of movement test) conducted weaknesses were identified by satisfactorify.
licensee. Electncal component failures Itampered testing on two rods, but 1&C support to effort was good in resolving issues.
10/30/96 POS IR 96-17 N
O MSIV Part-stroke surveillance testing.
Breifing and pre-test walkthrough good, 341 performance sat.
10/23/96 NCV IR 96-17 N
M E
Procedural inadequacy / personnel error identified in Procedure failed to contain firm 344 executing thrust bearing gap measurements.
acceptance criterlat or allowable thrust f
bearing gap. A recommended" range was included, the as-left condition was outside of this range, and no documented resolution of the nonconformance was pursued.
FROM.1/1/93 TO: 11/30196 Page 2 of 33 08-Jan-97
SFA DATE TYPE
. SOURCE ID PRIM SEC ITEM APPARENT CAUSEI COMMENTS 10/18/96 VIO IR 96-17 L
E Failure to satisfy QA plan requirements in the Failure to perform independent 324 development of design modifications to the Unit 1 verifications of design outputs Nuclear instrumentation system.
(drawmgs). Multiple examples. Also, failure to perform adequate validation and verification of software for incore monitoring.
10/18/96 VIO IR 96-18 N
PS Failure to implement training program for EP as Filures to provide training for multiple 321 speofied in E Plan.
positions for 3 years, failure to provide initial and requal training to multiple personnel, and other examples.
10/18/96 VIO IR 96-18 N
PS Failure to provide adequate EPIP for transferring OSC EPIP provided no more detail than plan, 322 functions to an attemate location in event an which said that EC would determine if evacuation of the OSC is required.
relocation was required. No speofics on possible attematives.
10/18/96 ViO IR 96-18 N
PS Failure to take corrective actions for critique items Corrective actions were still in dratft
~323 identified after Hurricane Erin in August,1995.
format and had not been acted uport 10/18I96 WEAK IR 96-18 N
PS Unreliable ability to notify state within 15 minutes of a Too many colateral duties assigned to 326 declared emergency.
Emergency Coordinator.
10/18/96 VEAK IR 96-18 N
PS Inadequate program of drills to ensure availability of No drills conducted since graded 327 sufficient personnel and timliness of ERF staffing.
exercise in February and no programmatic regt#ement to perform drills.
10/18/96 VIO IR 96-17 N
M Failure to initiate a condition report for a deficiency Resulted in miswiring the detector.
325 when cable labeling for Unit 18 channel Ni detector did not agree with drawing.
FROM: 1/1/93 TO: 11/30/96.
Page 3 of 33 08-Jan-97
SFA DATE TYPE
' ; SOURCE lID PRIM SEC ITEM APPARENT CAUSEICOMMENTS 10/18/96 VIO
^
IR 96-18 N
PS Failure to implement requirements of E Plan with Autodialer was inoperable and backup 320 respect to arrangements to staff and activate (manual) callout capability hindered by emergency response facilities from 7/22 to 10/3.
lack of distnbution of controlled and current phone number lists.
10/16/96 POS IR 96-13 N
E M.
Plans for performing periodic evaluations under the 330 maintenance rule met code requirements. Quarterly reports for SSCs considered positive indication of implementation of assessment process at a frequency exceeding requirements.
10/16/96 NEG IR 96-13 N
E M
Most system engineers interviewed during Licensee *s recent assignment of 337 Maintenance Rule inspection lacked some system system engineers (increased from 6 to knowledge and historical information on their 20 recent!y) seen as a major contributor systems. While they understood the rule, they didn1 to deficiencies noted in the team always understand how it applied to their systems.
inspection (System Engineers assigned too late in development of the program).
10/16/96 OTHER 1R 96-13 N
O M
Opereators were generally knowledgable on their 328 duties and responsibilities for implementing maintenance rule.
3 16/96 STREN IR 96-13 N
E M
Licensee's approach to development of a pre-336 evaluated maintenance risk assessment matrix (used for planning on-line maintenance) was considered a strength.
10/16/96 WEAK IR'96-13 N
E M
Engineering weaknesses noted in Maintenance Rule 335 inspection included ranking of initiating events and recovery actions not performed in quantitatis e manrier, re-ranking following sensitivity study not performed, expert panel guidence on shutdown risk weak.
10/16/96 POS IR 96-13 N
M Plant housekeeping and material condition 334 considered good. Preservation through painting was considered very good.
FROM.1/1/93 TO: 11/30/96 Page 4 of 33 08-Jan-97
l' SFA I ID PRIM SEC ITEM APPARENT CAUSEICOMMENTS DATE TYPE SOURCE 10/16/96 VIO IR 96-13 N
E M
Required SSCs were included within scope of 329 maintenance rule with the exception of PASS, site communications, Unit 1 Service Air and MSL rad monitors. Victation cited for failure to incorporate those systems.
10/16/96 VIO IR 96-13 N
E M
Licensee failed to establish appropriate performance Reliability goal of less than or equal to 333 criteria under maintenance rule) which were 2 MPFFs established across the board, commensurate with safety.
with no cvidence that individual SSC safety significance was factored in.
10/16/96 OTHER 1R 96-13 N
E M
Licensee has considered safety in establishing goals 332 and monitoring for SSCs under the maintenance rule.
10/16/96 NEG IR 96-13 N
E M
Licensee's approach to balancing reliabihty and While approach was acceptab$.
331 unavailabihty under maintenance rule was implementation of the approach would reasonat9e; however, measure of reliability for risk not be achievable until acceptablo significant systems did not meet code requirements.
performance criteria for reliability was developed.
10/12/96 NCV IR 96-15 '
L M
QA identified 3 areas of noncompliance with M&TE M&TE storage area had been relegated 311 controls; one lack of a cat sticker, lack of segregation to a self-service facility, counter to OA of sat and unsat M&TE, lack of an individual plan requirements. Indications are that controlhng M&TE.
a lack of personnel contributed.
10/12/96 WEAK IR 96-15 N
E PS No evidence could be found that containment leakage Lack of design basis documentation.
313 detection systems satisfied leak-before-break assumptions for detectability or seismicity.
10/12/96 VIO IR 96-15 N
M M&TE used in testing control channel Ni during M&TE was borrowed from another job, 310 installation was not logged out against the work order in violation of procedural controls.
for the job. Tracabihty was thus lost.
FROM: 1/1/93 TO: 11/30/96 Page 5 of 33 08-Jan-97
SFA DATE TYPE SOURCE ID PRIM SEC ITEM APPARENT CAUSEICOIMIENTS 10/9/96 POS IR 96-15 N
O Surveillance testing of 2A EDG performed well. Good 316 use of Real Time Training Coordinators 10/1/96 NEG IR 96-15 N
O O
2B HPSI pump discharge pressure noted to be 880#.
Poor attention to detail.
317 Operators could not explair it, had not noticed it. Was due to a pump run a week before.
9/19!96 NEG IR 96-16 N
PS Licensee :esponse to identification of glue in padlocks Events believed to have occurred at 299 in J% not thorough, as glue was later found in key sarne time, and licensee's intitial audits lock switches.
included only padlocks, door locks and valve locks.
9/19/96 POS IR 96-16 N
PS Licensee response to August discovery of glued key 298 lock switches satisfactory.
9/18!96 NCV IR 96-15 L
O Licensee bypassed the wrong ESFAS steam Poor labeling of bypass key slots.
314 generator low level channel in response to channel inoperability. Resulted in a failure to satisfy TS action statement requirements.
9/14/96 VIO IR 96-15 L
PS O
Unit 1 containment radiation rnonitor rendered HP tech failed to employ a procedure 312 inoperable after obtaining grab sample due to for restoring the monitor to service.
mispositioned valve. Repeat of previous violation.
Independent verifications were not performed 9/9/96 OTHER IR 96-15 S
M Set screw / locknut in Trip Circuit Breaker 5 sheared off Root cause pending. Initialindications 315 during surveillance testing and was later found in were of apparent hydrogen breaker cubicle.
embrittlement.
FROM.1/1/93 TO.11/30/96.
Page 6 of 33 08-Jan-97
l SFA DATE TYPE
- SOURCE
! ID PRIM SEc ITEM APPARENT CAUSEI COMMENTS 9/9/96 NCV IR 96-15 L
'O PS Licensee had not complied with requwements for Failure to fonow procedures.
308 -
ensuring that operators read training bunetins required to maintain requalification current. Licensee identified issue, with independent NRC findings.
9/9/96 POS 1R 96-15 N
O PS Control room watchstandtng practices satisfactory.
307 Watchstanders maintained a professional environment and were attentive to plant paramenters.
9/7/96 OTHER 1R 96-14 N
M Apparent improper use of M&TE for meggering N1 Failure to fo!!ow procedure.
302 cabling identified. Lack of tracability from M&TE to -
work order due to borrowing the equipment from one job for use on another job. URL 9/7/96 POS IR 96-14 N
M Review of 20 work orders indicated appropriate 30'3 control of work scope.
9/7/96 POS _
IR 96-14 N
M ESF response time testing procedure identified as 304 weak in detail. CR resolution to change procedure appropriate. Review oflast 4 performances of procedure for each unit indicated that TS satisfied for completion of all channels.
9/2/96 POS IR 96-14 N
O Unit 1 startup conducted well. Operator action to 301 terminated first approach to cnticality when Xe decay drove estimated critical conditions near anowed band limits was appropriate.
8/31/96 POS IR 96-14 L
O M
Operators manually tripped Unit 1 due to indications Operators acted quickly, 300 of gas accumulating in the 18 transformer. Operating conservatively, and in accordance with crew self-assessment fonowing event viewed as plant procedures.
excellent.
FROM: 1/1/93 TO: 11/30/96 Page 7 of 33 08-Jan-97
k i
SFA DATE TYPE iSOURCE
.ID PRitt SEc ITEM APPARENT CAUSE f COMMENTS 8/26/96 POS IR 96-14 N
E Engineering activities associated with leak in class 3 305 line to containment fan cooler in accordance with GL 91-18 and GL 90-05 for non-code repair.
8/23/96 NEG IR 96-16 N
PS Licensee extended control room access to a large 292 number of personnel, potentially in excess of those needing access.
8/23/96 VIO IR 96-16 N
PS Failure to report tampenng which occurred in July to Licensee made decision at the time that 291 NRC in accordance with 10 CFR 73 requirements.
tampering did not affect operation of the unit.
8/19/96 VIO IR 96-16 N
O Operations key controls found inadequate for keys Keys found uncontrolled at' 290 associated with control room evacuation / remote normal / isolate switch boxes forunit 2 shutdown PORVs.
8/16/96 WEAK IR 96-16 N
PS Interviews with maintenance personnel assigned to ineffective communication of 293 observe access to critical areas of the plant as a expectations during rapid development result of tampering event revealed that they had not of an augmented security posture.
been told what to look for, how to react, who to contact in the event of a problem, etc.
8/14/96 EMERG IR 96-16 L
PS O
NOUE declared due to security alert resulting from Event was similar to discoveries made 289 discovery of tampering. A glue-like substance had I.i July of a glue-like substance in been injected into Unit 1 and 2 hot shutdown panel padlocks.
key lock switches.
8/12/96 NCV IR 96-15 L
PS O
Failure to follow procedure resulted in the inoperability Poorly written procedure, compounded 309 of the Unit 1 containment radiation monitor following by weak execution by chemistry PASS panel operability check.
personnel. Good atter tion to cetail be NLO in identifying condition.
FROM: 1/1/93 TO: 11/30/96 Page 8 of 33 08-Jan-97
r SFA DATE TYPE iSOURCE llD PRIM SEc ITEM APPARENT CAUSEICOMANENTS 8/12/96 NCV IR 96-14 L
PS O
Operator identified low flow in Unit 1 containment air Failure to fonow procedure.
306 monitor. Condition the result of Chemistry personnel failing to property secure from a PASS system survei!!ance.
8/9/96 NEG IR 96-14 N
PS Examples of poor radiotaogical housekeeping 296 observed. Barrels for anti-C collection located outside of contaminated areas, use of multiple, undefined, stepoff pads, contaminated trash overflowing contaminated area boundaries.
8/9/96 EMERG IR 96-14 L
O M
NOUE declared due to RCS leakage in excess of 1 Charging pump packing leakage 288 gpm unidentified.
identified as source of leak. Operators correctly applied EAL.
8/6/96 NCV IR 96-14 N
O Operator observed not walking down control boards 394 prior to assuming shift, as required by procedure.
Operator terminated.
8/6/96 WEAK 1R 96-14 N
O Operator aids found in various areas of the plant Type of aids identified did not meet 295 which were not in agreement with system operating cnteria for inclusion in operator aid procedures, program and were not controlled.
8/3/96 OTHER IR 96-11 N
M E
Licensee's activities regarding maintenance of rod 281 control system were adequate.
8/3/96 VIO IR 96-11 N
E M
Prelubrication of valves prior to surveillance testing in Procedure wh>ch required prelube had 285 1995 resolved as being a violation of 10CFR50 not been considered for potential Appendix B cnterion XI.
effects on stroke time.
FROM: 1/1/93 TO: 11/30/96 Page 9 of 33 08-Jan-97
l SFA i
PRIM SEC ITEM APPARENT CAUSEICOMMENTS DATE TYPE
! SOURCE j ID 8/3/96 NCV IR 96-11' N
~ M Review of outage freeze seals indicated that one Stop work order by management for 284 freeze seal had been left unattended for deanup of the Unit 1 pipe tunnel approximately one hour.
resulted in dwecting freeze seal watd) to another area to make room for trash being hauled out of area.
8/3/96 NCV IR 96-11 L
O OA audit discovered that corrective action documents Rush to close out STARS (old 280 had been closed without being forwarded to originator corrective achon document) when CRs for approval (as required by procedure). NRC (new corrective action document) were identified that personnel without signature authonty instituted.
were closing documents.
7/30/96 OTHER 1R 96-11 L
E O
3 of 4 Unit 1 linear Ni channels found miswired, with Drawing errors - discrepancy between '
287 the detectors
- upper chambers feeding the lower NI vendor technical manuals and control drawer inputs and vice-versa. Result was 3 channels wiring diagrams generated for the for which axial shape index was in error.
insta!!ation of the new Unit 1 Ni drawers.
7/26/96 NEG IR 96-10 t
PS QA audit of Fitness for Duty program identified Failure to follow procedures and lack of 297 problems including personnel with negative tests both attention to detail and self-being recorded as positive (and vice versa) and checking cited as root causes.
personnel randomly selected for testing not being tested (even though they were available).
7/20/96 POS IR 96-11 N
M O
Post-outage walkdown of Unit 1 containment 283 indicated excellent cleanliness.
7/20/96 NEG IR 96-11 L
O M
2 operating charging pumps tripped when l&C failed to recognize that reactor 279 mainteriance induced an erroneous level signal into regulating system would be affected by reactor regulating system. Letdown isolated by their activities. Operators had charging operators. Upon reinitiating letdown, minor pump backup switch in wrong position, waterhammer event occurred.
leading to cessation of charging flow.
7/18/96 OTHER 1R 96-11 L
E M
Unit 1 AFAS setpoints found nonconservative during Failure to empicy as-built elevations of 286 review of recalibration activities.
condensate pots in the development of calibration criteria.
FROM: 1/1/93 TO: 11/30/96 Page 10 of 33 08-Jan-97
^
SFA DATE TYPE SOURCE ID PRIM SEc ITEM APPARENT CAUSEICOMMENTS 7/16/96 NEG' IR 96-11 L
O 2C auxilliary feedwater pump tripped on overspeed Operator error in not property 278 during post-maintenance testing.
implementing cautions in a procedure.
7/13/96 EMERG IR 96-11 L
O M
NOUE declared when 2C charging pump check valve Check valve stuck open due to possibly 282 stuck open, creating bypass flowpath from charging generic effects of pulsating low flow in a pumps to VCT. Operators timely in declaring event.
continuous service valve.
7/12/96 WEAK IR 96-12 L
E Licensee ventcat slice inspection of EDG, HPSI, and lack of proper configuration control 271 CCW systems revealed numerous deficiencies in over time.
procedure, design document and FSAR accuracy.
E Two SL IV violations cited for configuration Lack of appropriate pre and post-270 96-236 management control problems involving inaccuracies installation review.
in procedures and drawings due to design changes.
7/9/96 STREN IR 96-11 N
O Two entries into reduced inventory made during 276 inspection period. Strong management involvement in scheduling around Hurricane Bertha. Reduced inventory operations contrnues to be a strength.
7/8/96 POS IR 96-11 N
O M
Licensee preparations for Hurricane Bertha proactive Hurricane forcasts showed storm 277 and responsible.
missing area, but licensee prepared as though it would change course.
7/6/96 VIO IR 96-09 N
M E
Review of testing activities for continment b!ast Failure to property implement App. B 267 dampers indicated that violations of 10 CFR 50 App.
and QA plan as they related to B and site procedures existed. Two violations cited.
documenting as-found and as-left data.
7/6/96 POS IR 96-09 N
PS Review of RCP oil collection system.
System met description in FSAR and 269 vras in accordance with App R, except as allowed by approved exemption.
. FROM: 1/1/93 TO: 11/30/96 Page 11 of 33 08-Jan-97
~
SFA DATE '
TYPE SOURCE ID PRIM SEc ITEM APPARENT CAUSE ICOIMIENTS 7/5/96 POS IR 96-09 N
O Unit 1 reduced inventory preparations and execubon.
Mid-Loop controls effective. Licensee 264 attention and management oversight excellent.
6/27/96 OTHER IR 96-09 L
O E
Site reorganization announced which wouic place 265 almost all engineering functions (system engineenng, STAS, test engineers) under Engir eering Also.
Outage Management folded into a global work planning group under the Plant General Manager.
6/20/96 POS IR 96-09 L
M O
Loss of 3 Wide Range Nuclear Instrument Channels Operators prompt and accurate in 263 on Unit 1 resulted in entesing TS AS for Nts.
verifying shutdown margin requirements.
6/19/96 POS IR 96-09 N
O Unit 1 reduced inventory preparations and execution.
Controis were appropriate.
262 6/13/96 POS IR 96-09 N
M Maintenance activities associated with Unit 1 reactor Work conducted satisfactont r.
268 head lift and Unit 2 feed reg valve work.
6/13/96 VIO IR 96-09 N
M A review of overtime for a one month period indicated Failure of management to track the use 266 that overtime guide 8'nes were routinely exceeded of overtime as specified in site without prior (or subsequent) approval. 56 examples,
procedure. Procedure poorly defined cited for 5 individuals.
requirements.
6/8/96 POS IR 96-08 N
E M
Unit 1 RWT liner inspection.
Licensee satisfied committments to 253 inspect fibergfass liner in RWT.
Results sat.
FROM: 1/1/93 TO: 11/30/96 Page 12 of 33 08-Jan-97
SFA DATE TYPE
.SO.URCE ID PR!M SEC ITEM APPARENT CAUSEICOMMENTS 6/8/96 OTHER 1R 9648 N
M Review of maintenance backlog indicated that 251 licensee had a plan for backlog reduction in place but has yet to meet goals.
6/8/96 NEG IR 96-08 N
M Application of ladder and scaffolding programs 252 appears to be minimally compliant with licensee's self-imposed requirements. Many scaffolds and tadders required caution tags or had not been removed promptly after use.
6/8/96 POS IR 96-08 N
PS Fire barrier inspections performed by the licensee 259 were found to employ conservative criteria and be
. detailed.
6/8/96 OTHER 1R 96-08 L
E Ongoing review by licensee of UFSAR accuracy Failure to update FSAR over time and 260 identified approximate!y 150 items, ranging from failure to review FSAR property when typographical errors to more substhntive issues.
preparing procedures.
6/8/96 POS IR 96-08 N
O 3 QA audits reviewed Broad in scope, appropriately focused, 261 indicated an aggressive application of quality standards.
6/8/96 POS IR 96-08 N
O 3 QA Audits reviewed Broad in scope, focused on weak 247 areas. Agressive application of standards evident in the number of findings cited.
6/8/96
.STREN IR 96-08 N
E M
IS! activities for SG and reactor vessel eddy current Examinations weII-planned, performed 248 examinations reviewed.
and managed by very talented cad knowledgable personnel.
