ML20135A639
| ML20135A639 | |
| Person / Time | |
|---|---|
| Site: | Salem, Hope Creek  |
| Issue date: | 11/20/1996 |
| From: | Taylor J NRC OFFICE OF THE EXECUTIVE DIRECTOR FOR OPERATIONS (EDO) |
| To: | NRC |
| Shared Package | |
| ML20135A581 | List: |
| References | |
| FOIA-96-351 NUDOCS 9612030329 | |
| Download: ML20135A639 (105) | |
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UNITED STATES
-l NUCLEAR REGULATORY COMMISSION Q".s, j/
WASHINGTON. D C. 20555-0001
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i MEMORANDUM FOR:
RECORD FROM:
James M. Taylor Executive Director for Operations
SUBJECT:
DROP-IN VISIT -- PUBLIC SERVICE ELECTRIC AND j
GAS COMPANY (PSE&G)
On June 2, 1994, at 1 p.m.,
PSE&G representatives Mr. Steven Miltenberger, VP and Chief Nuclear. Officer, Mr. Joseph Hagan, VP
- Nuclear Operations and Acting General Manager - Salem i
Operations, Mr. Stanley LaBruna, VP - Nuclear Engineering, and Mr. Robert Dougherty, Jr.,
Senior VP - Electric Business Unit, met with Mr.
J.
Taylor, Mr.
J.
Milhoan, Mr.
W.
Russell (NRR), Mr.
L.
Reyes (NRR), Mr.
L.
Chandler (OGC), and Mr.
W. Dean (OEDO) to l
discuss items of mutual interest.
The following topics were discussed-Hope Creek Station & Salem Generating Station Performance 4/7/94 Salem Unit 1 Event PSE&G's Performance Improvement Plan Unitization Plans for Salem Mr. Miltenberger and Mr. Hagan discussed recent performance at l
both PSE&G sites, with the focus being on the continued poor performance at Salem.
They provided a briefing package which indicated areas (e.g.,
LERs, maintenance backlog, overdue l
preventive maintenance) in which the station continually improved i
over the last 4 years.
j The licensee's Comprehensive Performance Assessment Team's (CPAT), which was conducted last year in light of continuing i
performance problems at Salem, was discussed.
They identified 15 problem statements and prioritized them, with supervisory practices, work practices, and dealing with risk correctly as key areas requiring improvement.
Their action plan has recently been incorporated into their overall business plan, which they stated i
will continue to evolve.
A CPAT status book was provided which was a detailed plan and schedule for implementing corrective i
actions.
Actions have been initiated to unitize the two Salem units.
It is hoped this will be successful in dealing with the challenges they face in operations, maintenance, station planning, and outage planning.
They are increasing staff size by over 100 during the next year or so, and are rebidding supervisor and o
j
.c' 9612030329 961120 PDR FOIA 0'NE[LL96-351, PDR
t l l manager positions to get the appropriate people in the right jobs.
Mr. Hagan noted that their managers have not been as i
proactive in getting out into the field as they would like, and that this expectation has been strongly conveyed in the past few months.
It was noted by the EDO that it is up to PSE&G to improve performance, and that it can only be achieved if they go after it in a dedicated and determined fashion.
Mr. Miltenberger stated that they are committed to continually improve and to do a better job of self-assessment.
The meeting adjourned at 2:20 p.m..
No regulatory decisions were requested nor made,
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/ pmes M/ Taylor
' Executive Director b /
for Operations
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OVERVIEW OF NUCLEAR OPERATIONS AUGUST 26,1996
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The Power of Commitment OVERVIEW OF NUCLEAR OPERATION
? PSEG suvuiRv l
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1 PSE&G is committing the necessary resources to address o
long-standing performance problems o New Leadership is driving fundamental change in operational performance 4
o Continued safe, reliable operation of Hope Creek is number i
one priority j
o Company will not seek restart of Salem until. units are ready for safe, sustained operation i
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- mg O PSRG To All Members of the Nuclear Business Unit (NBU) Team:
The publication you hold in your hands is our road map for the next five years. This publication i< the NBU '996-2000 Business Plan w hich includes a summary of our newly introduced NBU Incentive Compensation Program for MAST associates (non-represented). The goals of our business plan are directly linked with those in the incentive program and also with the strategic initiatives of our parent company - Public Service Enterprise Group. You will find a description of this linkage in the incentive program summary.
The restan of our Salem Unit 2 and Hope Creek plants along with other activities to stabilize our operating performance is the immediate focus of the business plan. While the Salem Unit I steam generators are a major issue, we must demonstrate we are capable of running Salem Unit 2 and flope Creek reliably and uneventfully for their next fuel cycle. At this time,it would be premature to speculate on the NBU's course of action with Salem Unit I without adequate technical and economic analysis. Therefore, our business plan does not include the planned July 1996 to December 1997 operating cycle for Salem Unit 1.
We must not lose sight of our long-term objective: to be the chosen provider of safe, reliable electricity for our customers. Representing over 40 percent of PSE&G's assers, our performance is a key factor in the success of Public Service Enterprise Group. Future objectives and goals in the business plan for 1997-2000 will prepare the NBU for streamlining the way we do business. In 1998 we will begin the final phase of our improvement efforts to ensure we become a competi-tive producer for the duration of our plant licenses.
You are receiving this plan because NymyNyMbruggy You will make it happen. To reach our NBU vision to " Safely generate competitive electricity with nuclear power" will require the following :
Safe / Reliable Operation
+ Cost Management
- People; Culture and Skills a Stakeholder Relationship Please read the business plan and incentive program summary thoroughly and take note of specific areas w here you can make a contribution. It will take teamwork and determination to make our goals a reality. As the utility industry changes, we must change with it to competitively meet the needs of our customers. The business plan is our road map to excellence and we will reach our destination.
CNO and President - Nuclear Business Unit
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COMPET TIVE PRODUCER i
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We will move toward becoming a competitive producer in three phases:
4 STAB / HIE STREAMUNE C9MBTmVE l
We will improve and STABluZE NBU perfor-We will STREAMUNE the way we do business.
We will become a COMPETITIVE energy mance to insure future sustained highly reliable This phase is expected to begin during 1996 producer through sustained plant performance (overlappin' 'with the stabilization phase) and and continuous improvement in overall manage-operation througii the Salem Restart and Hope g
Creek improvement plans. This phase is ex-continue into early 1998.
ment and operation of the business. This phase pected to run through the start up of Hope Creek will begin during 1998 and run continuously and Salem Unit 2 and into 1997.
through the end of plant life at our Salem and Hope Creek generating units.
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The following chart represents how we expect to position the NBU as a competitive energy producer over the next five years. Although electric production (capac.
ity factor) for Salem Un:t I is not included for 1996 and 1997, our compe itis e goal is to pnxluce low cost electricity through safe, reliable and efficient operation of our nuclear facilities.
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1 SAI.EM ANi HOPE CREEK PROiUCTION COSTS 0&NI PO.US FUEL. C/Kwh 5.0 4.5 i
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i 4.0 3.5 I
,$12D/0E 3.0
[y:4
<.J 2.5 i
STREANUNE 1
2.0 j
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1.5 COMMTITNE l
1.0 I
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I 1995 1996*
199T 1998 1999 2000 3.97 clumn 4.54clumn 2.26 clumn 1.74 clumn 177 cluwn 1.65 clumn i
- 1996 and 1997 include Salem 2 and llope Creek only
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4 NBU BUS NESS PLAN OBJECTIVES
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l The four NBU business plan objectives are.the framework from which we will measure our performance. These objectives are directly liriked to the strategic j
j initiatives of the Public Service Enterprise Group:
1 i
EUBllCJERUICEINHRERISEGR992 NUCLEARBUSINESSUNIT l
STRRTERICJN/TIRTNES BUSINESSUNilGRIECINES Generation Strategy Safe / Reliable Operations Cost Management Cost Management lluman Resource Redesign People; Culture aird Skills i
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Regulatory, Public Policy Leadership Stakeholder Relationship l
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Critical success factors have been established for each business plan ~ objective. Critical success factors are those areas of performance that contribute to each l
business plan objectives. Critical success factor goals have also been established for the period 1996-2(X)0 is a means of measuring our performance and p The 1996 focus of the business plan is to return flope Creek and Salem Unit 2 to service complete the analysis and recommend a course of action to deal with the Salem Unit i steam generators, and the development of action plans for streamlining the NBU operation.
A competitise market analysis was performed to benchmark current NBU performance and future goals against the future market. The results of this analysis are incorporated in the business plan objectives and were used in the establishment of critical success factor goals.
1
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5 v.-
NBU BUS NESS Pl.AN OBJECTIVES i
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1 Safe /REHARLEONRAURN A key element to immediate improvement in safety standards is human performance. Nuclear safety comes first; it is the foundation of everything we do. A safety consciousness must be maintained. " Safety First" means conservative decision making in a nuclear plant. Procedures must be adhered to and safety issues raised w hen they are experienced or observed. Employees must effective'y demonstrate those supervisory, leadership and technical skills that consistently achieve high
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safety performance through aggressive, timely and effective self-assessment, root cause determination and corrective actions.
l I
Our competitive market analysis indicates that safe plants are also those that are reliable and low cost producers. Top performing nuclear plants operate at capacity j
factors above 80% with top quartile safety performance measured by the INPO Performance Index.