FROM.1/1/93 TO: 11/30/96 Page 13 of 33 08-Jan-97
SFA DATE TYPE SOURCE ID PRIM SEC ITEM APPARENT CAUSEi COMMENTS 6/8/96 POS IR 96-08 N
M Repair work for Unit 1 fuel transfer tube isolation valve. Conducted satisfactorily 249 6/6/96 POS IR 96-08 S
O Unit 2 manually tripped due to high main generator Operators acted promptly and correctly 246 gas temperature due to failed temperature control in tripping the unit. Post trip response vahre.
of both plant and operators was good.
6/6/96 VIO IR 96-12. EA-N E
USQ, involving taking a normally open EDG fuel oil Licensee determined that small 256 96-249 line isolation valve to the closed position and the use increase in the probability of failure of operator action to open the valve on EDG start, could be overcome by admin processes.
cited at SL 111.
6/3/96 OTHER 1R 96-08 N
M EDG reliability calculations indicate that EDG 243 reliabi!ity is in keeping with SBO assumptions 6/3/96 NEG IR 96-08 N
O.
Poor practice observed in spent fuel pool operations.
On deck" status was an effort to 245 Fuel assemblies were left hanging in an "on deck" expedite reload. Operatorleaving status while awaiting upender availability. Also, machine was due to inadequate operator left machine unattended with fuel hanging at manpower - operator had to operate least once per movement.
upender controls, which were mounted on watt.
6/3/96 WEAK IR 96-12, EA S
E M
High temperature condition in Unit 2 rod control Failure of an air conditioner. Further 241 96-236 cabinet room due to failure of an air conditioner led to review by licensee /NRC showed air indications of rod control problems. Indications later conditioner was temporary equipment shown to be false. Also, high temp condition led to installed without design controls during failure of a diverse turbine trip relay.
pre-op test phase.
6/3/96 OTHER IR 96-08 L
E O
Unit 1 outage extended due to. expansion of SG New plugging criteria resutting from 242 MRPC tube inspections. Tube plugging approached discussions with NRR on defect 25% limit. PLAs submitted to NRR to attow plugging characterization methodologies.
up to 30%.
- FROM.1/1/93 TO: 11/30/96 Page 14 of 33 08-Jan-97
\\
SFA DATE TYPE SOURCE ID PRIM SEC ITEM APPARENT CAUSEICOMMENTS 6/219 6 LER '
L O
M Non-safety related breaker alignments to support Unit Operators not aware that containment 240 1 outage resulted in loss of audible count rate
, amphfier was going to be affected by amplifier for containment. Audible counts lost in lineup. Control room amplifier not containment for approximately 5 minutes during fuel affected.
movements.
C/1/96 POS IR 96-08 N
E CNRB activities surrour Jing PLA reviews in support 257 of SG tube plugging issues were probing and competent.
5/31/96 OTHER 1R 96-08 s
O M
Blown fuse resulted in closure of all Unit 2 MSR Moisture found in a junction box 236 temperature control valves, resulting in a 5% load following heavy rain.
rejection.
5/29/96 LER L
O M
Suspected loss of approximately 1200 condenser 238 tube cleaning balls reported to state /NRC. Batis were found unaccounted for during an inventory balance.
Suspected that balls were released to Atlantic Ocean.
5/24/96 POS IR 96-08 S
O M
Rod control system failure resulted in inability to move Operators conservative in interpreting _
234 (electrically) 4 CEAs. Operators conservatively TS, plant organizations provided timely interpreted TS to require shutdown in this instance.
support with lists of equipment which Situation complicated by an out of service Startup would be inoperable when the main Transformer.
generator was tripped.
5/22/96 OTHER L
M V 3483 (SDC Suction Relief) setpoint found out-of-Root cause not established. Either 235 spec high, rendering valve incapable of performing its tampering or poor maintenance intended function.
practices (most likety).
5/17/96 NCV
- IR 96-08 N
M Failure to venfy the currency of procedure in use at Cognitive personnel error 254 jobsite FROM.1/1/93 TO: 11/30/96 Page 15 of 33 08-Jan-97
l l
SFA DATE TYPE SOURCE ID PRtM SEC ITEM APPARENT CAUSEI COMMENTS 5/17/96 ~
NCV IR 96-08 n
M Failure to satisfy requirements for " independence" on Cognitive error.
255 the part ofindependent verifier.
5/15/96 NEG IR 96-08 N
PS Observations of radiation worker practices revea!ed 258 inconsistencies in the application of site practices (e g. wearing of dosimetry, donning! doffing PCs).
5/14/96 POS 1R 96-08 N
O Fuel movements during Unit 1 core chm and reload 244 performed weII.
5/14/96 NCV IR 96-08 L
O Fuel movement begun with only one of two required Poor communication between control 237 wide range Ni channels operable. Condition identified room operators performing surveillance and fuel movement secured after a,pproximately 1 ft of testing (which inop'd NI) on the subject travel.
channel and the refueling center.
E O
initial temperature (and other) conditions specified in Programmatic weakness in Plant 239 96-236 Unit 1 spent fuel pool heat load calculation (to support Change / Modification process.
total core offload) was not factored into procedures, 5/11/96 POS IR 96-06 N
M E
Polar crane load rating calc and Unit 1 head lift.
No deficiencies identified.
224 5/11/96 POS IR 96-06 N
O 2 clearances audited, both correct.
222 5/11/96 POS IR 96-06 N
M Observations of Pressurizer Code Safety Valve No deficiencies noted 229 testing and repair i
FROM: 1/1/93 TO: 11/30/96 Page 16 of 33 08-Jan-97
SFA DATE TYPE
- SOURCE ID PRtM SEc ITEM APPARENT CAUSE1 COMMENTS 5/11/96 POS 1R 96-06 N
M MSSV testing - Unit 1 Outage Review of test data and methodology 225 sat.
5/11/96 POS IR 96-06 N
M Preparations for Unit 1 reactor vessel ISt.
In accordance with requirements and 232 showed good outage planning.
5/11/96 POS IR 96-06 N
M Observations of maintenance activities in containment No deficencies noted.
226 (Unit 1 outage) involving valve packing replacement and modification.
5/8/96 NCV 1R 96-06 N
M Lack of verified (controlled) copy of procedure Failure of Maintenance workers to 230 identified at CCW heat exchanger jobsite.
properly verify procedures prior to beginning work.
5/7/96 VIO IR 96-06 N
PS Programmatic weaknesses identified in Fire 11/62 members had expired medicals.
223 Protection Program br medical qualification of fire 9/65 with expired medicals worked 60 brigade members.
shifts in April. 2 Fire Team leaders not listed on roster worked 31 shifts in April.1 Fire Team member with expired medical and not on roster worked 1 sh;ft.
5/5/96 POS IR 96-06 N
O Reduced inventory operations conducted well by 227 perators.
5/3/96 POS IR 96-05 N
PS Inspection of FPL Speakout program.
Program effective in handling and 272 resolving employee safety concems.
FROM: 1/1/93 TO: 11/30/96 Page 17 of 33 08-Jan-97 s
SFA DATE TYPE SOURCE ID PRIM SEc ITEM APPARENT CAUSEI COMMENTS 5/3/96 WEAK ~
IR 96-05 N
PS Investigative techniques of Speakout program have No requirement to develop plans to 273 the potential to reveal, inadverteritty, of concemed
, ensure identity is protected, employees.
5/3/96 VEAK IR 96-05 N
PS Response letters prepared by Speakout to concemed 274 employees did not contain adequate feedback to concemed employees.
5/3/96 WEAK IR 96-05 N
PS Speakout program corrective actions were not tracked Lack of procedural specificity.
275 through implementation as required.
5/2/96 POS IR 96-06 N
O Good performance by operators and test personnel 231 during integrated safeguards testing on Unit 1. 18 EDG output breaker failed to close during first test.
Operators handled situation well.
4/29/96 NCV IR 96-06 N
E Failure to promptly document a nonconformance.
Engineering failed to initiate CR upon 217 discovery that approx. 35 S-R instruments on each unit might have been calibrated at temperatures lower than those assumed in setpoint ca!cs.
4/28/96 POS IR 96-06 N
O Operators performed well during Unit 1 RFO Communications formal, excellent use 215 shutdown.
of annunciator response procedure.
Performance of rod drop time testing a noteworthy initiative.
4/22/96 NCV IR 96-06 L
O E
Unauthorized breech in RAB fire barrier during Operators showed good attention to 219 installation of CCW piping modification.
detail in identifying two holes bored in wall. Engineering failed to account for the effects of modification installation in fire rated assembly, as required by procedure for engineering packages.
FROM.1/1/93 TO: 11/30/96 Page 18 of 33 08-Jan-97
SFA DATE TYPE SOURCE i, ID PRIM SEc ITEM APPARENT CAUSE1 COMMENTS -
4/20/96 OTHER IR 96-06 S
O Unit 2 downpowered and taken off-line due to lovv Blockage in auto-stop oil line orifice 208 pressure condition in auto-stop oil. Operators which prevented buildup of auto-stop oR observed to control evolution well.
pressure. Only negative aspect was crowding of control panels by control room SROs during portions of evolution.
4/18/96 NCV 1R 96-06 L
E M
Missing onfice plate identified in Unit 1 ICW system Either failure to install onfr.e during 233 during licensee field walkdowns.
plant modification, or failure to reinstall orifice following maintenance.
4/14/96 YEAK IR 96-06 N
O E
Configuration Controlissues resulted from ESF Walksdowns of both units' CS, ICW and 220 system walkdowns.
IA systems indicate programmatic failures in incorporating design changes into drawings, the FSAR and operating procedures. Unresolved item tracking expansion of inspection scope to include instrumentation setpoin'ts.
4/14/96 WEAK IR 96-06 N
O E
ICW system walkdown.
Results indicate weaknesses in 221 procedure-to-procedure agreement, labeling, and surveillance requirements, in addition to configuration control issues disussed separately.
- 4/13/96 POS IR 96-06 N
E Engineering response to failure of HVS4A motor Procurement engineering effective in 214 considered good.
locating and dedicating replacement motor and in identifying and resolving incorrect bearing rating calc for new motor. Minor problem existed in that new starting current profile was not adequately treated.
4/10/96 POS IR 96-300 N
O Simulator performed well throughout SRO 213 qualification testing.
FROM: 1/1/93 TO: 11/30/96 Page 19 of 33 08-Jan-97 l
SFA DATE TYPE SOURCE ID PRIM SEC ITEM APPARENT CAUSE i COIM4ENTS 4/10/96 OTHER IR 96-300 N
O 4 of 4 SRO candidates passed SRO examination. In 212 3 of the cases, performance was marginany satisfactory. No generic candidate weaknesses identified.
4/9/96 NEG S
E CIRC water piping through-wall leaks observed in two Galvanic corrosion due to inadequate 210 water boxes' outlets.
cathodic protection following installation of stainless steel Tapparogge components.
4!4/96 OTHER 1R 96-06 L
O Interim Operations Manager (H. Johnson) named.
228 3/31/96 EMERG 1R 96-06 N
O PS Operator response to RCS leakage through CVCS Operators effective at 216 system.
identifyinghsclating leak; however, Unus% Event call was non-conservative in that the call was delayed to allow a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> RCS inventory balance to be calc'd when other information indicated that excessive leakage existed.
~
3/30/96 POS 1R 96-04 N
O Review of 5 clearances indicates better attention to 194 detail than had been observed in past.
3/30/96 NEG IR 96-04 N
M Control of maintenance procedures was such that an Programmatic vunerability.
200 outdated procedures could, programmatically, wind up iri the field due to their inclusion in previously prepared packages. Licensee corrective action adequate.
3/30/96 OTHER 1R 96-04 S
M Maintenance underwent major departmental 201 reorganization. Selected supervisors
- qualit: cations found satisfactory per TS requirements.
FROM: 1/1/93 TO: 11/30/96-Page 20 of 33 08-Jan-97
SFA DATE TYPE SOURCE ID PRIM SEc ITEM APPARENT CAUSE E COMMENTS '
3/30/96 POS IR 96-04 N
M 10 maintenance activities observed during inspection 199 period. No significant deficiencies noted.
3/29/96 POS IR 96-04 N
O Operator requalification program found to be 198 supporting management expectations for operations and covering timely and important topics.
3/27/96 VIO IR 96-04 N
O Operators failed to properly log boron dilution Management direction to operators 190 evolutions. Global log entry was made at the a!!owing global log entries for reactivity beginning of the shift stating dilutions would be made; manipulations during transient however, procedure required each dilution to be conditions (e.g. uppower) which was logged.
not in accordance with Conduct of Operations procedure.
3/14/96 OTHER t
ps Management change. A. Desoiza (human resources 181 manager) replaced by Lynn Morgan (from TP) 3/12/96 POS ~
IR 96 04 3
o Licensee disposition for deficiency noted in 1 boroflex 202 panel (top 15' missing) found satisfactory. FRG treatment of issue found appropriate.
3/10/96 OTHER 1R 96-04 L
O Unit 1 downpowered to 97.5% due to hot leg Hot leg stratification.
182 stratification and flow swirl which resulted in higher than actual indicated reactor power.
3/7/96 NEG IR 96-04 N
O During MTC testing, inspector noted that boron Poor attention to detail.
196 concentration had been verified at 30 minute intervals, vice 15 minute intervals as called for in procedure.
l FROM: 1/1/93 TO: 11/30/96 Page 21 of 33 08-Jan-97
SFA DATE TYPE
. SOURCE
'.ID PRIM SEc ITEM APPARENT CAUSEICOMMENTS 3/7/96 NEG IR 96-04 N
O Licensee failed to place a CEA which had been.
Operator oversight.
195 declared administratively inoperable in the equipment out-of-sennce log. CEA was operable per TS.
3/1/96 OTHER IR 96-04 N
PS Housekeeping in RABs generally good; however.
205 equipment storage areas found cluttered and untidy.
3/1/96 OTHER t
O Management Changes - T. Plunkett succeeds G.
174 Go:dberg. C. Wood replaces L Rogers as manager of SCE, C. Marple replaces C. Wood as Ops Supervisor.
3/1/96 POS IR 96-04 N
PS Ongoing HP efforts to obtain accreditation of FPL 207 electronic dosimetry program identified as a good example of department's technical capabilities.
3/1/96 OTHER 1R 96-04 N
PS Licensee found to be utilizing ALARA techniques and 206 making progress at reducing collective doses for staff.
3/1/96 NCV IR 96-04 N
PS Inspection of Hot Tool Room identified several tools Attention to detail in tool storage and 204 which were either not painted purple (as required) or surveying.
which slightly exceeded limits for contamination.
3/1/96 OTHER IR 96-04 N
PS Licensee found to be implementing adequate RP 203 controls and monitoring individual exposures per code requirements.
l l
FROM.1/1/93 TO.11/30/96 Page 22 of 33 08-Jan-97
SFA 3
DATE TYPE SOURCE ID PRIM SEC ITEM APPARENT CAUSE ICOMMENTS 2/24/96 VIO IR 96-04 N
M Acceptance criteria specified for CEDM coit Failure ofI&C System Supervisor to 189 resistances in PC/M package found varied and adhere to test criteria compcunded by undear. Criteria were not property applied and values failure of l&C management to identify outside of speafications were not documented and obvious errors during post-work review.
resolved.
2/24/96 VIO IR 96-04 L
PS O
Unit 1 containment radiation monitor found out-of-Failure to follow procedure on the part 175 service due to isolation valve which was closed to of HP personnel, compounded by support a grab sample prior to a containment entry failure to identify condition by operators and not retumed to the open position. Condition during rounds.
existed for 2 days, unknown to licensee.
2/24/96 WEAK IR 96-04 N
M Maintenance practices for Steam Bypacs and Control Poor preventive maintenance on SCBC 177 System and Feedwater Regulating valves found weak valve air lines and FRVs.
in inspection following 2/22/96 Unit 1 trip.
2/24/96 WEAK IR 96-04 S
O Procedural weakness results in attempting to Procedure review weakness -lack of 193 synchronize main generator with grid with generator verification that disconnect links were
~
disconnect links open.
closed.
2/22/96 LER LER 335/96-S O
M Dropped CEA led to declaration of NOUE and plant 318 002 shutdown. During shutdown, failure of air line to a FRV led to manual trip.
2/22/96 VIO IR 96-04 N
O O
Operators found adding boric acid to VCT without Procedures were put away to tidy up 197 procedure in hand, as required by conduct of control room prior to NRC senict operations procedure. Additional example of EEA 96-managers' tour prior to SALP meeting.
040.
2/17/96 NEG IR 96-01 L
M Weakness identified in 1&C calibration procedure -
Proceduralinadequacy 112 lack of detail provided for safety related calibrations.
FROM: 1/1/93 TO: 11/30/96 Page 23 of 33 08-Jan-97
=
SFA DATE~
TYPE SOURCE ID PRIM SEc ITEM APPARENT CAUSEICOMMENTS 2/17196 NCV IR 96-01, IR N
'M
,P S' Work on 1 A ECCS suction header through-wall leak Personnelwork pracbces (workers 108 96-04 revealed strong FME, but poor HP work practices ignored RWP requirements)
- observed regarding contamination control resulted in NCV.
2/17/96 POS IR 96-01 N
M Noted improvements in housekeeping and matenal 110 conditions.
2/17/96 NEG IR96-01 N
M Freeze seal procedure lacked objective enteria Procedural Weakness 109 defining when a freeze seal existed.
2117/96 VEAK IR 96-01 N
O Numerous deficiencies identified in instrument air ProceduralInadequacy 111 system walkdowns, including drawings accuracy, ONOP adequacy, and annunciator response procedure accuracy.
2/15/96 NEG 1R 96-01 N
O M
Tours of ECCS rooms revealed several active leaks.
Material Condition 113 Licensee could not explain how (if) FSAR assumptions on ECCS leakage were satisfied. Later review of FSAR indicated leakage vnthin assumptions.
2/F/96 POS IR 96-02 N
PS Licensee's onsite emergency organization was found 186 to be well-defined and generally effective at dealing with simulated emergency during graded exercise.
2/7/96 POS IR 96-02 N
PS Communication among the licensee's emergency 187 response facilities and emergency organization and emergency response organization and offsite authorities were good during graded exercise.
1 i
l l
I FROM: 1/1/93 TO: 11/30/96 Page 24 of 33 08-Jan-97 l
I
^
O e
l SFA DATE TYPE iSOURCE ID PRIM SEc ITEM APPARENT CAUSEI COMMENTS 2/7/96 POS IR 96-02 N
PS Observations of licensee perforrance in CR, TSC, OSC, and EOF indicated good command and control, 188 staff utilization and staff demeanor during graded exercise.
2/7/96 OTHER 1R 96-02 N
PS EP exercise demonstrated that onsite emergency plans were adequate and that licensee was capable 183 ofimplementing them.
2/7/96 NEG IR 96 02 N
PS Two areas for improvement identified in graded EP inconsistencies in the use of Florida exercise - Need for management to become more Notification Message Form. Confusion 185 involved in assuring correctness of info being existed between NLOs dispatched from provided in offsite notification forms and need to refine OSC and Control room for similar repair C&C for damage control teams.
missions.
2/F/96-POS IR 96-02 N
PS Licensee made significant observation of E-Plan Licensee objectrvely questioning overall execution - 2 practice drills were required prior to state of readiness.
184 graded exercise for management to be satisfied with performance. Management dotermined that more frequent drills were required to ensure readiness.
1/26/96 OTHER 1R 96-01 N
O Inspection of corrective acton program revealed Corrective Actions timely action on the part of management, but 114 weaknesses in plans for tracking progress on personnel performance and procedure quality improvement.
O Violation identified regarding temporary changes to Procedure Control 115 96-01-01 procedure which changed intent and which were approved for use without prior FRG review, 1/22/96 VIO IR 96 EA
-L O
E Boron dilution event due to operator leaving control Operator error, poor short term 117 96-040 panel while dilution was in progress. Weak command tumover, poor command and control and control, procedural adherence, and short-term tumover. Additionally. OP for boration/ dilution not consistent with FSAR and no 50.59 performed.
~ FROM: 1/1/93 TO: 11/30/96 Page 25 of 33 08-Jan-97
a
?
SFA DATE TYPE
'SOUPCE ID PRIM SEc ITEM APPARENT CAUSEI COMMENTS 1/7/96 N
O SALP CYCLE 12 BEGINS 118 1/5/96 WEAK IR 95-22 L
o M
U2 manual RX trip on high generator H2 tamp due to Temp Contml Va!ve Failure.
119 failure of temp control valve. Operator awareness of Additiona'ly, failure to identify RPS status post-trip poor, inspection of post-trip unexpected reactor trip signals which review (for current trip as well as past trips} indicated came in during trip.
weaknesses in the rigor of post-trip reviews 1/5/96 VIO IR 96-04 L
O NLO failed to employ procedure when placing EDG Failure to use procedure, failure to 191 fuel oil tank on recirculation for chemistry. As a result.
notify control room of evolution.
he improperty performed the evolution by isolating the discharge of the EDGFO transfer pump, which resulted in an inoperable EDG.
1/5/96 NCV IR 95 N O
PS Severai deficiencies in prodecure change process Failure to Property implement 121 NCV 95-22-01 imolementation identified. Expired or cancelled TCs Procedures found in control rooms and hot shutdown panel.
1/5/96 NEG IR 95-22 N
O Several procedural deficiencies and calculational inadequate Procedure Review and 120 errors identified in reload physics test procedure.
Execution 12/27/95 NEG IR 95-22 S
O E
FRG meeting suffered / items deferred due to lack of Lack of Attendance at FRG 122 OPS /Eng'g attendance at meeting. Major issues at meeting affected OPS /Eng'g.
12/20/95 OTHER IR 95-22 S
M RX vessel flange inner O-ring groove pitting resulted Pitting - Localized Corrosion 123 in cooldown and head removal for repair.
FROM.1/1/93 TO: 11/30/96 Page 26 of 33 08-Jan-97
~
m i
SFA DATE TYPE
. SOURCE ID PRIM SEc ITEM APPARENT CAUSEI COMMENTS 12/9/95 OTHER 1R 95-22 L
M 2A2 RCP seal pkg lower seal destaged due to reverse Fining RCS Before Coupling RCP 124 pressure across seal.
- 12/5/95 VEAK 1R 95-22 N
O M
ESFAS cabinet doors found unlocked following Poor Logkeeping/ Attn to Detail 125 maintenance work - I&C error. Log entries associated with work were not complete.
12/4/95 NEG IR 95-21 N
O Operators unable to effectively obtain I&C setpoints inadequate Operator Training 132 from computer after hard copies were removed from control room.
12/1/95 WEAK IR 95-21 N
O SDC procedure contained conflicting values for RX Procedural Weakness!!nadequate 133 cavity level requirements. Procedu:a had been Review approved since emphasis on accuracy stressed.
12/1/95 WEAK IR 95-21 N
O CCW sample valve showed dualindication without FTF Procedure 131 corrective action documentation initiated.
12/1/95 WEAK IR 95-21 N
O Clearance in place to isolate N2 from CST to facilitate Poor Corrective Actions 130 pressure switch replacement for nine days without work order being written.
12/1/95 NEG IR 95-21 N
O-Recurrent non-valid alarms when starting fire pumps FTF Procedure 129 were not documented as operator workarounds.
Voltage dips associated with such starts were contributors to a trip previously.
12/1/95 NEG IR 95-21 N
O SDC Procedure required natural cire-related Proceduralinadequacy 128 surveitlance prior to establishing RCS pressure boundary. Natural cire not possible without pressurization.
FROM: 1/1/93 TO: 11/30/96 Page 27 of 33 08-Jan-97
-1
^
SFA APPARENT CAUSEICOMMENTS DATE TYPE
- SOURCE ID PRIM SEc ITEM,
12/1/95 WEAK IR 95-21 N
O Followup to previous inspection findings indicated a Corrective Achons 127 weakness in followthrough in addressing deficiencies.
12/1/95 NEG IR 95-21 N
PS Rad survey results unavailable for B hot leg work Failure to Document RAD Survey 126 Surveys performed but not documented.
~
12/1/95 NEG 1R 95-21 N
O Unit 2 procedures and valve deviation log used to Valve Position Administrative Controls 134 cycle Unit 1 cross connect valves.
O Messed RCS Boron sample surveillance - Repeat from Personnel Error 135 95-21-03 IR 95-18.
11/21/95 NCV IR 95 L O.
Failure to maintain Penetration Log FTF Procedure 136 NCV 95-21-04 11/21/95
~OTHER 1R 95-21 S
O Light socket failure during lamp replacement results in Equipment Failure 137 loss cooling to 1 A Main Transformer. Unit downpower to -60%.
O Valve discovered Closed vice Locked Closed as FTF Procedure 138 95-21-01 specified on Equipment Clearance Order.
11/16/95 OTHER IR 95-21 s
O M
Unit 1 manually tripped when 1B MFRV locked in 50%
Long-Standing Equipment Problem 139 position. Root cause - degraded power suppfy, compounded by voltage dip on starting both station fire pumps.
~ FROM: 1/1/93 TO: 11/30/96 Page 28 of 33 08-Jan-97
- l
+
I SFA DATE TYPE
O Tectt Spec. equipment not specified for IV on FTF Procedure 140 95-21-02 Equipment Clearance Order.
11/6/95 OTHER 1R 95-21 S
M Failure of EDG 2A relay sockets. Potential common Equipment Failure 142 mode failure.
11/1/95 NCV IR 95 S M
ICI wiring error during RX head insta!!ation last RFO.
Personnel Error -
143 NCV 95-18-05 10/19'/95 NCV IR 95 S O
Missed shift CEA position indication surveit ance.
Personnel Error 144 NCV 95-18-06 10/18!95 NCV IR 95 L O
Missed RCS Boron sample surveillance.
Personnel Error 145 NCV 95-18-07 10/17/95 VEAK IR 95-18 S
O Lack of attention to task resulted in overfilling RCB '
Personnel Error 146 lower cavity during flood up.
E Inserting CIAS signal during safeguards test shifted Design Error 147 95-18-04 EDG 2A to isochronous mode while EDG paralleled with offsite power.
10/9/95 LER LER 95-S'02 L
PS Potential route for unauthorized access to protected Personnel Error 143 area, CW water piping.
FROM: 1/1/93 TO: 11/30/96 Page 29 of 33 08-Jan-97
7
~
SFA DATE TYPE
O Did not enter bypass key position in deviation log.
Failure to Follow Procedures 149 95-18-01 10/5/95 OTHER IR 95-18 s
M DG 1B developed FO leak at threaded connection Equipment Failure 150 during survetilance run.
O Did not enter bypass key position in deviation log.
Failure to Follow Procedures 151 95-18-02 9/28/95 OTHER 1R 95-18 S
E Leaking PZR SVs extended forced outage - problems Equipment Failure 152 with tailpipe alignment.
9/20/95 OTHER 1R 95-18 s
M EDG 1 A/18 govemor control problems resulted in Equipment Failure 153 load oscillations.
O M
Main / Ops did not provide clearance for work on Failure to Follow Procedures-154 95-18-03 condenser waterbox cover When cover pu!!ed closed, severed worker's finger.
9/14/95 WEAK LER U1/U2 L
ps Security failed to take correct compensatory action on Failure to Follow Procedure 155 95-S01 computer failure.
9/10/95 WEAK IR 95-18 s
o SG blowdown sent to incorrect system on RAB roof.
Failure to Use Correct Procedrue 156 Operator used wrong procedure. When identified did not back out of procedure correctly.
FROM 1/1/93 TO: 11/30/96 Page 30 of 33 08-Jan-97
k a.
SFA DATE TYPE SOURCE ID PRIM SEC ITEM APPARENT CAUSEICOMMENTS 9/9/95 WEAK IR 95-15 3
M Leak on SV 1201 flange extended outage, identified Weakness in Work Screening and 157 one month earlier but not worked.
Planning 9/7/95 WEAK IR 95-15 L
O Unit 2 Main Generator overpressurized while filiing Personnel Error / Inoperable 158 W'th H2. Inattention by operators.
Equipment /OWA 9/2/95 VIO IR 95 VIO N
O Weaknesses identified in logs relatmg to abnormal Personnel Error 159 95-15-03 equipment conditions and out of service equipment not logged (mulitple examples).
8/31/95 OTHER 1R 95-15 3
M Damaged cylinder and head on 18 EDG due to loose Personnel Error 160 lash adjustment.
8/30/95 WEAK IR 95-15 N
PS Containment closure walkdowns by management Management and OC Weaknesses 161 were inadequate and depended heavily on DC involvement to identify deficiencies.
8/30/95 WEAK 1R 95-15 N
M Maintenance personnel not using procedures for work Supervisory Oversight and Worker 162 in progress.
Attitude 8/29/95 VIO 1R 95 VIO N
M Maintenance joumeyman not signing off procedure Procedure Use 164 95-15-06 steps as work completed (previously identified as a weakness in May 1995).
O Started 1B LPSI pump with suction valve closed (No Personnel Error 163 95-15-04 damage to pump)
FROM.1/1/93 TO: 11/30/96-Page 31 of 33 08-Jan-97
a.
I SFA DATE TYPE
' i SOURCE
, ID PRIM SEc ITEM APPARENT CAUSEICOMMENTS
~
8/23/95 WEAK IR 95-15 S
M 2A HDP inp due to relay failure. Eight HDP trips in Equipment Failure / Inadequate 165 past year. Engineering solution available but not Correctrve Acton implemented.
8/22/95 VIO IR 95-15 N
PS QA failed to document a deficiency on containment Personne! Error 166 spray valve surveillance identified in an audit.
1 B/19/95 WEAK IR 95-15 S
O Overfill of PWT. Spilled approx.10K gallons on Operator Error / Operator Workaround 167 ground inside RCA. Operator work around on level control system and inattention to filling process by operator caused error.
8/18/95 WEAK IR 95-15 N
M Procedural weakness involving supervisory oversight Procedural Weakness 168 and joumeyman qualification.
8/17/95 VIO LER U195-S O
Spraydown of Unit 1 containment STAR process did Procedurat inadequacy and 169 007 - VIO 95-not assign accountability for corrective action. Valve Weakness / Operator-Work-Around 15 surveillanct prelube not documented on STAR.
8/9/95 VIO IR 95 LER L
M Inoperable Unit 1 PORVs due to maintenance Maintenance / Testing Errors 170 Ut 95-005 -
error / testing inadequacies. (Valves assembled EA 95-180 incorrectly) (Used acoustic data only) 8/6/95
- VIO LER U195-S E
Lifting of Unit 1 SDC thermal relief due to procedural Corrective Action /ProceduralWeakness 171 006 - VIO 95-revision from previous corrective action. Inoperable 20-01 equipment not logged.
FROM: 1/1/93 TO.11/30/96 Page 32 of 33 08-Jan-97 i
l SFA DATE TYPE
- SOURCE
} ID PRIM SEC ITEM APPARENT CAUSE1 COMMENTS.
~
8/2/95 VIO LER U195-L O
1 A2 RCP seal failure due to "restagog" at high _
Procedural Weakness / Failure to Follow 172 004 - VIO 95-temperature.
Procedures 15-02 8G/95 VIO LER U195-3 O
Operator failed to block MSIS actuation during Operator Error "173 04 - VIO 95 cooldown.
01 SALP Functional Areas:
ID Code:
E ENGINEERING
[ LICENSEE M
MAINTENANCE jN NRC
- O, OPERATIONS
'S
- SELF-REVEALED
.PS PLANT SUPPORT
.SA SAFETY ASSESSMENT & OV FROM: 1/1/93 TO: 11/30/96 Page 33 of 33 08-Jan-97
j, j'
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BIOGRAPHICAL DATA -
NRC RESIDENT STAFF '
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. MARK 8. MILLER UJ.NRC Senior Resident inspector 8t.Lucie Nuclear Plant Date Assigned:
Assigned as Residentinspector 9193 i
Assumed SRIPosition Il96 l
Previese NRC Employmeet Reactor Systems Engineer,NRRIDSSA 1993 Headquarters Operetions Officer, AE00 1991 1993 Resident inspector, Yankee Rows 1991 Reactor Engineer, Region i 1990 1991 Previese Employment Musissoni8 tete University Gradusta ResearchlTeaching Assistant 1988 1990 Teses Utilities Electric Comanche Peak Steam Electnc Station System Engineer / Regulatory Compliance Engineer 1987 1988 Plowoort News Shiobuddme and Dry Dock Co.
Shift Test Engineer (S8G) 1983 1987 Edesaties:
MusiamoniState University j
M.S. Nuclear Engineering,1990 MusissinniState Universty M.8. Nuclear Engineering,1983
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Biographical Information 6
5:PL J
C. Ashton Pell 1
Outage Manager, St. Lucie Plant Ash Pell is Outage Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. Pell reports to the Site Vice President. He is responsible for the planning and scheduling of St. Lucie Plant outages and for coordination of operations and maintenance activities on a daily basis.
Mr. Pell began working for FPL in 1975. He has held a variety of positions of increasing authority, including. Reactor Engineer, Reactor Supervisor, Technical Staff Supervisor, Assistant to Senior Vice President-Nuclear, Director Nuclear Administrative j
Services, Plant Services Manager and Outage Manager. Mr. Pell completed certification as a senior reactor operator for both the St. Lucie and Turkey Point nuclear units.
Mr. Poll is a graduate of the University of Central Florida and holds a. Bachelor of Science degree in Physics.
He is a member of the Southeast section of the American Nuclear Society (ANS).
4 9
1/96
Biographical Information O
I: P L Charles H. Wood System & Component Engineering Manager, St. Lucie Plant Chuck Wood is System & Component Engineering Manager of Florida Power and Light Company's St. Lucie Nuclear Power Plant. In this function Mr. Wood reports to the Plant
. General Manager. He is responsible for the direction and coordination of the technical support.
to Operations and Maintenance Departments and the coordination of issues, regulatory interaction and documents at the St. Lucie Plant located on Hutchinson Island.
Mr. Wood began working for FPL in 1979 as a helper at the Putnam Plant. He has held various positions of increasing responsibility in the St. Lucie operations department, including i
reactor control operator, senior reactor control operator, assistant nuclear plant supervisor, nuclear plant supervisor, assistant operations supervisor and opentions supervisor. Mr. Wood also worked in the outage management department. Mr. Wood has held a reactor operator license and holds an inactive senior reactor operator license for St. Lucie Units 1 and 2.
Mr. Wood previously worked for the Alachua County Regional Utility as an auxiliary operator, boiler operator and control center operator and attended Santa Fe Community College.
Effective 2/26/96 4
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t Biographical Information I: P L Christopher L. Burton Services Manager, St. Lucie Plant
'Chris Burton is Services Manager of Florida Power & Light Company's St Lucie Nuclear Power
- Plant. In this function, Mr. Burton reports to the Site Vice President. He is responsible for Plant Facilities, Budget, Fire Protection, Emergency Planning, Training, Land Utilization, Security, and Information Services at the St. Lucie site.
l Mr. Burton began working for FPL in 1975. He has held a variety of positions of incr. casing authority, including reactor operator, nuclear plant supervisor, assistant operations supervisor, reliability maintenance supervisor, operations supervisor, operations manager, and plant general manager. Mr.
Burton has held reactor operator and senior reactor operator licenses at St. Lucie.
Mr. Burton is a graduate of State University of New York and holds a Bachelor of Science degree in Electronics Technology. Mr. Burton also holds a Master of Business Administration degree from Florida Institute of Technology.
He is a member of the American Nuclear Society (ANS) and the Professional Reactor Operator Society.
D t
1/96
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Biographical information O
FPL Daniel J. Denver Site Engineering Manager, St. Lucie Plant Dan Denver is the Site Engineering Manager for Florida Power & Light Company's St.
Lucie Nuclear Power Plant. In this function, Mr. Denver. reports to the Vice President - Nuclear Engineering and Licensing and is responsible for engineering services including design packages, as-building, procurement engineering, fuel design, and outage NDE inspections for the two nuclear units at the St. Lucie site located on Hutchinson Island.
Dan joined Florida Power & Light Company in May,1993 as Director, Nuclear Technical Support in the Juno Beach offices. In this capacity, he was responsible for nuclear fuel supply, information services and the administrative staffs for Nuclear Engineering and Licensing. He has worked in the nuclear power industry since 1967 in various engineering and technology development areas. He worked for a number of electric utilities including Public Service Electric
& Gas, Yankee Atornic, and Houston Lighting and Power as well as Westinghouse Electric and a nuclear industry services company, EIInternational.
Dan graduated from the University of Notre Dame in 1966 with a Bachelor of Science degree in Mechanical Engineering and received a Master of Science in Nuclear Engineering from Massachusetts Institute of Technology in 1967.
In outside activities, Dan has served in local town government and on the boards of several amateur theater organizations and professional societies. He is a registered professional engineer in the Commonwealth of Virginia.
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BiographicalInformation O
I:PL Edward J. Weinkam 111 Licensing Manager, St. Lucie Plant Ed Weinkam is Ucensing Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. Weinkam reports to the Site Vice President and is responsible for cocrdination of the St. Lucie Plant regulatory interface among the NRC Resident inspectors, NRC Region il Staff, and NRC Headquarters staff.
J Mr. Weinkam began working for FPL in 1986. He has held a variety of positions of increasing authority, including NRR licensing engineer and corporate licensing supervisor for the St. Lucie Plant, licensing manager for the Turkey Point Plant. He has worked in the nuclear industry since 1979 in various engineering, educational, and regulatory areas. He was a U. S. Navy nuclear subrnarine officer, an engineering instructor at the University of Maryland, and USNRC, NRR project manager. Mr. Weinkam completed certification as a senior reactor operator at the Turkey Point nuclear units.
Mr. Weinkam is a graduate of the University of Notre Dame and holds a Bachelor of Science degree in Mechanical Engineering. He received a Master of Science in Mechanical Engineering from the University of Maryland in 1979.
l 1
l 1/96 6
0 1
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BiographicalInformation FPL John A. Stall Vice President, St. Lucie Plant Art Stellis Plant Vice President of Florida Power & Light Company's St. Lucie Nuclear Power Plant. He reports to the Nuclear Division President and oversees the operation of the two nuclear units at the St. Lucie site located on Hutchinson Island, approximately 50 miles north of West Palm Beach. Mr. Stall joined FPL in May 1996.
Mr. Stall previo'usly served as Station Manager for Virginia Power' Company at the North Anna nuclear plant. He joined Virginia Power in 1977 and held various positions of increasing responsibility, including superintendent of operations, assistant station manager for safety and licensing, and superintendent of technical services. A career nuclear professional, Mr. Stall brings his extensive experience to St. Lucie and will play an important role in the continued performance and efficiency improvements.
Mr. Stall earned his Bachelor of Science degree in nuclear engineering from the University of Florida in 1977, and achieved his Master of Business Administration from Virginia Commonwealth University in 1983. Mr. Stallis a registered professional engineer and held a senior reactor operator license while at Virginia Power Company.
1 4
i 6/96
4
)
l Biographical lnformation I
I: P L Joseph Marchese Jr.
Maintenance Manager, St. Lucie Plant Joe Marchese is Plant Maintenance Manager of Florida Power & Light Company's St. Lucie
' Nuclear Power Plant. In this function, Mr. Marchese reports to the Plant General Manager and is responsible for supervision and coordination of the maintenance activities including electrical, mechanical, instrumentation & control, records and planning at the St. Lucie Plant located on Hutchinson Island.
Mr. Marchese began working for FPL in 1984. He has held a variety of positions of increasing authority, including lead construction electrical supervisor -Turkey Point Plant, lead construction mechanical supervisor - Turkey Point Plant, site construction manager - Turkey Point Plant, and plant maintenance manager. Prior to his tenure at FPL, Mr. Marchese had 12 years nuclear experience in various positions of increasing authority with Bechtel Power Corporation, including Milestone, Davis Besse, and St. Lucie Nuclear Plants construction and startup testing. Mr. Marchese completed the senior reactor operator certification training program at Turkey Point.
l Mr. Marchese is a graduate of the University of Akron and holds a Bachelor of Science degree in Electrical Engineering. Mr. Marchese is a registered Professional Engineer in Florida and Virginia.
He is a member of the American Nuclear Society (ANS).
1/96 4
n MM 4
0 FPL 1
l Jame.s Scarola Plant General Manager, St. Lucie Plant Jim Scarola is Plant General Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function Mr. Scarola reports to the Site Vice President. He is responsible for Operations, Maintenance, and technical Support activities at the St. Lucie site located on Hutchinson Island.
Mr. Scarola began working for FPL in 1980. He has held a variety of positions of increasing authority, including l&C startup engineer, l&C maintenance engineer, assistant superintendent electrical maintenance, manager special projects, maintenance manager, manager equipment, support, and inspectior's, engineering project manager, and operations manager at St. Lucie.
i Mr. Scarola holds a Bachelor of Science degree in Electrical Engineering from the University of Notre Dame and a Master of Business Administration degree'from Florida Institute of Technology. Mr. Scarola has completed the senior reactor operator certification training program at St. Lucie.