I Our objective is to establish ongoing levels of safety confidence and credibility through the successful implementation of the Salem Restart Plan and llope Creek Improvement Plan.
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i CRITICAL SUCCESS FACTORS AND GOALS t
SAFE /REllABLESPERM10N Critical Success Factors Critical Success Factor Goals INPO Perform <mce Index ($)
i l
A weighted index prepared by INPO based on the ten lydf[ic
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1996 1997 1998 1999 2000 industry indicators: capability factor; unplanned ca-
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7 pability loss factor; unplanned automatic scrams;
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, -76l. ' 'i85' 86 i
safety system performance; thermal performance; fuel
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'81
' 8/ '" 90 90 reliability; chemistry indicator; collective radiation hg@;
- i.;g?gg'd 3
- m exposure; low level radioactive waste generated; and g>
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mdustrial safety accident rate.
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'me IU Iinined Automatici
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p rg 6c gey,,g4:p'm cScrams (number per um,t)f,4 -
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Unphmned Automatic Scrams 9;.% m.E
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The scram (automatic shutdown) rate for approx _-i mately one year (7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />) of operation.
S
$ystem Perforidaikelsdiesi@ 0.015 ' O.015 70.0157 10.015 0.015
[(r'aikpejrplant) _
%ggHCy 0.018, 0.018 0.015. 0.015. 0.015
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X sakty surem Performance
'y5,j,, y,;,3,,g, The availability of three important safety systems at each plant. (BWR - high pressure injection, residual heat removal, emergency AC power system. PWR -
high pressure safety injection system, auxiliary l
feedwater system, emergency AC power system).
i (S) Denotes 1996 NBU Incentive Plan Goal 7
l CRITICAL SUCCESS FACTORS ANI GOALS i
Mff/RElstBLERMMTI9N l
Critical Success Factors Critical Success Factor Goals l
Fuel Reliability The monitoring of the progress in preventing defects in the metal cladding thatjurrounds the fuel.
laag 1997 1998 1999 2000 Fuel Reliability (pc/gm)
Salem
.0004*
.0004*.0004
.0004
.0004 1
Collective RadiatidtrEsposure
( c/sec)
.HC 200 200 200 200 200 The monitoring of ethe effectiveness of personnel ra-diation exposure controls for PWRs and BWRs. The Collective Radiation Salem 130*
5*
105 245 98 4
sum of internal and external dose, Total Effective Dose jposure (rem)
..,H C, 152 310 230 62 226 Equivalent (TEDE), received hy bil personnel, includ-
[o ing contractors and visitor 3e
[,[.Q
! Industrial Safety O.40 0.30 030 0.30 0.30
~ ' '
AEldent (rate per plant)
IndustrialSafety Accident Rate ($)
The number of accidents that result in lost work time,
< $jd &
I Cn restricted work or fatalities per 200,000 work-hours.
)
[g'jj kRestart Plan Overall :
,100%
- N/A
-N/A-N/A N/A
[3dedule Performance i
Salem Restart Plan OverallSchedule Performance Adherence to planned work activity schedule on a
"
- Sa'lem Unit 2 only monthly basis against the Salem Restart Plan schedule.
l$) Denotes 1996 NBU Incentive Plan Goal i
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CRIT CAL SUCCESS FACTORS AND GOALS i
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SAFE /RElldBLEBEERAH9N Critical Success Factor Goals l
Critical Success Factors i
Hope Creek impivvement Plan Overall Schedule l 1996 1997 1998 1999 2000 i
Per/armance l
Adherence to planned work activity schedule on a 100 %
N/A N/A N/A N/A nmnthly basis against the lii>pe Creek Improvement -
llope Creek Improvement i
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Plan Overall Schedule Performance ;
I Capability Factor ($)
The percentage of maximum energy generation that a Capability Factor Salem 20*
96*
79 71 77 l
plant is capable of supplying to the electrical grid, (perceiitage)
HC' 72 80 86 96 85 limited only by factors within the control of plant
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management. For planning purposes, although not
- Salem Unit 2 only technically supported, Salem I capacity factor for years 1998 through 2000 has been limited to 75% in a non-outage year..
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(5) Denotes 1996 NBU Incentive Plan Goal l
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NBU BUS NESS Pl.AN OBJECTIVES 4
l SALEMUNIT1STIAMGENERATORS 1
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On February 23,1996 the restart of Salem Unit I was delayed for an indefinite period while the condition of the unit's four steam generators is being assessed. The delay in Unit l's restan sterns from the results ofinspections which revealed indications of microscopic cracks in a number of steam generator tubes.