4 1/96
)
l-Biographical information j
FPL L. Wesley Bladow Site Quality Manager, St. Lucie Plant Wes Bladow is the Site Quality Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. Bladow reports to the Vice President Nuclear Assurance and is responsible for independently assessing the Quality Control and Quality Assurance Program implementation by the St. Lucie Nuclear Plant.
Mr. Bladow began working for FPLin 1967 in the Distribution Engineering Department.
He has held a variety of positions of increasing authority, including quality assurance supervisor, quality assurance superintendent, and site quality manager at the Turkey Point Nuclear Plant and quality assurance manager of the St. Lucie Unit 1 steam generator replacemeret project, and manager of nuclear safety speak out.
Mr. Bladow is a graduate of Florida International University and holds a Bachelor of Science degree in Industrial Technology with a minor in industrial safety.
Mr. Bladow is a member of the American Nuclear Society.
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Biographical Information r
I: P L Robert E. Dawson Business Manager, St. Lucie Plant Bob Dawson is Business Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Bob Dawson repou, to the Site Vice President and is responsible for the strategic plan, the plant operating plan, 'h' corrective action program, and the in-house-event tracking and trend analysis programs at the St. Lucie Nuclear Plant.
Mr. Dawson began working for FPL in 1973. He has held a variety of positions of increasing authority, including reactor engineering department head at Turkey Point. Plant, staff reactor support, mechanical startup group supervisor for St. Lucie Unit 2, core barrel repair project, electrical maintenance department head, plant, maintenance manager, and plant licensing manager. Mr. Dawson has held an senior reactor operator license at St. Lucie.
Mr. Dawson is a graduate of the University of Virginia and holds a Bachelor of Science degree in Nuclear Engineering.
He is a member of the American Society of Mechanical Engineers (ASME) and the American Nuclear Society (ANS).
1/96
Biograrihical information I: P L Thomas F. Plunkett President, Nuclear Division j
i Tom Plunkett is President, Nuclear Division at Florida Power & Light Company. In this function, Mr. Plunkett oversees the operation of FPL's four nuclear units, two at Turkey Point in south Dade County and two at St. Lucie on Hutchinson Island in St. Lucie County as well i
as the technical support cetivities at corporate headquarters in Juno Beach.
Mr. Plunkett joined Florida Power and Light Company in 1990 as Vice President, Turkey Point Nuclear Plant. Prior to that he worked for Gulf States Utilities Company as General Manager of the River Bend Nuclear Plant and for Illinois Power Company as General Manager of the Clinton Nuclear Plant. Earlier he was Technical Manager at the D. C. Cook Nuclear Station for,the Indiana Michigan Power Company. Mr. Plunkett began his career with the Douglas Aircraft as a nuclear engineer.
Mr. Plunkett holds both a Bachelor of Science in Mechanical Engineering ind a Master of Science in Nuclear Engineering from the University of Wisconsin.
Effective 3/1/96
m,- u - u n w era w we si u.a sub,7i'Gi, su ^
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P St. Lucie Agenda Bimonthly. Meeting with Licensee (open to public) y 0630-0645 Arrive on site 0645-0800 Discussion of current events and media interest
[
0800-0930 Plant Tour 0930-1200 Public Meeting 1200-1300 Lunch in South Service Building 1300-1400 Meeting with A. Stall-1400 1430.
Meeting with J. Scarola i
-1500 Depart Note -
Media Interest is expected at public meeting. Items of recent press interest attached e
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- a we,eeeswem us, nee s au < avi noa e.ua Items of Recent Press interest 1.
Housekeeping During an interview with n local television station, the reporter produced copies of photographs taken in the plant. In general, they showed valves with packing leaks and boron /NaOll buildup, roped-off contaminated work areas and messy tool rooms.
SRI responded that regulations dictate maximum permissible levels of contamination and combustible loading and that is our prime area of emphasis. SRI stated that housekeeping offered insights into the culture of the site. See video.
2.
Backlogged Maintenance During and interview with a local television station, the reported produced copies of a list of purportedly backlogged maintenance items, with some dating back several years, and solicited comment. SRI responded that the list contained, largely, noun name references to the equipment in question (as opposed to the conditions requiring maintenance) and stated that the individual conditions, not the age necessarily, must be considered in the context of operability of safety-related components. See video.
3.
Layoffs /Prudency.
)
In the same interview, the SRI was asked to remove.hlmself from the NRC role to that
.of a consumer and comment on recent layoffs. The premise was that, if the site could i
be operated by the current level of staffing or less, the previous level constituted " fat,"
and indicated that the consumer had been bilked. The SRI refused to address the issue, i
4.-
The " Major Investigation" The SRI dealt with the list provided by the reported as an allegation and contacted the reporter the next day for information required by the ROI. The reporter asked how the NRC process worked in this regard, and the panel and inspection process was described.
The reporter then contacted the licensee for comment on the major investigation" the NRC was conducting.
5.
Unit 2 Trip The SRI was contacted by two newspapers regarding the Trip of Unit 2. The situation was described. Neutral articles appeared in the Palm Beach Post and Port St. Lucie Tribune. Quotes were (accurately) attributed to the SRI referring to the root cause (a failed temperature control valve) as an equipment reliability issue (the same valve led to a Unit 2 trip in January).
6.
Personnel Actions
va-me w ern w Luc i e re n.2,,,t
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-u, m m The print media asked about disciplinary actions taken against supervisors (days o for occurrences at the plant SRI responded that the licensee must be contacted for personnel-related information.
- During the outage period,6 maintenance supervisors have been disciplined (to include written reprimands and days of0 for errors related, mostly, to clearance program violations.
7.
Personnel Injuries T
The SRI was questioned regarding personnel injuries which have occurred on-site recently. The SRI responded that a number of injuries had occurred the number of which increasing with the number of personnel on-site through the outage, and that the injuries ranged from minor abrasions to a possible hernia.
8.
" Strong" Cover Letter The television story on St. Lucie reported a quote from the cover letter to inspection Report 96-04. The letter included the following:
"The violations are of concern because they indicate that personnel performance with respect to procedure coinpliance and usage and attention to detail persist even after corrective actions had been completed for previous, similar, violations.
Particularly illustrative of this point is a violation for failures associated with the Unit I containment particulate / iodine / gaseous radiation monitor. The event displayed particularly poor performance on the part of several individuals and included aspects of failing to access and follow a procedure, compounded by falling to capitalize on multiple opportunities to j
identify the inoperable component through logtaking. Logtaking weaknesses were further compounded by the fact that non licensed operators taking the logs were electronically prompted that a key parameter associated with the component's operability was unacceptably low. The failure.to pursue this condition, with at least six logtaking opportunities, indicates that a lack of a questioning attitude extends to multiple personnel. It is also noted that a failure to employ an approved procedure lead to a condition of Emergency Diesel Generator inoperability (the subject of another violation in the enclosed report)."
The issue is summarized in the Technical Issues portion of this document.
9.
Management Changes The television interview included a question regarding the new management of St.
Lucle.
SRI responded that performance would indicate the effectiveness of management.
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4 Technical issues 1.-
Unit 1 Steam Generators
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. At the Regulatory Information Conference. NRR stated that the NRC knew of no industry method for characterizing the size of steam generator' cracks. - FPL felt they had and went to White Flint shortly after the conference,1 wishing to explain their methodology prior. to the outage. NRR disagreed with FPL's assessment of their
~
capabilities and,in.a conference call. stated'that more restrictive tube plugging crkeria must be adopted by FPL and that NRR was prepared to go forward with a 50.54(f)-
letter or an Order if FPL did not.' FPL has acceded to all.of NRR's demands with the l
. exception of a commitment to a mid cycle outage for tube inspection.
3 The more conservative plugginB criteria is projected to drive Unit 1 plugging past the 25% limit contained in the' accident analysis. FPL has submitted an exigent license amendment allowing 30% plugging. The PLA.will not result in a derate until 7000 EFPH,but will require changes to reactor flow values, thermal margin limhs, low flow setpoints, and the volume of water in the RCS.
2.
Unit 1 PIG The Unit 1 containment particulate iodine gaseous monitor was found out-of service by the licensee. The component was isolated to obtain a grab sample of containment after the January' Unit 1 trip. It was isolated by an HP technician without the use of the
. appropriate procedure and was not properly returned to service. Two days went by.and non-licensed operators logged an unacceptably low flow value at the component (a total of six times) in computerized. data-loggers. The data loggers, when fed an out-of-specification value, prompt the operator to log the number again, thus " telling" them there's a problem.
We covered the issue and felt that the licensee had not done a comprehensive job of corrective actions and. included a request in the cover letter that they describe other m
corrective actions in addition to the ones they had listed. This issue will be a source of discussion during the meeting.
3.
Configuration Mana'gement
]
)
The NRC has identified a number of issues in configuration management in the last 2
)
months. These include:
i
]
Annunciator response summaries (off-normal procedures) which include erroneous information (due to plant changes which were not factored in) such as wrong setpoints, wrong drawing references, responses to compuents which no longer exist, and wrong referenced sens'ing elements.
Drawings _which fail to incorporate changes (valves'shown on drawings which o
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m.%
,.,y,
'l has previously been reviewed).
' Operating procedures which failed to incorporate changes The licensee has also identified these types of issues. Examples include:
A refueling procedure which - failed to include calculational assumptions (temperature to be established prior to core off-load, number of spent fuel pool cooling pumps)
A rod control cabinet alt conditioning system which doesn't appear'on drawings.
Enforcement is being prepared which cites a programmatic breakdown in Configuration Management.
11 J
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SITE INTEGRATIOlv MATRIX BY DATE St. Lucie SFA DATE TYPE SOURCE ID PRIM sEc ITEM APPARENT CAUSE / COMMENTS 6/3/96 WEAK IR 96-08 N
M EDG reliability calculations and action may not Informality in process.
(pending) have been perfonmed perlicensee's program.
6/3/96 OTHER IR 96-08 L
O E
Unit 1 outage extended to July 19 due to New plugging criteria resulting from (pending) expansion of SG MRPC tube inspections.10 discussions with NRR on defect free-span indications identified to date.
characterization methodologies.
Projected tube plugging will exceed 25% limit.
PLAs submitted to NRR to allow plugging up to 30%.
6/3/96 NEG IR 96-08 s
M E
High temperature condition in Unit 2 rod control Failure of an air conditioner.
(pending) cabinet room due to failure of an air conditioner Furtherieview by licensee /NRC led to indications of rod control problems.
~ howed airconditionerwas s
Indications later shown to be false. ilso, high temporary equipment installed temp condition led to failure of a dNerse turbine without design controls and room trip relay.
itself may have been constructed without seismic or appendix R reviews.
6/2/96 WEAK IR 96-08 L
O M
Non-safety related breaker alignments to Operators not aware that (pending) support Unit 1 outage resulted in loss of audible containment amplifier was going to count rate amplifier for containment. Audible be affected by lineup. Control counts lost in containment for approximately 5 room amplifier not affected.
minutes during fuel movements.
5/31/96 OTHER IR 96-08 s
O M
Blown fuse resulted in closure of all Unit 2 MSR Moisture found in a junction box (pending) temperature control valves, resulting in a 5%
following heavy rain.
Ioad rejection.
FROM: 1/1/90 TO: 6/6/rd Page 1 of 20 06-Jun-96
l
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SFA DATE TYPE SOURCE ID PRIM sEc ITEM APPARENT CAUSEICOMMENTS -
5/29/96 LER IR 96-08 L
O M
Suspected loss of approximately 1200 -
(pending) condenser tube cleaning ba!!s reported to state /NRC. Balls were found unaccounted for during an inventory balance. Suspected that balls were released to Atlantic Ocean.
5/24/96 POS IR 96-08 S
O M
Rod control system failure resulted in inability to Operators conservative in (pending) move (electrically) 4 CEAs. Operators interpreting TS, plant organizations conservatively interpreted TS to require provided timely support with lists of shutdown in this instance. Situation complicated equipment which would be by an out of service Startup Transformer.
Inoperable when the main generatorwas tripped.
5/22/96 OTHER IR 96-08 L
M V 2483 (SDC Suction Relief) setpoint found out-Root cause is yet to be established.
(pending) of-spec high, rendering valve incapable of performing its intended function.
5/14/96 NCV IR 96-08 L
O Fuel movement begun with only one of two Poor communication between (pending) required wide range NI channels operable.
control room operators performing Condition identified and fuel movement secured surveillance testing on the subject after approximately 1 ft of travel.
channel and the refueling center.
Compounded by operators not 5/12/96 WEAK IR 96-08 L
O E-Initial temperature conditions specified in. Unit 1 Programmatic weakness in Plant (pending) spent fuel pool heat load calculation (to support Change / Modification process.
total core offload) was not factored into procedures. Calc required less than or equal to, 106F pool temp, procedure allowed 140F.
5/11/96 POS IR 96-06 N
O 2 clearances audited, both correct.
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FROM: 1/1/90 TO: 6/6/96 Page 2 of 20 06-Jun-96
CFA DATE TYPE SOURCE ID PRIM SEC ITEM APPARENT CAUSE / COMMENTS 5/11/96 POS IR 96-06 N
M E
Polar crane load rating calc and Unit 1 head lift.
No deficiencies identified.
5/11/96 POS IR 96-06 N
M MSSV testing - Unit 1 Outage Review of test data and methodology sat.
5/ji/96
,POS IR 96-06 N
M Observations of maintenance activities in No deficencies noted.
containment (Unit 1 outage) involving valve packing replacement and modification.
5/11/96 POS IR 96-06 N
M Observations of Pressurizer Code Safety Valve No deficiencies noted testing and repair 5/11/96 POS IR 96-06 N
M Preparations for Unit i reactor vessel ISI.
In accordance with requirements and showed good outage planning.
5/8/96 NCV IR 96-06 N
M Lack of verified (controlled) copy of procedure Failure of Maintenance workers to identified at CCW heat exchangerjobsite.
property verify procedures prior to beginning work.
5/7/96 VIO IR 96-06 N
PS Programmatic weaknesses identified in Fire 11/62 members had expired Protection Program for medical qualification of medicals. 9!65 with expired fire brigade members.
medicals worked 60 shifts in April.
2 Fire Team leaders not listed on rosterworked 31 shifts in April.1 Fire Team me_mber with expired medical and not on roster worked 1 shift.
1 i
FROM: 1/1/90 TO: 6/6/96 Page 3 of 20 06-Jun-96 l
SFA DATE TYPE SOURCE ID PRIM SEc ITEM.
APPARENT CAUSEI COMMENTS 5/5/96 POS IR 96-06 N
O Reduced inventory operations conducted well by operators.
5/2/96 POS IR 96-06 N
O Good performance by operators arxi test personnel during integrated safeguards testing on Unit 1.1B EDG output breaker failed to close during first test. Operators handled situation well.
4/29/96 NCV IR 96-06 N
E Failure to promptly document a nonconformance. Engineering failed to initiate CR upon discovery that approx. 35 S-R instruments on each unit might have been calibrated at temperatures lower than those assumed in setpoint cales.
4/28/96 POS IR 96-06 N
O Operators performed well during Unit 1 RFO Communications formal, excellent shutdown.
use of annunciator response procedure. Performance of rod drop time testing a noteworthy initiative.
4/22/96
- NCV IR 96-06 L
O E
Unauthorized breech in RAB fire banier during Operators showed good attention to installation of CCW piping modification.
detail in identifying two holes bored in wall. Engineering failed to account for the effects of -
modification installation in fire rated assembly, as required by procedure for engineering packages.
- FROM: 1/1/90 TO: 6/6/96 Page 4 of 20 06-Jun-96
CFA DATE TYPE
^
SOURCE ID PRfM sEC ITEM APPARENT CAUSEICOMMENTS 4/20/96 OTH5R 1R 96-06 S
O Unit 2 downpowered and taken off-line due to Blockage ln auto-stop oil line orifice low pressure condition in auto-stop oil.
which prevented buildup of auto-Operators observed to control evolution well.
stop oil pressure. Only negative aspect was crowding of control panels by control room SRos during portions of evolution.
4/18/96 NCV IR 96-06 L
E M
Missing orifice plate identified in Unit 1 ICW Either failure to install orifice during system during licensee field walkdowns.
plant modification, er failure to reinstall orifice following maintenance.
4/14/96 WEAK IR 96-06 N
O E
ICW system walkdown.
Results indicate weaknesses in procedure-to-procedure agreement, labeling, and surveillance requirements,in addition to configuration controlissues disussed scparately.
4/14/96 WEAK IR 96-06 N
O E
Configuration Controlissues resulted from ESF Walksdowns of both units' CS, ICW system walkdowns'.
and IA systems indicate programmatic failures in incorporating design changes into drawings, the FSAR and operating procedures. Unresolved item tracking expansion ofinspection scope to include instrumentation
~
setpoints.
4/13/96 POS IR 96-06 N
E Engineering response to failure of HVS-4A Procurement engineering effective motor considered goost in locating and dedicating replacement motor and in
' dentifying and^ resolving incorrect i
l bearing rating calc for new motor.
Minor problem existed in that new starting current profile was not adequately treated.
FROM: 1/1/90 TO: 6/6/96 Page 5 of 20 06-Jun-96
l l
SFA
'DATE TYPE SOURCE ID PRIM sEc ITEM APPARENT CAUSE / COMMENTS 4/10/96 OTHER IR 96-300 '
N O
4 of 4 SRO candidates passed SRO examination. In 3 of the cases, performance was marginally satisfactory. No generic candidate weaknesses identified.
4/10/96 POS IR 96-300 N
O Simulator performed well throughout SRO qualification testing.
4/9/96 NEG S
E CIRC water piping through-wall leaks observed Galvanic corrosion due to in two water boxes' outlets.
Inadequate cathodic protection following installation of stainless steelTapparogge components.
4/4/96 OTHER 1R 96-06 L
O Interim Operations Manager (H. Johnson) named.
3/31/96 EMERG IR 96-06 N
O PS Operator response to RCS leakage through Operators effective at CVCS system.
identifying / isolating leak; however, Unusual Event call was non-conservative in that the call was delayed to allow a 1 hout RCS inventory balance to be calc'd when otherinformation indicated that excessive leakage existed.
3/30/96 POS IR 96-04 N
O Review of 5 clearances indicates better attention to detail than had been observed in past.
3/30/96 OTHER 1R 96-04 S
M Maintenance underwent major departmental reorganization. Selected supervisors
- qualifications found satisfactory per TS requirements.
FROM: 1/1/90 TO: 6/6/96 Page 6 of 20 06-Jun-96
-_y.
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i SFA DATE TYPE SOURCE ID PmM sEC ITEM APPARENT CAUSEICOMMENTS 3/30/96 NEG IR 96-04 N
M Control of maintenance procedures was such Programmatic vunerability.
l that an outdated procedures could, programmatically, wind up in the field due to i
their inclusion in previously prepared packages.
Ucensee corrective action adequate.
3/30/96 POS IR 96-04 N
M 10 maintenance activities observed during inspection period. No significant deficiencies noted.
3/29/96 POS IR 96-04 N
O Operator requalification program found to be supporting management expectations for operations and covering timely and important topics.
3/27/96 VIO IR 96-04 N
O Operators failed to properiy log boron dilution Management direction to operators evolutions. Global log entry was made at the allowing globallog entries for beginning of the shift stating dilutions would be reactivity manipulations during made; however, procedure required each transient conditions (e.g. uppower) dilution to be logged, which was not in accordance with Conduct of Operations procedure.
' 3/14/96 OTHER L
PS Management change. A. Desolza (human resources manager) replaced by Lynn Morgan (from TP) 3/12/96 POS IR 96 04 s
O Licensee disposition for deficiency noted in 1 boroflex panel (top 15" missing) found satisfactory. FRG treatment ofissue found appropriate.
3/10/96 OTHER 1R 96-04 L
O Unit 1 downpowered to 97.5% due to hot leg Hot leg stratification.
stratification and flow swirl which resulted in higher than actual Indicated reactor powbr.
FROM: 1/1/90 TO: 6/6/96 Page 7 of 20 06-Jun-96
~
CFA DATE TYPE SOURCE ID PsuM sEC ITEM c
APPARENT CAUSE1 COMMENTS 3/7/96 NEG~
IR 96-04 N
O During MTC testing, inspector noted that boron Poor attention to detail.
concentration had been verified at 30 minute intervals, vice 15 minute intervals as called for in procedure.