At this time, the analysis is far from completed and it would be premature to speculate on a course of action. Ultimately, there are several options, including but not
]
limited to repairing, replacing the steam generators or retiring'the unit, or some other, yet-to-be. determined option.
k Our 1996-2000 Business Plan does not include the next planned operating cycle for Salem Unit 1. This operating cycle was expected to run from June of 1996 to December 1997. Therefore, the goals contained in the plan do not include Salem Unit I for 1996 and 1997. Specific Salem Unit I goals have been established for that
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period and are identified on the following page.
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I CRIT CAL SUCCESS FACTORS AND GOALS 1
1 SMEAfUNIT160RIS Critical Success Factors Critical Success Factor Goals INPO Performance Index
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A weighted index prepared by INPO based on the ten industry indicators: capability 1996 1997
- c pyj;f T
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factor; unplanned capability to'ss factor; unplanned automatic scrams; safety system per-y,
- .g i
formance; thermal performance; fuel reliability; chemistry indicator; collective radia-g gg y
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tion exposure; low level radioactive waste generated; and iridustrial safety accident rate.
qq-m ; 7 f p y,
.;e, 3.g g;Mrmg $9wifSistenEQ;&m th
%Cng/w 0.015 ; 0 015 Emergency AC Power Supply System (5) dbhi$esidihor~ProjectF p v;&
iM%d5 W M N N'E The availability of the emergency AC power system (diesel generators) at Salem Unit 1.
i T Std~a m G 100 %
100 %
.. w...
Steam Generator Pmject Performance
'Periormance&
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Adherence to established milestones in the Steam Generator Project schedule.
.,..g u.
- Unit 1 Pldn' Lay Up Plan 100 %
100 %
t Unir i Plant lay Up Plan Performance Performanhe l
Plan development and milestone performance to protect our current investment and mini-mize the deterioration of equipment and systems while the unit is _out of service.
. Collective Radiation Exposure (rem) 78 100 Collective Radiaticn Exposure ($)
=
1 Industrial Safety Accident Rate 0.40,
0.40 The monitoring of the effectiveness of personnel radiation exposure control for PWR.s and BWR's. The Effective Dose Equivalent (TEDE), received by all personnel, includ-ing contractors and visitors.
I IndustrialSafety Accident Rate (5)
Additional Performance Indicators Under Development The number of accidents that result in lost work time, restricted work or fatalities per
)
2(M),000 sork-hours.
Service muer System and Spent Fuel Cooling System Performam e These indicators will measure the availability of these safety systems (S) Denotes 1996 NBU Incentive Plan Goal at Salem. Unit 1.
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1 NBU BUSINESS PLAN OBJECTIVES i4 1
l COSTMANRGEMENI :
1 In order to be competitive, we must improve our operations and megawatt production w hile anchoring a cost management culture wit
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on reducing our O&M Capital and Fuel expenditures. Fundamental to this culture is a focus on minimizing future capital investment. We l
where possibie, our PSE&G resources and continue to rely less on contractor seriices.
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Our competitive market analysis indicates that PSE&G'y position is somewhat below that of the regional utilities w hich operate j
of the country. In 1994, PSE&G's average residential' rate was 11.22 c/Kwh versus the industry average of about 8.85 cents.1;ikewise. P mercial rate and 7.51-cent industrial rate were abou't 19% and 53% higher than the industry averages, respectively. Regionally, the 3
1 although still significant. The average residential, commercial, and industrial rates for the Pennsylvania-New" Jersey-Maryland 1994 were about 9.8 cents,8.5 cents, and6.25 cents respectively. PSE&G's rates reflect, in part, high' fixed costs, which in 199 1
and 58% greater than the regional average, in large measure the result of the high sunk costs of the Hope Creek nuclear pla the company's competitive positio'. New Jersey imposes a gross receipts franchise tax of 13% on every dollar of revenue that is gen n
Poors - Utility Credit Report : Public Service Electric & Gas Co..- Anghst i995).
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Our cost management objective will require an increasing level of'tearnwork and individual commitment if we are to achieve performance and cost goals than in the past. We must challenge ourselves with resulting production cost performance as the measure of r success.
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CRIT CAL SUCCESS FACTORS ANi 00ALS i
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i COSTMANRREMENT i
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Critical Success Goals CriticalSuccess Factor Goals htal O& M Espenditures ($)
Operating and Maintenance expenditures including
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'1996 1997 1998 1999 2000 i
labor, material, contractor and'other costs.