3/7/96 NEG 1R 96-04 N
O Licensee failed to place a CEA which had been Operator oversight.
declared administratively inoperable in the equipment out-of-service log. CEA was operable perTS.
3/1/96 OTHER L
O Management Changes - T. Plunkett succeeds G.
Goldberg, C. Wood replaces L Rogers as manager of SCE, C. Marple replaces C. Wood as Ops Supervisor.
3/1/96 OTHER IR 96-04 N
PS Licensee found to be implementing adequate RP controls and monitoring individual exposures per code requirements.
3/1/96 NCV IR 96-04 N
PS Inspection of Hot Tool Room identified several Attention to detail in tool storage tools which were either not painted purple (as and surveying.
required) or which slightly exceeded limits for contamination.
3/1/96 OTHER 1R 96-04 N
PS Housekeeping in RABs generally good; however, equipment storage areas found cluttered and untidy.
3/1/96
- OTHER IR 96-04 N
PS Licensee found to be utilizing Al. ARA techniques and making progress at reducing collective doses for staff.
~
FROM: 1/1/90 TO: 6/6/96 Page 8 of 20 06-Jun-96
SFA DATE TYPE SOURCE ID PMM SEc ITEM APPARENT CAUSE / COMMENTS 3/1/96 POS IR 96-04 N
PS Ongoing HP efforts to obtain secreditation of FPL electmnic dosimetry program identified as a good example of department's technical capabilities.
2/24/96 WEAK IR 96-04 N
M Maintenance practices for Steam Bypass and Poor preventive maintenance on Control System and Feedwater Regulating SCBC valve airlines and FRVs.
valves found weak in inspection fol lowing 2/22/96 Unit 1 trip.
2/24/96 VIO IR 96-04 N
M Acceptance criteria specified for CEDM coil Failure of l&C System Supervisor resistances in PC/M package found varied and to adhere to test criteria.
unclear. Criteria were not propedy applied and compounded by failure of I&C values outside of specifications were not management to identify obvious documented and resolved.
errors during post-work review.
2/24/96 WEAK IR 96-04 S
O Procedural weakness results in attempting to Procedure review weakness-lack synchronize main generator with grid with of verification that disconnect links generator disconnect links open.
were closed.
~
2/24/96 VIO IR 96-04 L
PS O
Unit 1 containment radiation monitor found out-Failure to fo!!ow procedure on the of-service due to isolation valve which was part of HP personnel, compounded closed to support a grab sample prior to a by failure to identify condition by containment entry and not retumed to the open operators during rounds.
position. Condition existed for 2 days, unknown to licensee.
2/22/96 EMERG IR 96-04 S
O Dropped CEA (due to SCR failure) leads to TS-Equipment Failure required shutdown and declaration of NOUE.
l Failure of air supply to FRV leads to operators tripping repctor from 26%. Good operator performance throughout.
I i
l l
FROM: 1/1/90 TO: 6/6/96 Page 9 of 20 06-Jun-96 l
CFA DATE TYPE SOURCE ID PRIM sEC ITEM APPARENT CAUSE1 COMMENTS 2/22/96 VIO IR 96-04 N
O O
Operators found adding boric acid to VCT Pmcedures were put away to tidy without procedure in hand, as required by up control mom priorto NRC senior conduct of operations procedure. Additional managers' tour priorto SALP example of EEA 96-040.-
meeting.
2/17/96 NCV IR 96-01, IR N
M PS Work on 1 A ECCS suction header through-wall Personnel work practices (workers -
96-04 leak revealed strong FME, but poor HP work ignored RWP requirements) practices observed regarding contamination control resulted in NCV.
2/17/96 NEG IR 96-01 L
M Weakness identified in I&C calibration Proceduralinadequacy procedure'-lack of detail pmvided for safety related calibrations.
2/17/96 WEAK IR 96-01 N
O E-Numemus deficiencies ider;tified in instrument ProceduralInadequacy air system walkdowns, including drawings accuracy, ONOP adequacy, and annunciator response procedure accuracy.
2/17/96 NEG IR96-01 N
M Freeze seal procedure lacked objective criteris Procedural Weakness defining when a freeze seal existed.
2/17/96 POS,
IR 96-01 N
M' Noted improvements in housekeeping and material conditions.
2/15/96 NEG IR 96-01 N
O M
Tours of ECCS rooms revested several active Material Condition leaks. Licensee could not explain how (if) FSAR assumptions on ECCS leakage were satisfied.
Later review of FSAR indicated leakage within '
assumptions.
l FROM: 1/1/90 TO: 6/6/96 Page 10 of 20 06-Jun-96 l
w.
x
SFA DATE TYPE SOURCE ID '
PRIM SEc ITEM APPARENT CAUSEICOMMENTS 2/7/96 OTHER IR 96-02 N
PS EP exercise demonstrated that onsite emergency plans w re adequate and that licensee was capable of implementing them.
2R/96 POS IR 96-02 N
PS Licensee made significant observation of E-Plan Ucensee objectively questioning execution - 2 practice drills were required prior overall state of readiness.
to graded exercise for management to be satisfied with performance. Management determined that more frequent drills were required to ensure readiness.
2R/96 NEG IR 96-02 N
PS Two areas for impro' ement identified in graded inconsistencies in the use of v
EP exercise - Need for management to become Ficrida Notification Message more involved in assuring correctness of info Form. Confusion existed between being provided in offsite notification forms and NLOs dispatched from CSC and
~
need to refine C&C for damage control teams.
Control room for similar repair missions.
2/7/96 POS IR 96-02 N
PS Licensee's onsite emergency organization was found to be well-defined and generally effective at dealing with simulated emergency during graded exercise.
2/7/96 POS IR 96-02 N
PS Communication among the licensee's emergency response facilities and emergency organization and emergency response organization and offsite authorities were good during graded exercise.
2/7/96 POS IR 96-02 N
PS Observations of licensee performance in CR, TSC, OSC, and EOF indicated good command and control, staff utilization and staff demeanor during graded exercise.
FROM: 1/1/90 TO: 6/6/96 Page 11 of 20 06-Jun-96
CFA DATE TYPE SOURCE ID PMM SEc ITEM APPARENT CAUSEICOMMENTS 1/26/96 VIO IR 96 N O
Violation identified regarding temporary changes Procedure Control VIO 96-01-01 to procedure which changed intent and which were approved for use without prior FRG review.
1/26/96 OTHER IR 96-01 N
O Inspection of corrective action program revealed Corrective Actions timely action on the part of management, but weaknesses in plans for tracking progress on personnel performance and procedure quality improvement.
1/22/96 VIO IR 96 1.
O E
Boron dilution event due to operatorleaving Operator error, poor short taim EA 96-040 control panel while dilution was in progress.
tumover, poor command and Weak command and control, procedural control adherence, and short-term tumover.
Additionally, OP for boration/ dilution not consistent with FSAR and no 50.59 performed.
1/7/96 N
O SALP CYCLE 12 BEGINS
-1/5/96 NCV IR 95 N O
PS Several deficiencies in prodecure change Failure to Property implement NCV 95 process implementation identified. Expired or Procedures 01 cancelled TCs found in control rooms and hot shutdown panel.
1/5/96 NEG IR 95-22.
N O
Several procedural deficiencies and inadequate Procedure Review and calculational errors identified in reload physics Execution test procedure.
FROM: 1/1/90 TO: 6/8/96 Page 12 of 20 06-Jun-96
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SFA DATE TYPE SOURCE ID PMM sEc ITEM APPARENT CAUSE / COMMENTS 1/5/96 WEAK IR 95-22 L
O M
U2 manual RX trip on high generator H2 temp Temp ControlValve Failure due to failure of temp control valve. Operator awareness of RPS status post-trip poor.
Inspedion of post-trip review (for current trip as well as past trips) indicated weaknesses in the rigor of post-trip reviews 1/5/96 VIO IR 96-04 L
O NLO failed to employ procedure when placing Failure to use procedure, falture to EDG fuel oil tank on recirculation for chemistry.
notify control room of evolution.
As a result, he improperty performed the evolution by isolating the discharge of the EDGFO transfer pump, which resulted in an inoperable EDG.
12/27/95 NEG.
IR 95-22 S
O E
FRG meeting suffered / items deferred due to Lack of Attendance at FRG lack of OPS /Eng'g attendance at meeting.
Major issues at meeting affected OPS /Eng'g.
12/20/95 OTHER 1R 95-22 S
M RX vessel flange inner O-ring groove pitting Pitting - Localized Corrosion resulted in cooldown and head removal for repair.
12/9/95 OTHER IR 95-22 L
M 2A2 RCP seal pkg lower seal destaged due to Filling RCS Before Coupling RCP reverse pressure across seal.
12/5/95 WEAK IR 95-22 N
O M
ESFAS cabinet doors found unlocked following Poor Logkeeping/ Attn to Detail maintenance work-l&C error. Log entries associated with work were not complete.
12/1/95 WEAK IR 95-21 N
O Followup to previous inspection findings Corrective Adions indicated a weakness in followthrough in addressing deficiencies.
FROM: 1/1/90 TO: 6/6/96 Page 13 of 20 06-Jun-96
SFA DATE TYPE SOURCE ID PRIM SEc ITEM APPARENT CAUSEICOMMENTS 12/1/95 NEG IR 95-21 N
O.
SDC Procedure required natural ciro-related ProceduralInadequacy surveillance prior to establishing RCS pressure boundary. Natural cire not possible without pressurization.
12/1/95 NEG IR 95-21 N
'O Recurrent non-valid alarms when starting fire FTF Procedure pumps were not documented as operator workarounds. Voltage dips associated with such starts were contributors to a trip previously.
12/1/95 WEAK IR 95-21 N
O Clearance in place to isolate N2 from CST to-Poor Corrective Actions facilitate pressure switch replacement for nine days without work order being written.
12/1/95 WEAK tR 95-21 N
O CCW sample valve showed dualindication FTF Procedure without corrective action documentation initiated.
12/1/95 NEG' IR 95-21 N
O Operators unable to effectively obtain I&C Inadequate Operator Training setpoints from computer after hard copies were removed from control room.
12/1/95 WEAK IR 95-21 N
O SDC procedure contained conflicting values for Procedural Weakness / Inadequate RX cavity level requirements. Procedure had Review been approved since emphasis on accuracy stressed.
l 12/1/95 NEG IR 95-21 N
O Unit 2 procedures and valve deviation log used Valve Position Administrative l
to cycle Unit 1 cross connect valves.
Controls l
l FROM: 1/1/90 TO: 6/6/96 Page 14 of 20 06-Jun-96 l
l
[
1
CFA DATE TYPE SOURCE ID PRIM SEC ITEM.
APPARENT CAUSE / COMMENTS 12/1/95 NEG IR 95-21 N
PS Rad survey results unavailable for B hot' leg Failure.to Document RAD Survey work. Surveys performed but not documented.
11/27/95 VIO IR 95 L O
Missed RCS Boron sample surveillance -
Personnel Error i-VIO 95-21-03 Repeat from IR 95-18.
11/21/95 OTHER IR 95-21 S
O Light socket failure during lamp replacement Equipment Failure results in loss cooling to 1 A Main Transformer.
Unit downpower to -60E 11/21/95 NCV IR 95 L O
Failure to maintain Penetration Log.
FTF Procedure NCV 95 t 04 11/20/95 VIO IR 95 N
_O Valve discovered Closed vice Locked Closed as FTF Procedure VIO 95-21-01 specified on Equipment Clearance Order.
11/16/95 OTHER 1R 95-21 S
O M
Unit 1 manua!!y tripped when 18 MFRV locked Long-Standing Equipment Problem in 50% position. Root cause - degraded power supply, compounded by voltage dip on starting both station fire pumps.
11/11/95 VIO IR 95 N O
Tech. Spec. equiprhent not specified for IV on
~FTF Procedure VIO 95-21-02 Equipment, Clearance Order.
FROM: 1/1/90 TO: 6/6/96 Page 15 of 20 06-Jun-96
SFA DATE TYPE SOURCE ID PfuM SEC ITEM APPARENT CAUSEICOMMENTS 11/6/95 -
OTHER 1R 95-21 S
M Failure of EDG 2A relay sockets. Potential Equipment Failure common mode failure.
11/1/95 NCV IR 95 S M
ICI wiring errorduring RX head installation last Personnel Error NCV 95 RFO.
05 10/19/95 NCV IR 95.
S O
Missed shift CEA position indication surveillance. Personnel Error NCV 95 06 10/18/95 NCV IR 95 L O
Missed RCS Boron sample surveillance.
Personnel Error NCV 95 07 10/17/95 WEAK IR 95-18 S
O Lack of attention to task resulted in overfilling Personnel Error RCB lower cavity during flood up.
10/12/95 VIO IR 95-18.
S E
Inserting CIAS signal during safeguards test Design Error VIO 95-18-04 shifted EDG 2A to isochronous mode while EDG paralleled with offsite power.
10/9/95 LER LER 95-S02 L
PS Potential route fo'r unauthorized access tp Personnel Error protected area, CW water piping.
FROM: 1/1/90 TO: 6/6/96 Page 16 of 20 06-Jun-96
SFA DATE TYPE SOURCE ID PRM SEc ITEM APPARENT CAUSEICOMMENTS 10/7/95 VIO IR 95 N O
Did not enter bypass key position in deviation Failure to Follow Procedures VIO 95-18-01 log.
10/5/95 OTHER IR 95-18 S
M DG 1B developed FO seak at threaded Equipment Failure connection during surveillance run.
9/30/95 VIO IR 95 N O
Did not enter bypass key position in deviation Failure to Fo!!ow Procedures VIO 95-18-02 log.
9/28/95 OTHER 1R 95-18 S
E Leaking PZR SVs extended forced outage -
Equipment Failure problems with tailpipe alignment.
9/20/95 OTHER 1R 95-18 S
M EDG 1 A/1B govemor contml problems resulted Equipment Failure in load oscillations.
~
9/15/95 VIO IR 95 S O
M Main / Ops did not provide clearance for work on Failure to Fo!!ow Proced6res VIO 95-18-03 condenser waterbox cover. When cover pulled closed, severed workers finger.
l 9/14/95 WEAK LER U1/U2 L
PS Security failed to take correct compensatory Failure to Follow Procedure 95-S01 action on computer failure.
9/10/95 WEAK IR 95-18 S
O SG blowdown sent to incorrect system on RAB Failure to Use Correct Prticedrue roof. Operator used wrong procedure. When Identified did not back out of procedure correctly.
FROM: 1/1/90 TO: 6/6/96 Page 17 of 20 06-Jun-96
SFA-DATE TYPE SOURCE ID PMM sEc
- ITEM,
~
APPARENT CAUSEICOMMENTS 9/9/95 WEAK IR 95-15 S
M Leak on SV 1201 flange extended outage, Weakness in Work Screening and identified one month earlier but not worked.
Planning 9/7/95 WEAK IR 95-15 L
O Unit 2 Main Generator overpressurized while Personnel Error / Inoperable fillin2 with H2. Inattention by operators.
Equipment /OWA 9/2/95 VIO IR 95.N O
Weaknesses identified in togs relating to Personnel Error VIO 95-15-03 abnormal equipment conditions and out of service equipment not logged (mulitple examples).
8/31/95 OTHER 1R 95-15 S
M Damaged cylinder and head on 1B EDG due to Personnel Error loose lash adjustment.
8/30/95 WEAK IR 95-15 N
M Maintenance personnel not using procedures for Supervisory Oversight and Worker work in progress.
Attitude 8/30/95
~ WEAK IR 95-15 N
PS Containment closure walkdowns by Management and QC Weaknesses management were inadequate and depended heavily on QC involvement to identify deficiencies.
8/29/95 VIO IR 95 t O
Started 1B LPSI pump with suction valve
. Personnel Error VIO 95-15-04 closed. (No damage to pump) i i
, FROM: 1/1/90 TO: 6/6/96 Page 18 of 20 06-Jun-96 b
SFA DATE TYPE SOURCE ID PRIM '
sEc ITEM APPARENT CAUSEICOMMENTS 8/29/95 VIO IR 95 N M
Maintenance joumeyman not signing off Procedure Use VIO 95-15-06 procedure steps as work completed (previously identified as a weakness in May 1995).
8/23/95 WEAK IR 95-15 S
M 2A HDP trip due to relay failure. Eight HDP trips Equipment Failure / Inadequate in past year. Engineering solution available but Corrective Action not implemented.
8/22/95 VIO
!R 95-15 N
PS QA failed to document a deficiency on Personnel Error containment spray valve surveillance identified in an audit.
8/19'/95 WEAK IR 95-15 s
~ O Overfill of PWT. Spilled approx.10K gallons on Operator Error / Operator ground inside RCA. Operatorwork around on Workaround level control system and inattention to filling process by operator caused error.
8/18/95 WEAK IR 95-15 N
M Procedural weakness involving supervisory Procedural Weakness oversight and joumeyman qualification.
8/17/95 VIO LER U195-S O
Spraydown of Unit 1 containment. STAR Procedural Inadequacy and 007 - VIO 95-process did not assign accountability for Weakness / Operator-Work-Around 15 corrective action. Valve surveillance prelube not documented on STAR.
8/9/95 VIO IR 95 L M
Inoperable Unit 1 PORVs due to maintenance Maintenance / Testing Errors LER U195-error / testing inadequacies. (Valves assembled 005 - EA 95-incorrectly) (Used acoustic data only) 180
. FROM: 1/1/90 TO: 6/6/96 Page 19 of 20 06-Jun-96
CFA DATE TYPE SOURCE ID PR!M SEc ITEM APPARENT CAUSE ICOMMENTS BE)/95 VIO -
LER U195-S E
Ufting of Unit 1 SDC thermal relief due to Corrective Action / Procedural 006 - VIO 95-procedural revision from previous corrective Weakness 20-01 action. Inoperable equipment not logged.
8/2/05 VIO LER U195-L O
1 A2 RCP seal failure due to
- restaging" at high Procedural Weakness /Fallure to 004 - VIO 95-temperature.
Follow Procedures 15-02 8/2/95 VIO LER U195-s O
Operator failed to block MSIS actuation during Operator Error 04 - VIO 95-cooldown.
15-01 SALP Functional Areas:
ID Code:
E ENGINEERING L
UCENSEE M
MAINTENANCE N
NRC O
OPERATIONS -
S SELF-REVEALED PS PLANT SUPPORT SA SAFETY ASSESSMENT & QV l
FROM: 1/1/90 TO: 6/6/96 Page 20 of 20 06-Jun-96
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s St. Lucie Agenda f
Bimonthly Meeting with Licensee (open to public) y 0630-0645 Arr*ve on site 0645-0800 Discussion of current events and media interest 0800-0930 Plant Tour 0030-1200 Public Meeting 1200-1300 Lunch in South Service Buildmg 1300-1400 Meeting with A. Stall-1400 1430 Meeting with J. Scarola 1500 Depart Note -
Media interest is expected at public meeting, items of n ent press interest l
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l EXECUTIVE
SUMMARY
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Pre-Decisional Semiannual Plant Performance Assessment St. Lucie 1 and 2 Current SALP Assessment Period: 1/7/96 through 6/97 Last SALP Rating Previous SALP Rating 1/2/94 - 1/6/96 5/3/92 - 1/1/94 Operations 2
1 Maintenance 2
1 Engineering 1
1 Plant Support 1
1 j
Last INP0 Assessment: 1 Previous INP0 Assessment: 1 4
I.
Performance Overview Since July 1995, there have been a series of events that led to questioning the plant's overall performance. These have included:
e The attempt to restage an RCP seal using inadequate and j
inappropriate procedural guidance. The evolution was compounded i
by failing to follow aspects of the guidance that did exist, which led to the failure of the second and third stage s'eals (SL4).
e Both. pressurizer power operated relief valves being found inoperable due to incorrect assembly during a refueling outage.
The conditions had existed for approximately 10 months (SL3,CP).
e An loss of RCS inventory (4000 gallons) due to a shutdown cooling relief valve which lifted and then failed to reseat due to incorrect setpoint margins (a generic problem involving several valves). The licensee had sufficient evidence that this generic condition existed, but had failed to act promptly to evaluate the conditions (SL4).
e The spraydown of containment due to an inadequate procedure and operator error coupled with an existing operator-work-around (SL4).
e On January 5,1996, a Unit 2 manual reactor trip resulted from the malfunction of a temperature control valve which provided water to generator hydrogen coolers. - The valve in question had been recently reworked, and the operator failed to act on the valve's erratic performance after placing it in service.
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~ e The significant operator inattentiveness which resulted in the overdilution event on January 22, 1996,. highlighted the recent large number of personnel errors and lack of command and control in the control room (SL3, CP).
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On February 22, 1996, a dropped CEA and an ensuing Unit I shutdown resulted in the declaration of an unusual event. During the shutdown, main feedwater regulating valve instabilities resulted in operators manually tripping the unit.
e On February 24, a containment radiation monitor was rendered inoperable for two days due to an improper valve lineup following i
a grab sample. As a result, the unit was started up without this TS-required component available.
Several instances of failure to
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follow procedures and operator inattention led to the extended period of inoperability (SL4).
On April 20, Unit 2 was removed from service due to low auto-stop e
oil pressure due to partial blockage in an auto-stop oil orifice.
Note that contaminants in Unit 2 turbine lube oil (same as auto stop oil) is considered to be responsible for damage to Unit 2 J
generator beaHngs, discovered after the June'6 Unit 2 trip.
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On May 12, fuel movement was commenced on Unit I without only 1 of e
2 wide range NI channels available. Operators performing a
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surveillance test on the inoperable channel did not coordinate with the refueling center properly.
On June 6, Unit 2 was, manually tripped due to high generator gas t
e temperature.
Root cause was a screw which vibrated loose and resulted a temperature control valve feedback arm falling free of F
its connection. This failure mode had been encountered *before.
Following the event, damage to the main generator bearings was F
identified, resulting in a 2 to 4 weck unscheduled outage.
1 These and several other recent deficiencies involving weak procedures, a L
general lack of procedural compliance, equipment failures, and personnel errors clearly indicated that the plant's past high level of performance had declined. An NRC root cause effort determined that, in addition to procedural adherence / adequacy weaknesses, the licensee. suffered from weaknesses in both interfaces across organizational lines and corrective actions.
. II.
Functional Area Assessments A SALP board convened on January 18, 1996. The board concluded that the j
licensee's performance.in the areas of Operations and Maintenance' had declined from excellent levels of performance to good levels. The conclusions reached by the board are summarized below.
Operations The board determined that safety-performance in the Operations area had i
declined, particularly in the final six months of the assessment period.
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As bases, the board noted an increase in the number of operational events attributable to:
e Weaknesses in operator performance e
On January 22, 1996, operator inattentiveness resulted in an overdilution event. The event began when an operator forgot he'was diluting the unit, continued when an inadequate
-turnover between himself and another operator took place, and included a lack of command and control on the part of the shift SRO, who was near the center of the activity throughout, e
On January 5,1996, a Unit 2 manual reactor trip resulted from the malfunction of a temperature control valve which l
provided water to generator hydrogen coolers. The valve in question had been recently reworked, and the operator failed to observe the valve's erratic performance after placing it in service.
e On October 17, 1995, operator inattention to detail resulted in an overfill of the Unit 2 lower reactor cavity during floodup and prior to establishing integrity in the cavity seal ring.
e On August 2,1995, a main steam isolation signal was generated due to an operator failing to block a MSIS signal during a cooldown when an annunciator indicated that the block was enabled. This failure occurred despite the fact that the operator's attention was directed to the annunciator on at least two different occasions.
e On March 4,1995, an approximate 14 minute loss of shutdown cooling event occurred when an operator cycled the wrong valve during a train swap. The valve was cycled out of sequence and weak annunciator respons.e complicated recovery.
Acceptance of long-standing equipment deficiencies e
On August 17, 1995, a spraydown of the Unit I containment was caused, in part, by the licensee's willingness to operate with a valve in its fail-open position following the valve's failure to satisfy stroke-time requirements.
The operator workaround process was not aggressively pursued by the licensee until issues such as the spraydown of unit I containment p'ointed out the cost of living with defi.cient conditions. Once management became committed to resolving the operator workarounds, many more were identified ahd 43, have been completed to date. ~
e' Management expectations were not effectively communicated to personnel and enforced 6
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e-Management has failed.to achieve the desired level of operator attentiveness, evidenced in the overdilution event and numerous NRC-identified control room indication deficiencies.
e Standards of chronological logkeeping, out-of-service logkeeping, and valve deviation and key logkeeping have not, until recently, been consistently applied. A number of recent violations-in this area have been identified, and the failure to maintain a current valve deviation log complicated a loss of RCS inventory event.when floor drains were found to be unintentionally shut, result _ing in an accumulation of 4000 gallons of coolant in the Unit 1 pipe 1.unnel.
Standards of. prompt notification of licensee. management by operators have not been maintained, as evidenced by failures-to notify the. Operations Supervisor in a timely fashi~on for the recent overdilution event and the loss of a number of Unit 2 control room annunciators the next night.
Weaknesses in procedural adequacy and adherence o
Procedural violations have accounted for 16 SL IV violations in the last (24 month) SALP cycle.
.e Th'e licensee's shift to a verbatim compliance policy resulted in hundreds of changes to procedures, required in order.for the procedures to be followed. Management of the procedure change process then became a challenge, as the system in place was no.t prepared to deal with the increased volume.
e On August 17, a spraydown of Unit I containment was due to an inadequate procedure and operator error coupled with an existing operator-work-around.
e-On August 2,1995, an attempt to restage an RCP seal using inadequate and inappropriate procedural guidance, compounded by failing' to follow aspects of the guidance that did exist, led to the failure of 3 of 4 stages of the seal package.
e-On July'29, 1995,'a Unit I trip occurred during l
turbine trip testing due to procedural weaknesses, poor operator performance, and weak supervisory oversight.
e.
Implementation' and. adequacy of corrective actions e
. Inadequate corrective act. ions.resulted in repeated failures to perform TS surveillance sampling of the SITS and the RCS for boron concentration.
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On August 6,.1995, a loss of RCS inventory (4000 gallons) due to a shutdown cooling relief valve which lifted and then failed to reseat due-to incorrect setpoint margins (a generic problem involving several valves). The licensee'had sufficient evidence that this generic condition existed, but had failed to act promptly to evaluate the conditions.
4 o
On August 29,-1994, inadequate corrective actions for an NRC NOV, regarding safeguards testing with respect to swing intake and component cooling water pumps, resulted in operators placing the electric plant in a configuration which made an EDG inoperable.
The licensee undertook' a number of efforts to reverse declining performance following the onset of the operational events described above.
Verbatim procedural compliance was established as the norm for the site, which resulted in the need for literally hundreds of procedural changes and around-the-clock on-site review committee meetings. An increased emphasis on the initiation of corrective action documentation resulted in an increase in the number of documents initiated, but has also resulted in increases in backlogs.
As of' June 7, licensee performance appears unchanged. Operator errors 3
continue to indicate attention-to-detail deficits.
Full power operations have been challenged by equipment issues, including the operability of CEAs (both units), degradation of the Unit 2 condenser circulating water outlets, and Unit 2 generator gas cooling problems (two trips attributable to different aspects of the same valve).
The corrective action program for the site has been changed to reflect the program at Turkey Point and management has encouraged the use of the-system by all employees.
Increases in the use of the new " Condition Report" process has been noted, i
Maintenance The board determined that performance in this area declined during the previous assessment period. However, the board found that six unit trips which occurred during the period had roots in maintenance.
4 Weaknesses identified by the board included:
Inadequate post-maintenance testing e'
On January 5,1996,:a Unit 2 manual reactor trip resulted from the malfunction of a temperature control valve which provided water to generator hydrogen coolers. The. valve in question had been recently reworked, but it had not been
- dynamically tested, nor was testing planned.
e On August 9, 1995, both pressurizer power operated relief valves were found inoperable due to incorrect assembly during a refueling outage. The conditions had existed for approximately 10 months and were not detected through the 9
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e Procedural adequacy and adherence
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Instability in management due to acting managers while the L
maintenance manager received SR0 training 1
The board indicated that the current stability of the maintenance i
management appeared to be reversing the observed negative trends.
Since the SALP, maintenance has been found to be generally acceptable,
.although equipment reliability has presented severa'l challenges to Operations, as described above.
Engineering I
The board found that engineering had sustained a superior level of performance. Support to both operations and maintenance, the quality and support of. design modifications, and initiatives to' reduce the l
numbers of operator workarounds and jumpers / lifted leads we seen as strengths.
Licensee submittals to the NRC were noted to be of high
' quality, as were. safety evaluations.
l Since the SALP, issues have been raised which question the licensee's ability to properly implement design changes. NRC walkdowns have identified. numerous cases of annunciator response procedural prrors (due to design changes), several drawing errors, and operating procedures which were not in full agreement with the plant configuration.
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Plant Support The board found that plant support organizations collectively performed at a superior level. Area breakdowns were as follows:
Health Physics was identified as having strong management support
-e and initiatives such as remote monitoring and electronic dosimetry were seen as strengths.
Reductions in the areas of contaminated floor space and the volume of solid waste were also noted.
Since the SALP, the NRC has identified several examples of poor HP worker. practice and inconsistencies in HP briefings.
e-Security was cited as maintaining an excellent level.of performance during staff reductions due to the implementation of biometrics.
Training, including the use of a combat f. iring range, and self-as.sessments were considered good.
Some performance problems were noted through the period, however, including two failures to provide compensatory measures during computer failures.
i Fire Protection performed well in both drills and in responding to
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e plant fires; however, surveillance testing obs'ervations indicated d
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weak; procedures, poor attention to detail, and hardware
-deficiencies.
Since the SALP, the NRC identified numerous cases of fire brigade members standilig watches with expired physical examinations.
Programmatic failures led to the findings.
e Emergency preparedness was considered good, and the status of equipment'and supplies were found to be adequate. The full participation exercise was successful.
Since the SALP, the licensee has declared to Unusual Events _(Unit I shutdown due to dropped CEA and Unit.2 excessive RCS leakage).
The first was found to be a conservative decision, while the second was found.to be nonconservative.
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Pre-Decisional i
Semiannual Plant Performance Assessment St. Lucie I and 2
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Current SALP. Assessment Period: 1/7/96 through 6/97 Last SALP Rating Previous SALP Rating 1/2/94 - 1/6/96 5/3/92 - 1/1/94 Operations 2
1 Maintenance 2
1 Engineering 1
1 Plant Support 1
1 I.
Performance Overview Since July 1995, there have been a series of events that led to questioning the. plant's overall performance. These have included:
A Unit I turbine trip due to procedural weaknesses, poor operator performance, and weak supervisory oversight.
The attempt to restage an RCP seal using inadequate and inappropriate procedural ~ guidance. The evolution was compounded
)
by failing to follow as)ects of the guidance that did exist, which i
led to the failure of t1e second and third stage seals.'
A main steam isolation signal due to an operator failing to block the MSIS signal during a cooldown when an annunciator indicated that the block was enabled. This failure occurred despite the fact that the operator's attention was directed to the annunciator on at least two diffvent occasions.
Both pressurizer power operated relief valves being found inoperable due to incorrect assembly during a refueling outage.
The conditions had ex.isted'for approximately 10 months (SL3,CP).
An loss of RCS inventory (4000 gallons) due to a shutdown cooling relief valve which lifted and then failed to reseat due to incorrect setpoint margins (a generic problem involving several valves). The licensee had sufficient evidence that this generic condition existed, but had failed to act promptly to evaluate the j
conditions (SL4)..'
The spraydown of containment due to an inadequate procedure and operator error coupled with an existing operator-work-around.
The significant operator inattentiveness which resulted in the overdilution event on January 22, 1996, highlighted the recent large number of personnel ' errors and lack of command and control in the control room.
These and several other recent deficiencies involving weak procedures, a
general lack of procedural compliance, equipment failures, and personnel errors clearly indicated that the plant's past high level of performance i
had declined. An NRC root cause effort determined that, in addition to procedural adherence / adequacy weaknesses, the licensee suffered from weaknesses in both interfaces across organizational lines and corrective actions.
II.
Functional Area Assessment - Operations A.
Assessment i
A SALP board convened on January 18, 1996. The board concluded that the licensee's performance in the areas of Operations had declined from an excellent level of performance to good. The
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decline in Operations' performance particularly occurred in.the final six months of the assessment period. The licensee undertook a number of efforts to reverse declining performan' c following the onset of the operational events described above.
Verbatim procedural compliance was establfshed as the norm for the site, 1
which.resulted in the need for literally hundreds of procedural changes and around-the-clock on-site review committee. meetings.
An increased emphasis on tho initiation of corrective action documentation resulted in an increase in the number of documents initiated,.but has also resulted in increases in backlogs.
As of June 7, licensee performance' appears anchanged.
Operator errors continue to indicate attention-to-detail deficits.
Full power operations have been challenged by equipment issues, including the operability of CEAs (both units), degradation of the Unit 2 condenser circulating water outlets, and Unit 2 generator 1
gas cooling problems (two trips attributable to different aspects of the same valve).
The corrective action program for the site has been changed to reflect the program at Turkey Point and management has encouraged the use of the system by all employees.
Increases in the use of the new " Condition Report" process has been noted.
B.
Basis As basis, the board noted an increase in the number of operational events attributable to weaknesses in operator performance, acceptance of long-standing equipment deficiencies, Management expectations not being effectively communicated and enforced, weaknesses in procedural adequacy and adherence, and implementation of corrective actions.- Examples, both from the previous'SALP cycle and the current one, are as follows:
e Weaknesses in operator performance e
On May 12, fuel movement was commenced on Unit I without only 1 of 2 wide' range NI channels available.
Operators performing a surveillance test on the inoperable channel did not coordinate with the refueling center properly.
e On' February 24, a containment radiation monitor was
)
rendered inoperable for:two, days due to an improper valve lineup following a grab sample. As a result, the unit was started up without this TS-required component available. Several instances of failure to follow procedures and operator inattention led to the extended period of inoperability (SL4).
e On. January 22, 1996, operator inattentiveness resulted in an overdilution event. The event began when an operator forgot he was diluting the unit, continued when an inadequate turnover between himself and another operator took place, and included a lack of command and control on the part of the shift SRO, who was near the center of the activity throughout.
e On January 5,1996, a Unit 2 manual reactor trip resulted from the malfunction of a temperature control valve which provided water to generator hydrogen coolers. The valve in question had been recently reworked, and the operator failed to observe the valve's erratic performance after placing it in 4
service.
e On October 17, 1995, operator inattention to detail resulted in an overfill of the Unit 2 lower reactor cavity during floodup and prior to establishing integrity in the cavity seal ring.
e On August 2,1995, a main steam isolation signal was generated due to an operator failing to block a MSIS signal during a cooldown when an annunciator indicated J
that the block was enabled. This failure occurred despite the fact that the operator's attention was directed to the annunciator on at least two different occasions.
e On March 4, 1995, an approximate 14 minute loss of
~
shutdown cooling event occurred when an operator cycled the wrong valve during a train swap. The valve j
was cycled out of sequence and weak annunciator response complicated recovery.
e Acceptance of long-standing equipment deficiencies e
On August 17, 1995, a spraydown of the Unit 1 containment was caused, in part, by the licensee's willingness to operate with a valve in its fail-open i
position following the valve's failure to satisfy stroke-time requirements.
e The operator workaround process was not aggressively pursued by the licensee until issues such.as the spraydown of unit I containment pointed out the cost l
of living with deficient conditions. Once management became committed to resolving the operator workarounds, many more were identified and 43 have been completed to date.
e Management expectations were not effectively communicated to personnel and enforced j
e Management has failed to achieve the desired level of operator attentiveness, evidenced in the overdilution event and numerous NRC-identified control room indication deficiencies'.
Standards of chronological logkeeping, out-of-service logkeeping, and valve deviation and key logkeeping have not, until recently, been consistently
- applied ~.
A number of recent violations in this area have been identified, and the failure to maintain a current valve deviation log complicated a loss of RCS l
inventory event when floor drains were found to be unintentionally shut, resulting in an accumulation of j
4000 gallons of coolant in the Unit 1 pipe tunnel.
Standards of prompt notification of licensee management by operators have not been maintained, as j
evidenced by failures to notify the Operations i
Supervisor in a timely fashion for the recent overdilution event and the loss of a number of Unit 2 control room annunciators the next night.
e Weaknesses in procedural adequacy and adherence o
Procedural violations have accounted for 16 SL IV violations in the last (24 month) SALP cycle.
e The licensee's shift to a verbatim compliance policy resulted.in hundreds of changes to procedures, required in order for the procedures to be followed.
Management of the procedure change process then became a challenge, as the system in place was not prepared to deal with the increased volume.
4 e
On August 17, a spraydown of Unit I containment was due 'to an inadequate procedure and operator error coupled with an existing operator-work-around, e
On August 2,1995, an attempt to restage an RCP seal using inadequate and inappropriate procedural guidance, compounded by failing to follow aspects of the guidance that did exist,. led to the failure of 3 of 4 stages of the seal package.
e On July 29, 1995,~a Unit I trip occurred during turbine trip testing due to? procedural e
5 weaknesses, poor operator performance, and weak supervisory oversight.
l e
Implementation and adequacy of corrective actions e
Inadequate corrective actions resulted in repeated failures to perform TS surveillance sampling of the SITS and the RCS for boron concentration.
e On August 6, 1995, a loss of RCS inventory (4000 gallons) due to a shutdown cooling relief valve which lifted and then failed to reseat due to incorrect setpoint margins (a generic problem involving several valves). The licensee had sufficient evidence that this generic condition existed, but had failed to act promptly to evaluate the conditions.
e On August 29, 1994, inadequate corrective actions for an NRC NOV, regarding safeguards testing with respect to swing intake and component cooling water pumps, resulted in operators placing the electric plant in a configuration which made an EDG inoperable.
t C.
Future Inspections Increase staffing at St Lucie to N + 1 and focus greater inspection effort in the areas of: routine operator performance -
professionalism in CR; procedural compliance and enhancements; operator problem identification and corrective action; management communication of expectations; interdepartmental interface; resolving impact of operator work arounds; and operation contribution to adequacy of safety evalsations.
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6 III.
Functional Area Assessment - Maintenance A.'
Assessment Adverse trends were noted in maintenance and the board concluded that the licensee's performance in the area of Maintenance had declined from an excellent level of performance to good. The EDG problems indicate a weakness in EDG Maintenance. The number of problems related to personnel errors and procedure problems may indicate possibly attitude problems. Also,. Safety Equipment i
performance has failed to meet the industry average on all _ safety system. Maintenance performance has declined.
Since the SALP, maintenance has been found to be generally i
acceptable, although equipment reliability has presented several challenges to Operations, as described above.
B.
Basis 1.
Adverse trends were noted on the Site Integration Matrix.
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Recent Equipment Failures:
01/23/96-Elect. arc during maint. caused loss of 25% of control room annunciators 12/20/95-Pitting of reactor flange o' ring groove 11/06/95 - Failure of EDG 2A relay sockets 10/05/95 - EDG IB fuel oil leak at threaded connection 09/20/95 - EDG 1A/IB governor control problems resulted in load oscillations
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Recent Personnel Errors-01/01/96 -
ICI wiring error during Rx head installation 08/31/95-Damaged cy. head on IB EDG due to loose lash adjustment 08/09/95 -
Inoperable Unit 1 PORV due to maintenance error / testing inadequacy Recent Procedure Problems:
12/09/95-2A2 RCP seal destaged due to inadequate or weak procedure 09/15/95-Failure to have clearance for work on cond. water box 08/25/95-Failure to sign off procedure steps as work completed 2.
Safety Equipment Performance (Availability %) has been below industry a average,
. Actual Industry Averages Unit 1 Unit 2 AFW 99.5 97.8 99.6 - 99.1 HPSI 96.0 98.8 99.7 - 99.2 EDGs' 95.6 99.8 99.1 - 98.6
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- 2C-AFW steam admission valve did not open and-mbchanical trip linkage problem u
- HPSI 2B Breaker Failure y
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Numerous equipment failures have caused power reductions:.
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- 10/95 Unit 1 Heater Level Control i
10/95 Unit 1 IB Heater Drain _ Pump
- 11/95 Unit-1 FW Reg. V1v. Control
- 11/95 Unit 1 1A Main Transformer
- 01/96 Unit 1 FW V1v. LSV-24-A2
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- 08/95 Unit 2 Heater Drain Valve
- 08/95 Unit 2 Heater Drain Pump l
- 08/95 Unit 2 Cire. Water Valve
- 08/95 Unit 2 Htr. Drn. Pmp. PCM I
- 01/96 Unit 2 Hydrogen Sys. Prob.
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--01/96 Unit 2 MFW Pump
- 04/96 Unit 2 Auto Stop Oil Pressure
- 04/96 Unit 2' Circulating Water Pipe Leaks
- 06/96 Unit. 2 TCW Temperature Control Valve C.
Future Inspections: Assist the Resident inspector with the routine Resident Maintenance / Surveillance Inspections program.
~ Conduct Regional Initiative inspection, focus on outage activities BOP and EDG maintenance, procedure adequacy and safety system performance.
Perform maintenance rule inspection in September 1996.
Conduct the ISI inspection.
IV.
Functional Area Assessment. Engineering A.
Assessment Engineering performance at St. Lucie remairied superior during the SALP_per,iod ending January 6, 1996, and has not changed since-then. Continue with core inspections in the engineering area.
Since the SALP, issues have been raised which question the licensee's ability-to properly implement ~ design changes.
NRC walkdowns have identified numerous cases of annunciator response procedural errors (due to design changes), several drawing errors, and operating procedures which were not in full agreement with the plant configuration.
B.
' Basis The basis for the'above assessment'was the SALP report issued on' February 8,.1996, and a continued low number,of engineering issues. A recent inspection identified weakness in engineering safety evaluations._-
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C.
Future Inspection i
Conduct the following core inspections: engineering core inspection which focus on operability,10 CFR 50.59 evaluations, engineering support to maintenance and FSAR review; employee concern program due to increased number of allegations in the last 4
year; and corrective action plan implementation.
V.
Functional Area Assessment - Plant Support A.
Assessment j
i Mostoftheassessmentinformationinthepastsixmontiishasbeen i
captured in the most recent SALP report 95-99 dated February 8, 1996.
There were no specific inspections of the Radiation Protection (RP) program during the past 6 months. However, Resident Inspectors observed RP activities throughout the assessment period and performance was satisfactory. The RP j
program continues to adequately maintain external and internal l
radiation exposures within regulatory limits. The plant programs for plant chemistry, radiochemical analysis, radiological effluent and environmental monitoring, and radioactive waste shipping continued to be effective although some issues were identified.
4 The EP program continued to provide an adequate. level of readiness to respond to events. Overall, site security has been adequate.
Implementation of the fire protection program continued to be satisfactory.
Potential problem exists with " Speak Out" employee concerns. program (ECP).
Since the SALP, the NRC has identified several examples of poor HP worker practice and inconsistencies in HP briefings.
In the area of Fire Protection, the NRC identified numerous cases of fire brigade inembers. standing watches with expired physical examinations.
Programmatic failures led to the findings.
In the area of Emergency Preparedness, the licensee has declarbd to Unusual Events (Unit I shutdown due to dropped CEA and Unit 2 excessive RCS leakage). The first was found to be a conservative decision, while the second was found to be nonconservative.
B.
Basis Near the end of the assessment period the licensee missed some RCS boron surveillances. The surveillance was missed in October and a NCV 95-18-06 was identified. However the licensee's corrective actions were not sufficient to prevent a recurrence in November and a VIO 95-21-03 was issued.
Unit I was suspected of having some leaking fuel that was not evident prior to this assessment period.
No Exercise Weaknesses were identified in the Feb 1996 Full Participation Exercise. Site Management expressed concern.
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9 that two practice drills were necessary before the NRC 1
graded exercise to assure no NRC findings.
The licensee reported a training and qualification error in which security personnel were qualified using only half the required rounds, a failure to compensate within 10 minutes and problems with protected area barriers.
Fire protection inspections, conducted by resident inspectors, identified overall good performance but weaknesses in fire fighting techniques and respirator qualification program.
A large number of allegations have been received.
No pattern to organization but some against " Speak Out" program C.
Future Inspections Conduct the following core inspections in the areas of:
occupational exposure to observe RP practices;' security - to review audits, corrective action, plans, m'anagement support, review PA equipment, vital access and alarms; and employee concerns program implementation due to.large number of allegations dealing with adequacy of employee concern program.
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1 VI.
Attachments A.
Inspection Schedule j
B.
Power Profile (last six months)
C.
Site Integration Matrix 1
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REGION 11 i
j ATLANTA, GEORGIA PLANT STATUS REPORT l
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l ST. LUCIE i
Units 1 and 2 i
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i l-February,1996 i
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PLANT STATUS REPORT FOR ST. LUCIE i
TABLE OF CONTENTS I
PART 1 - FACILITY DESCRIPTION 4
1.1 FACILITY / LICENSEE....................................Page 2
4 1.2 UTILITY SLNIOR MANAGEMENT...........................Page 2 1.3 NRC STAFF............................................Page 2 L
1.4 LICENSE INFORMATION..................................Page 3 1.5 PLANT CHARACTERISTICS................................Page 3 1.6 SIGNIFICANT DESIGN INFORMATION.......................Page 3 1
i 1.7 EMERGENCY RESPONSE FACILITIES / PREPAREDNESS...........Page 8
~1.8 PRESENT OPERATIONAL STATUS (Past Six Months).........Page 9 1.9 OUTAGE SCHEDULE AND STATUS...........................Page 10 t
PART 2 - PLANT PERSPECTIVE 1
i l!.1 GENERAL PLANT PERSPECTIVE............................Page 11 i
2.2 SALP HISTORY (Past Two SALP Periods).................Page 11 4
2.3 SELECTED SALP AREA DISCUSSIONS
......................Page 11 PART 3'- SIGNIFICANT EVENTS 3.1 SIGNIFICANT EVENTS 8RIEFINGS (Past 12 Months)........Page 16 j
3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months)..........Page 16 PART 4 - STAFFING AND TRAINING e
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.4.1-OPERATIONS STAFF - 0VERALL'..........'................. Page I6 4.2 WORK FORCE
..........................................Page 17 4.3 OPERATOR QUALIFICATION /REQUALIFICATION PROGRAM.......Page 17 4.4 PLANT SIMULATOR......................................Page 17 4.5 INP0 ACCREDITATION...................................Page 17 i
PART 5 - INSPECTION ACTIVITIES i
l 5.1 DUTSTANDING ITEMS LIST
SUMMARY
.......................Page 18 5.2 MAJOR INSPECTIONS....................................Page 18 1
5.3 PLANNED TEAM INSPECTIONS.............................Page 18 1
5.4 INFRE0 VENT INSPECTION PROCEDURE STATUS...............Page 18 5.5 SIMS STATUS (OPEN.TMI ITEMS).........................Page 18 ATTACHNENTS 1.
PERFORMANCE INDICATORS i
2.
ALLEGATION STATUS 3.
NRR OPERATING REACTOR ASSESSMENT 4.
ORGANIZATION CHARTS 5.
POWER' HISTORY CURVES 6.
MASTER. INSPECTION PLAN (NOT INCLUDED) 7.-
SITE' ACTIVITY SCHEDULE 8.
SITE INTEGRATION MATRIX 9.
PERFORMANCE ANALYSIS GRAPH 4
( :
2 PART 1-FACILITY DESCRIPTION 1.1 FACILITY / LICENSEE FACILITY:
St. Lucie Units 1 and 2 PLANT LOCATION:
Hutchinson Island near Port St. Lucie, Florida LICENSEE:
Florida Power and Light Co. (Corporate Office in Juno Beach, Florida) 1.2 UTILITY SENIOR MANAGEMENT CORPORATE:
J. L. Broadhead (Jim), Chairman of the Board and CEO J. H. Goldberg (Jerry), President, Nuclear Division SITE:
W. H. Bohlke (Bill) - St. Lucie Plant Interim Vice President C. L. Burton (Chris) - Services Manager L. W. Bladow (Wes) - Nuclear Assurance Manager R. E. Dawson (Bob) - Business Manager D. J. Denver (Dan) - Site Engineering Manager A.
DeSoiza (Andy) - Human Resources Manager P. L. Fincher (Pat) - Training Manager T. G. Kreinberg (Tom) - Nuclear Materials Management Superintendent 4
J.
Marchese (Joe) - Maintenance Manager C. A. Pell (Ash) - Outage Manager L. A. Rogers (Lee) - Systems and Component Engineering Manager J.
Scarola (Jim) - Plant General Manager E. J. Weinkam III (Ed) - Licensing Manager J. A. West (Jeff) - Operations Manager 1.3 NRC STAFF REGION II, Atlanta,'GA:
S. D. Ebneter (Stew), Regional Administrator, (404) 331-5500 L. A. Reyes (Luis), Deputy Regional Administrator (404) 331-5610 E. W. Merschoff (Ellis), Director DRP, (404) 331-5623 K. D. Landis (Kerry), Branch Chief, (404) 331-5509 L. S. Mellen (Larry), Project Engineer, (404) 331,5561 E. Lea (Edwin), Project Engineer, (404) 331-3641 SITE:
M. S. Miller (Mark), Senior Resident Inspector, (407) 464-7822 S. S. Sandin (Steve), Acting Resident Inspector, (407) 464-7822
3 NRR:
D. B. Matthews, Director, Project Directorate II-2, (301) 415-1490 J. A. Norris (Jan), Senior Project Manager, Project Directorate II-2, (301) 504-1483 AEOD:
S. Israel (Sandy), Reactor Operations Analysis Branch, (301) 415-7573 1.4 LICENSE INFORMATION Unit 1 Unit 2 Docket Nos.
50-335 50-389 License Nos.
DPR-67 NPF-16 Construction Permit Nos.
CPPR-74 CPPR-144 Construction Permit Issued 7/1/70-5/2/77 Low Power License NA 4/83 Full Power License 3/1/76 6/10/83 Initial Crit.icality 4/22/76 6/2/83 1st Online 5/17/76 6/13/83 Commercial Operation 12/21/76 8/8/83 1.5 PLANT CHARACTERISTICS Dgscription Units 1 and 2 Reactor Type Combustion Engineering PWR, 2-loop Containment Type Freestanding Steel w/ Shield Building Power Level 830 MWe (2700 MWt)
Architect / Engineer Ebasco NSSS Vendor Combustion Engineering Constructor Ebasco Turbine Supplier Westinghouse Condenser Cooling Method Once Through Condenser Cooling Water Seawater 1.6 SIGNIFICANT DESIGN INFORMATION 1.6.1 REACTOR INTEGRITY Reactor Pressure Vessel (RPV)
With the present fuel type and management policy,. Unit 1 is expected to reach a 40-year RPV life. On this unit, the fuel type and management policy have been modified to make that RPV life span possible.
Presently, a program is evolving for RPV life extension beyond'the projected 40 years, potentially to 60 years, via a flux reduction program.
A flux reduction program has started with the addition of eight absorbers in core corner
i 4
positions, performance of vessel fluence calculations, and determination of an optimum power profile for each core load.
Calculations using current methodology and uncertainty predict a significant RPV life extension, but.not to 60 years.
Due to different design and construction characteristics, Unit 2 RPV life expectancy exceeds 60 years.
Low leakage core designs are now used for economic reasons, however the low 1eakage designs t
provide even greater life expectancy.
Reactor Coolant Pressure Boundary On this CE plant, ECCS-to-RCS injection points are isolated by at least two check valves and one closed MOV.
High pressure safety injection (HPSI), low pressure safety injection (LPSI), and containment spray (CS) pumps' common containment sump suctions are isolated from the containment sump by one closed MOV in conjunction with a closed seismic piping system.
The CS headers are isolated from containment by one closed MOV and a check valve in conjunction with a closed seismic piping system. CVCS has the normal complement of two automatic actuation isolation valves.
1.6.2 REACTOR SHUTDOWN Reactor-Protection System The reactor protection system provides protection for the reactor fuel and its cladding by providing automatic reactor shutdowns based on input from reactor power, reactor coolant pressure, coolant temperature, coolant flow, steam generator pressure, containment pressure, turbine hydraulic fluid pressure, and, in Unit 2 only, Component Cooling Water flow to reactor coolant pumps.
The RPS ifs a redundant, four channel system that operates on a two-out-of-four logic.
ATWS Protection LATWS protection, outside the normal reactor protection system, is initiated via the ESF pressurizer pressure signal.
It actuates by opening contactors. in the output of the CEA MG sets, thereby J
interrupting control element assembly power at its source.
This protection has been installed on both units per CE, the NSSS, recommendations.
Remote Shutdown Facilities These facilities are located in the switchgear rooms beneath each j
unit's control room.
1.6.3 CORE COOLING Feedwater System l
. i 5
'The main feedwater pumps are motor driven with each delivering 50 percent of the flow required for full power..
Turbine Bynass/ Steam Dumo Canacity i
.Each unit has five steam bypass ' valves, providing 45 percent of total capacity.
Unit'l has one atmospheric dump valve per train (two trains)'and Unit 2 has two valves per train.
Each unit has the capability of dumping nine percent steam ~ flow to the atmosphere.
Agg1]iary Feedwater System l
There are two motor-driven pumps on each unit with 100 percent l
capacity per pump.
There is one steam-driven pump on each unit with 200 percent capacity.
Any of the three pumps can inject to either steam generator. Automatic initiation and faulted steam generator protection are provided by each unit's Auxiliary
'Feedwater Actuation System provided by the NSSS.
Eneroency Core Coolino System In each unit, there are two HPSI pumps and two LPSI pumps with no unit-to-unit cross-connections. One pump of each type per unit will handle a postulated LOCA. The LPSI pumps also provide decay heat removal as required when the unit is shut down.
Decav Heat Remqy.Al i
As indicated above, the LPSI pumps also provide decay heat removal as required when the unit is shut down by taking suction from the RCS (hot legs), passing the fluid through the shutdown cooling heat exchangers,- and returning it to the RCS (cold legs). The 1
heat r'emoving medium is CCW -' discussed in section 1.7.6-below.
Shutdown cooling. flow path overpressure protection is provided by-automatic isolation valves and various relief valves in the system.
1:
i 1.6.4 CONTAINMENT Pressure Control / Heat Removal There are two containment spray pumps and four containment fan coolers available per unit to suppress pressure spikes and cool the containment.
One.CS pump and two fan coolers will handle a postulated LOCA.
There are no unit-to-unit cross-connections.
This engineered _ safety._ feature is automatically started by ESFAS.
'Hydrooen Control e
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.. - - - -. _. ~...
- V 2
.g
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Post-LOCA containment. hydrogen control 'is accomplished on each
~
unit.by two trains of hydrogen.recombiners located on the operating deck inside containment.
By elevating, in a controlled manner, the temperature of containment atmosphere flowing through
.the recombiner, the recombiner units ' recombine hydrogen and oxygen 4
to form water,-thus preventing the buildup of hydrogen to potentially explosive levels.
1.6.5 ELECTRICAL POWER j
i -
Offsite AC~
3 4
.The station switchyard is connected to the transmission system by three independent 240 KV,ines that share a right of way and l
interconnect with FPL's grid on the mainland approximately 10 t
miles West of the plant site.
There are two independent offsite 1
power feeds from the station switchyard to the emergency busses.
Onsite AC t
Onsite AC power is provided by four EDGs (two per unit).
EDGs are 1
i independent of other plant systems except vital DC power for
. control of starting. A Station Blackout (SBO) cross connection is installed and tested.
This cross-connection serves the emergency busses directly and reduces cross-connect time to less than 15 j
minutes.
.)
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DC power-5 Two trains of vital batteries per unit have been routinely tested for four-hour DC load profiles.
Recently, following a cell
[
i replacement, they have been tested for three-hour battery capacity instead. The battery capacity test is harsher than the load profile test and is intended to more accurately reflect expected 4
usage. There are four normal chargers per unit.with swing chargers available for. service.
Non-safety batteries can be cross-connected to the' safety-related swing bus if needed.
Instrumentation power Each unit has four inverters, two powered from each vital DC train, that provide four trains of instrumentation power.
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Station Blackout Resolution Status 1
i -
Unit 2 is a four-hour "DC coping" plant per the original license i
while tent 1 is subject to the station blackout (SBO) rule of 10 CFR 50.63 requiring additional licensee action (unit-to-unit cross-connect of 4160V' bus).
I I
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1.6.6 SAFETY-RELATED COOLING WATER SYSTEMS '
Intake Coolina Water (Service Water)
Intake cooling water (ICW) for each unit originates in the unit-common Intake Canal. The canal level varies with the tides since r
it is filled by a level difference between the Atlantic Ocean and the ICW pump's. One 16-foot and two 12-foot diameter pipes pass under the beach to connect the ocean and canal. The intake pipe ends in the Atlantic are covered by intake structures'(rebuilt in 1991) intended to limit flow velocities,'particularly vertical velocity, to reduce marine life entrapment. After use,~ICW returns to the ocean through the Discharge Canal and under-beach pipes.
Each unit has two trains of ICW plus a swing pump that can be aligned to either train electrically and physically. The licensee has converted the deep draft ICW pumps from externally (water) lubricated to self-lubricated to increase reliability.
The 100 percent (each) capacity pumps take suction from the intake canal via a canal intake structure using tra.veling screen debris protection. The intake canal structures adjacent to.the ICW pump i
suctions are continuously injected with a hypochlorite solution to reduce marine growth in the associated piping and heat exchangers.
The ICW pumps move water.through two trains of heat exchangers that cool component cooling water (CCW) and two trains of heat exchangers that cool main turbine cooling water. During a postulated accident, water flow isolates from the turbine cooling heat exchangers. The discharge from the heat exchangers returns via the discharge canal to the ocean.
Closed Coolina Water Systems Each unit has two trains of Component Cooling Water (CCW). The arrangement of two pumps and a swing pump mimics the.ICW system.
The swing pump can be aligned to either train. The 100 percent (each) capacity pumps drive water through the CCW/ICW heat exchangers and then on to the heat loads, mainly the containment fan coolers and the shutdown cooling -(decay heat) heat exchangers (which also can operate as containment spray heat exchangers),
Additionally, CCW cools a variety.of bearings, seals, and oil coolers for the HPSI, LPSI, and CS pumps. A non-safety-related portion of the CCW system cools reactor coolant pump seals and the spent fuel pool. This section isolates upon engineered safety-features actuation.
1.6.7 SPENT FUEL STORAGE Wet storage capability exists up to the year 2002 (Unit 2) and 2007 (Unit 1).
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8 l
1 1.6.8 INSTRUMENT AIR SYSTEM Instrument air compressors and driers on each unit ~ provide all instrument air for Unit 2 and all but containment air for' Unit 1.
-Unit 1.has instrument air compressors inside containment.
l 1.6.9 STEAM GENERATORS Each unit has two large steam gene.rators (SGs) rather than the' three or four usually seen. The licensee has begun to focus on a j
Unit 1 SG replacement in 1998. The SGs are under construction at_
l the B&W Canada shops and a site organization is functioning.
.1.7 EMERGENCY RESPONSE' FACILITIES / PREPAREDNESS Emergency Operations Facility:
10 miles West of site, I-95/ Midway Rd. Exit
'i Technical Support Center:
Onsite, Adjacent to
~
Unit 1 Control Room i
Operational Support Center:
Onsite, 2nd floor of '
North Service Building l
The last annual emergency preparedness exercise was in February,1996.-
This ' exercise was formally evaluated by the.NRC.
Since St. Lucie site has a high probability of hurricanes, communications facilities were improved following the Turkey Point experience with Hurricane Andrew in August, 1992.
Improvements include:
High Frequency Auto-link with other FPL sites and NRC.
Enhanced 900 MHZ System for site and mobile communications, with radios 'also in the licensee's EOF and county emergency facility.
Cellular phones with hardened antennas.
Hardened Local-Government Radio antenna ties.
1.8 PRESENT OPERATIONAL STATUS
-Availability Factors:
Unit 1 Unit 2 1991 81.0
~100.0 1992 96.5 75.2 i
1993 74.0 71.8 1995 (through 7/95) 86.8 79.6 i
1994 93.9 98.3 Cumulative (through 7/95) 77.7 83.7 I
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9 1.8.1 UNIT 1 OPERATING HISTORY (Past Twelve Months from 1/25/96)
Unit 1 operated continuously during the past 12 months with the
{-
following exceptions:
I-j On February 21, 1995, the unit was removed from service for the
+
j replacement of pressurizer code safety valves which had been leaking by the seat since shortly after startup in November,1994.
i On March 4,1995, the unit experienced a 14 minute loss of shutdown cooling.
The apparent root cause was operator error by a reactor operator placing.one loop of SDC in standby.
The operator apparently closed the suction valve to the operating, vice standby, pump.
The operator in question denied the error; however, the licensee detennined that he'was responsible. He resigned from the company. The unit was returned to service on -
March 8, 1994.
On July 8,1995, the unit tripped during turbine valve p
surveillance testing.
It returned to power on July 12, 1995.
On August 1,1995, the unit was shutdown as a result of Hurricane 2
Erin. Due to a series of equipment problems and personnel performance issues, the unit remained shut down for 73 days, Problems encountered during the shutdown included a maintenance-
)
induced RCP seal failure, discovery of two inoperable PORVs due to maintenance errors during refurbishment, a loss of inventory event while placing shutdown cooling in service due to lack of margin to relief valve lift setpoint and complicated by an excessive i
blowdown value, inadvertant spraydown of the Unit I containment, catastrophic failure of the IB EDG, and, leaking pressurizure code safety valve flange leakage. The unit returned to power on i
October 12.
?
On November 16, the unit was manually tripped when a feedwater regulating valve failed to the 50% position, resulting in low l
steam generator water level. The root cause of the failure was determined to be a faulty power supply.
The power supply was replaced and the unit was returned to service on November 18.
On January 22, 1996, operator error resulted in an excessive dilution event which resulted in reactor power accending to 100.2%. The operator in question apparently left the control room while dilution was in progress without informing other watchstanders of the evolution in progress.
The operator was
+
i removed from licensed duties and the final disposition of the event is pending.
i 1.8.2 UNIT 2 OPERATING HISTORY (Past Twelve Months from 1/25/96)
Unit 2 operated continuously during the past 12 mo.nths with the following exceptions:
~ '. '
g-
.v-.
i.
e<r
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10 On February 21, 1995, the unit. tripped as a result of low steam generator water level.
The condition was the result of a I
feedwater regulating valve closure after a steam generator water level control' level transmitter failed high.
The transmitter was-replaced and the unit was returned to service on February 25, t
F 1995.
'On April 25)1995, the unit was shutdown for approximately 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />s-to replace a main turbine DEH. power supply.
On August 1,1995, the unit was shutdown as a result of Hurricane Erin.
It was restarted on August 4, 1995, but operated at reduced
'>ower from August 17 through-29,.1995, to clean condenser water
> oxes and repair equipment problems.
On' October 9, the unit entered a refueling outage.
The outage was complicated by the discovery of leaks in RCS flow transmitter taps at the loops, a ranctor flange 0-ring leak, discovered during repressurization, and the failure of one stage of an RCP seal package. The unit returned to power on January 1, 1996.
i The unit was manually tripped from approximately 35% power on January 5 due.to high generator hydrogen temperature.
The root i
cause of the event was improper o>eration of a turbine cooling water temperature control valve w11ch supplied cooling water to the hydrogen coolers.
Post-trip review resulted in the discovery of clogged steam generator-water level transmitter sensing lines which resulted in artificially. low levels being indicated when steam generators were isolated upon turbine trip.
The lines were-i blown down and the unit was' returned to service on January 7.
)
1.9 OUTAGE SCHEDULE AND STATUS Unit l's last refueling outage began on October 26, 1994, and ended on November 29, 1994. Major activities included: refueling; reactor vessel nozzle and flange weld ISI inspection; installation of a permanent cavity seal ring; replacing reed switches-for several CEAs; integrated safeguards test;. steam generator tube inspection and plugging; steam i
generator sludge lancing; repair of refueling water storage tank; several instances of reduced inventory / mid-loop operations; replacement of ICW/CCW LOOP logic (HFA latching relays) with pull-to-lock switches; removal (collection) of Rx vessel neutron flux dosimetry; modification of EDG skids to allow access underneath; inspection of ECCS sump area; replacement of a main transformer; modification of containment spray NaOH addition piping; and mechanical, electrical, and I&C systems maintenance.
The next Unit I refueling outage is scheduled for April 29, 1996._
Unit 2's last refueling outage began on October 9,1995, and ended, j
January 1, 1996. Major outage activities included:
refueling; steam
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generator tube. inspection and plugging; low pressure turbine blade replacement; emergency diesel generator inspection; replacement of three 1
11' reactor coolant pump mechanical seals; and mechanical, electrical, and I&C systems maintenance. The next Unit 2 refueling outage is scheduled for April 15, 1997.
PLANT PERSPECTIVE PART 2
2.1 GENERAL PLANT PERSPECTIVE A SALP board meeting was conducted on January 18, 1996, covering the SALP period of January 2,1994, through January 6,1996.
The facility was rated category 1 in the areas of Plant Support and Engineering and 2 in the areas of Operations and Mainenance and Surveillance. The latter scores were a decline from the previous SALP cycle, when the facility was rated category 1 in all areas.
2.2 SALP HISTORY (Past 2 SALP Periods)
The last SALP period, SALP Cycle 11, ended on January 6,1996. The current SALP period ends (tentatively) in June, 1997.
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ASSMT.
OPS RAD MNT/SURV.EP SEC ENG/TECil SAQV PERIOD j
5/1/89 -
1 1
2 1
1 1
1 10/31/90 11/1/90 -
1 1
1 1
1 1
1 5/2/92 PLANT OPS MAINTENANCE ENGINEERING PLANT SUPPORT 5/3/93 -
1 1
1 1
1/1/94 1/2/94 2
2 1
1 1/6/96 2.3 SELECTED SALP AREA DISCUSSION Since July 1995, there has been a series of events that led to questioning the plants overall performance.
These have included:
A Unit I turbine trip due to procedural weakness, operator performance and supervisory oversight.
The attempt to restage an RCP seal using inadequate and inappropriate procedural guidance.
The evolution was compounded by failing to follow aspects of the guidence that did exist, which led to the failure of the second and third stage seals.
4
12 A main steam isolation signal due to an operator failing to block the MSIS signal during a cooldown when an annunciator indicated that the block was enabled. This failure occurred dispite the fact that that the operator's attention was directed to the annunciator on at least two different occassions.
Both pressurizer power operated relief valves being found inoperable due to incorrect assembly during a refueling outage.
The conditions had existed for approximately 10 months.
An loss of RCS inventory due to a shutdown cooling relief valve which lifted and.then failed to reseat due to incorrect setpoint margins (a generic problem involving several valves). The licensee had sufficient evidence that this generic condition existed, but had failed to act promptly to evaluate the con,ditions.
The spraydown of cantainment due to an inadequate procedure and operator error coupled with an existing operator-work-around.
These and several other recent deficiencies involving weak procedures, a general lack of procedural compliance, equipment failures, and personnel errors clearly indicated that the plant's past high level of performance had declined.
These and other problems led to several plant management changes, an overall evaluation of the recent plant problems by a plant-requested independent assessment team, and a root cause evaluation by the NRC.
In a meeting with the NRC on August 29, 1995, the licensee comitted to use the results of the independent assessment team to develop an action plan for improvement.
Plant Ooerations Sumary of Previous Assessment The previous SALP assessment concluded that Operations remained strong, that management actions were aggressive in dealing with identified weaknesses, and that attention to detail was a continuing challenge for the licensee.
Sumary of the Most Recent SALP The board concluded that licensee performance had declined in the most recent SALP period. The board found that day-to-day activities were conducted with a degree of complacency.
Corrective actions, management involvement and comunication of expectations, attention to detail, procedural adequacy and adherence, and operator workarounds were similarly considered to be challenges to licensee performance.
' Maintenance / Surveillance Summary of Previous' Assessment Maintenance was assessed as category 1 in the previous SALP.
Assessments made early in-the most recent cycle. indicated that the performance level of maintenance activities had not abated.
I Summary of the Most Recent SALP l
The board concluded that performance in this functional area had declined. Areas of concern included the existance of long-
{
standing equipment problems and a sense that management expectations.were either low or not adequately enforced. Of
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particular concern was the fact that equipment failure factored into 6 unit trips during the SALP cycle. Additionally, worker adherence to procedures, and the quality and adequacy of procedures was found to be a challenge to performance.
1 Enaineerino Summary of Previous Assessment l
The previous assessments for this SALP cycle concluded that engineering was generally strong.
Good support of the plant was cited, as was the quality of engineering products, both i
to the site and in submittals to the NRC.
J Summary of the Most Recent SALP j
The board concluded that Engineering continued to perform at a superior level.
Continued support to the plant, as well i
as adequacy in safety and operational evaluations were identified.
In. addition, the licensee
- s activities at the 3
engineering materials laboratory and in the developement of maintenance specifications were seen as strengths.
SIGNIFICANT EVENTS
-PART 3
3.1 SIGNIFICANT EVENTS BRIEFINGS (past 12 Months) 1 Unit 1:
95-08, 3/22/95, Failures of Rosemount Transmitters due to Gas Permeation of Monel Diaphragms
]
Unit 2:
None I
3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months)
SL III Violation ($50,000 CP) for violations. associated with 3
inoperable Unit 1 PORVs 1
5 o
6 14 Predecisional Enforcement Conference held, SL IV violation issued for failure to take prompt corrective action for issues relating to relief valve lift and blowdown setpoint values which resulted in a loss of Unit 1 RCS inventory while on shutdown cooling.
S T A F.F I N G AND TRAINING PART 4
4.1 OPERATIONS STAFF - OVERALL (9/95)
Average performance of the operations staff has been'noted.
Control room demeanor of personnel is above average.
Number of Shifts:
(RCO, SRO) Five shift rotation, 8-hour shifts; (NPO, ANPO, SNPO) Five shift rotation, 8-hour shifts.
Number of SR0s:
38 active /13 inactive / 51 total Number of R0s:
23 active /1 inactive / 24 total Total Lice ~nsed Operators:
61 active /14 inactive / 75 total 4.2 FORK FORCE (2/96)
Plant personnel (including 787 disciplines below)
Breakdown by Maior Oraanization FPL Contractors Operations 128 0
Chemistry 20 0
Health Physics 73 0
Maintenance 311 60 Outage Management 21 0
Nuclear Material Management 36 0
Site Engineering"
'50 0
Juno Engineering Security 9
120 QA/QC 37 0
- Includes Reactor Engineers, System Engineers, and Test Engineers 4.3 OPERATOR OVALIFICATION/RE0VALIFICATION PROGRAM (Past Two Years) 4.3.1 REQUALIFICATION PROGRAM Last Inspection - 9/26/94, Inspection Report 50-335,389/94-19 Next Inspection - 10/96 4.3.2 INITIAL EXAMS a
4 4
0
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'4 Last Exams 10/17/94 -
2 R0 2 passed for 100%
9 SRO 9 passed for 100%
Next Exam 3/25/96 -
6 R0 4.4-
-PLANT SIMULATOR The simulator is on site and fully certified to meet ANSI /ANS 3.5, 1985.
i
' 4.5 INP0 ACCREDITATION l
All training programs are maintaining INPO accreditation. The site specific simulator has been used for training since 1988 and has been fully certified for approximately 5 years.
NRC inspections in the form i
of operator examinations at the simulator have found no serious probl ems.
P'A R T 5
INSPECTION
. ACTIVITIES 5.1 INSPECTION FOLLOWUP OPEN ITEMS
SUMMARY
(UNITS 1 AND 2 COMBINED)
(10/6/94)
Pre Division '
Change from Division
_21 1921 M
Last Report DRP -
4 34 18 l
__DRli 1Q 4
14 Total 14 37 51 Note:
Each item that. applies to both units is counted as one item.
5.2 MAJOR INSPECTIONS IR-No.
Qg.tg h
89-02 1/89 RG-1.97 89-03 3/89 NDE 89-07 3/89 EQ 89-09 3/89 Design Control 89-24 10/89 Maintenance Team Inspection 27 11/89 E0P Followup 90-09 4-5/90 OSTI
, 03 2-3/91 EDSFI 91-18 9/91 MOV (no negative findings)91-201 9-10/91 Service Water Inspection 92-14 7/92 Emergency Preparedness Program 92 7/92 EDSFI Followup' 93-01 1/93 Check Valves 94 ^
5/94 MOV Followup 95-05 6/95 Engineering 4
4 v---e
n.
d~
16 95-16 9/95 PORV Special Inspection 96-01 1/96 Dilution. Event Spectial Inspection 5.3 PLANNED TEAM' INSPECTIONS None 5.4 INFREQUENT INSPECTION PROCECURE STATUS No core inspection procedures are overdue at this time.
5.5 SIMS STATUS - OPEN TMI ITEMS There are no open TNI, items.
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ST. LUt E UNIT 1
Operational Period September ~1995 through June 13, 1996 100-On November 19,199;5, 8O-a manual reactor trip was Z
End of ou.tage followinc April 29' 1996' N
initiated to perform MFW iB:
Hurricane En.n shutdown Tor maintenance.
60-refueling a
On February 24,1996,
~
E-Z a manual trip was initiated N
40-g w lile going to a TS required
{
sht tdown O
mmm=
> i i i i i i i i i i i i: :i i i i i i i i i i i i i i i i i i i i i i i i i i i ii i i
- i i i i i i i i i i i i i i i i i i i i =nmmmtm S
O N
D J
-F M
A M
J PERIOD OF OPERATION Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
u.
ST. LU
.E UNIT 2
Operational Period September 1995 through June 13, 1996 100 g
=.
=
g x
On October 9,1995, the 80-unit was shut down for-On April 20,1996 N
sched'uled refueling outag e.
Ei:
the unit was removed o
6 0 --
from service during 4
turbine testing H
On Jar uary 5,1996, the z.
O April 2,1996, power 40-unit was manually tripped was reduced to allow g
due to ligh generator
~T circ water system pipe hydrog en gas temperature.
repairs 20-On June 6, 1996, the' unit was manually tripped due to hich aenerator hydrogerrgas temperattre.
O iiiiiii=vve m m m t m m t m m tvi=iiiu iiiiiiiio iiiiiiiiiiiiiiiiii: :iiiiiiiiiiiii= m S
O N
D J
F M
A M
J PERIOD OF OPERATION Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
f bbub,$
i j.
i' FLORIDA POWER AND LIGHT COMPANY i
ST. LUCIE PLANT l
i i
l l
IMPROVE MENT 1
STATUS-4 SUKMARY i
I US:SRC REGIONIIMEETING l
1 ATLANTA, GA i
J FEBRUARY 8,1996 1
i
OPERATIONAL IMPROVEME:ST ACTIVITIES l
RESOLUTION OF LO:SG-STANDING PROBLEMS ELIMINATED 43 OPERATOR WORKAROUNDS, IMPLEMENIED DAILY DARK BOARD EXPECTATION FOR ANNUNCIA1DRS MODIFIED CONTAINMENT SPRAY VALVES REPLACED EXCORE NUGEAR INSTRUMENTA110N SYSTEM -
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EQUIPME:ST PERFORMANCE REDUCED 'IEE CORRECI1VE MAINTENANCE BACKLOG BY 400 PLANT WORK ORDERS REDUCED THE NUMBER OF ACITVE IEAKS FROM 120 TO 40
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REDUCED 1HE NUMBER OF 1EMPORARY SYSTEM ALTERATIONS FROM 43 TO 15 fiGkrk-TRANED ENGMEERS M ROOT CAUSE ANALYSIS PERSOKSEL PERFORMANCE IMPIEMENTED OPERATIONS SELF ERROR IDENTIFICATION SYSTEM M
tOwEREo TnE m uOUSE EvENr mRESaOto d4ggee CATED REINFORCED REQUIREMENTS FOR PERSONAL ACCOUNTABILTIY TO j
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PROCEDUREIMPROVEMENT UPGRADD4GOPERADONS PROCEDURES UPGRADING MADTTENANCE PROCEDURES,
STRENGINENED AND UPGRADED DIE FACIIIIY REVIEW GROUP PROCESS-FM IMPLEMENIED MORE RIGOROUS TEMPORARY SYS1EM ALTERATION PROCESS STRENGTHENED 1NE REVIEWPROCESSFORFIRST-TIME-USEPROCEDURES I
ASSESS /TRESD PLAST EVENTS CREATED A QUARTERLY STAR 1 REND REPORT -
IMPROVED DIE INFORMATION RECORDED WITHIN 111E OPERATOR LOGS IMPLEMENIED THE USE OF COMPUIERIZED LOGS 4
TRAS'SITION FROM THE IMPROVEEST PLAN TO MANAGEMESTIXDICATORS 3
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. PERIODIC INSTRUMENT SENSING LINE MAINIENANG l
UNIT 1 BORON OVER-DILIJr!ON A REACITVITY MANIPULATION WAS INITIATED AND LEFT UNATIENDED SLOW RESPONSE BY PLANT STAFF POR RECOGNITION OF EVENT SIGNIFICANG.-
BARRIERS REVIEWED PERSONNEL SUPERVISION AND MANAGEMENT PROCEDURES / DOCUMENTS / POLICIES TRAINING & QUALTIY ASSURANG 4
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PROVIDING OtTTSIDE TRAINING 1'
CONTINUED USE OF INDUSTRY SPECIALISTS FOR ASSESSMENT AND AUDITS
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t PERSONNEL PERFORMANCE DEVELOPING TRENDINDICATORS EXPECTATIONS VERSUS PERFORMANCE f
IMPLEMENTINO FOCUSED OBSERVATIONS RY MANAGEMENT i
i CONTENT OF PROCEDURES INCREASING LEVEL OF DETAIL IN PROCEDURES IMPROVING TIMELINESS OF PROCEDURE UPGRADES IMPLEMENT MAINTENANCE RULE i
IDENTIFYING AND MONITORING SYSTEMS IN CATEGORY A1 IMPLEMENTING CORRECTIVE ACTION TO TRANSITION FROM CATEGORY A1 TO CATEGORY A2 l
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i To:
Kerry D.
Landis, Chief, Reactor Projects Branch 3 From:
Mark S. Miller, Resident Inspector
Subject:
St. Lucie Unit 2 Reduced Inventory Operationc i
on November 28, Unit 2 will enter a reduced RCS inventory conditiron to support 2A2 RCP seal work.
The following items were verified prior to this evolutions Containment Closure Capability - Instructions were issued to accomplish this; men and tools were on station.
The inspector verified that the penetration log properly indicated ' actions necessary to close the three logged penetrations which were required to establish containment integrity.
RCS Temperature Indication - The inspector verified that two normal mode 1 CETs were available for indication.
RCS Level Indication - The inspector verified that independent RCS wide and narrow range level instruments, which indicate in the control room, were operable.
An additional Tygon tube loop level in the containment was to be manned during level changes and was displayed via closed circuit television in the control room.
The inspector verified that the tygon tube'was free of obvious kinks and properly supported. The inspector noted, however, that the tube was routed directly over the B. hydrogen recombiner.
At the time, the A recombiner was operating under j
a surveillance test.
Operation of the recombiners results in high amount of heat rising from the units.
The inspector notified the, control room, cautioning operators not to operate the B recombiner without rerouting the tygon level indicator.
RCS Level Perturbations - When RCS level was altered, additional operational controls were invoked.
Procedural restrictions required operators to te,rminate maintenance activities that could affect RCS level, shutdown cooling, or related instrumentation and controls.
i RCS Inventory Volume Addition Capability - The inspector verified'that.one (of three) charging pumps and a HPSI pump were available for RCS addition.
RCS Nozzle Dams - Nozzle dams were not installed at the time.
Vital Electrical Bus Availability - Operations would not release busses or alternate power sources for work during reduced inventory conditions.
The 1A EDG was considered operable and the IB EDG was constdered available and was, in fact running loaded, as the licensee was performing the TS-required 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> surveillance run, performed each refueling on each EDG.
Governing procedures prohibited switchyard work during reduced inventory conditions and signs were posted to that affect at the switchyard.
Pressurizer Vent Path - The manway atop the pressurizer was removed to provide a vent path, and a vented FME device was attached.
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The inspector reviewed AP 0010145, revision 7,
" Shutdown Cooling Controls," and'OP 2-160023, revision 38, " Refueling Sequencing Guidelines" and found that initial conditions either were satisfied at the time of the review or could be satisfied by the time inventory reduction commenced.
The inspector noted that Appendix B, j
Check Sheet 1,. "Surveillances Performed During Reduced Inventoryr" l
contained a verification, in step 1.E, to verify that 1 SG with a level of at least 10% narrow range was available when nozzle dams were removed.
The step was apparently meant to ensure the possibility of natural circulation in the event of a loss of shutdown cooling; however, it had been established previously that RCS integrity and pressurization was required to ensure natural circulation. As one requirement.for reducing inventory was to vent the pressurizer, this step appeared superfluous. The inspector questioned operators as to the applicability of the subject step and found operators knowledgeable on the issue, stating that they realized that the step was meaningless and stating that it was a holdover from previous revisions.
The NPS stated that the procedure would be revised to remove the subject surveillance.
Overall, the inspector found operator knowledge of the upcoming evolution to be l
good.
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