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'O[s xpenditures ($M) 324 258 265' 265 246 I
of fuel burned represented in c/Kwh.
UI wh) 0.62 0.61 0.54-0.54.
0.53 i
da@ pit $iExpenditures ($M)
_..{135
'i 87 55 58 45 Capital Expenditures ($)
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Total dollars spent on capital replacements and new Proddction Cost (c/Kwh) 4.54 2.26
> 1.74:
1.77 1.65 j
capital equipment including capital modifications.
l NBU Staffing Level (year.end) 2300 2240 2060 1880 1800 i
l l'rvduction Cmt t$)
i Includes O&M and fuel cost for a time period, divided by net energy produced during the period for Salem 1, i
Salem 2 and Hope Creek. Expressed in terms of e/Kwh.
NilU Statling Level (5)
Total approved N B U staffing leyel. PSE&G personnel only.
($) Denotes 1996 NBU Incentive Plan Goal 1
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CR TICAL SUCCESS FACTORS AND GOALS i
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PE0ffECULTUREMR_ Skills '
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Critical Success Factors Critical Success Factor Goals Cuhure Surrey j
A survey that measures how well the NBU is living up K-1996 1997 1998 1999 2000 to our vision. mission and values. (FPI - safety culture V 'u index)
Culture Survey ea 12 i 13
>14
>14
>14 1
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> Emlployee Concerns Issues'A~ab q
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,;.p Employee Concerns h5ues Resolution 30 l
-30 30 30 30 The time required to resolve employee issues reported REsdistion (days)
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through the Empidyee Concerns program, measured in j
the number of days.
jeNdrmance Ranking (percent).,
cagp
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100 N/A N/A N/A N/A Performance Ranking ($)
l A process to validate the performance evaluation of NBU employees. The process is a key element to improve the reliability at Salem and flope Creek and to effect a step -
l change improvement in the entire NBU organization.
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(3) Denotes 1996 NBU Incentive Plan Goal i
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18 l
1 1
l NBU BUSINESS Pl.AN OBJECTIVES i
.i STAKENotDERJELBRNSMit 4
The relationship the NBU develops and maintains with intemal and external stakeholders will affect the business environment as compe to engage the entire work force, our internal stakeholders, is essential. Only then will we achieve the required efficiency gains and competitive p j
NBU. This will be done thiough a combination ofinternal communication initiatises, increased employee involvement in business matters and thos detailed in the People; Ctrlture and Skills section of this plan.
I i
Our competitive market analysis indicates that external'stakeholders, especially those in the financial community, are sensitive to the
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nuclear assets. The lo'ng range success of the Public Service Enterprise Group will be largely dependent on the performance and utilization ofits nu j
the level of confidence that is maintained wi,th our stakeholders.
l f
Our stakeholders include regulators, industry groups, the media, state and local neighbors and the ultimate customer. The relationship w stakeholders will reflect the confidence we promote through the quality of our plant operations, communications and commitment complianc a more proactive role in edsuring that external stakeholders are'provided with timely and accurate information for ongoing initiatives, as well as e i
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i CRITICAL SUCCESS FACTORS AND 00ALS l
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STAMEN 0lDERREUR0NSHIE I
Critical Success Factors Critical Success Factor Goals INPO Significcmt Events IS) j Events identified as significant by INPO at Salem I, 1996 1997 1998 1999 2000 Salem 2 and Hope Creek cause'd by human error.
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. INP,0 Significant Events 0
0 0
0 0
1 Commitment Compliance A measure of the ability of the NBU to meet regula-futinitinent Cornpliance (percent).,
100 100
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-100 100 i
tory commitments.
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.. NRCViolations(level 4) 15 12
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NRC Molations Violations received from the NRC (Total NBU).
Level I violations are the most significant and level 4 are the least significant. (Level I through 3 target is zero,les el 4 targets listed)
(S) Denotes 1996 NBU Incentive Plan Goal 17
l 4
l AiDIT ONAL PERFORMANCE INiICA~ TORS i
l l
Additional performance indicators are currently under development. After they are fully developed and we have both ba'selined and trended the data for these l
j indicators, we will consider adding them to our critical success factors in the 1997-200.1 l
definitions are p,rovided for your information.
' NBU Business Plan. These additional performance indicators and their
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j l
PINERNMARCEJMMMEMENTJNDR A weighted index.to measure human performance that would inclulle the percentage of performance ranking improvements, employee availability rate, training a days of event free operation.
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LEADERSHIESONE An indicator focusdd on a specific section of the culture survey that would measure how well NBU managers and supervisors are perceived to be living up to the l
NBU vision, missimi and core values.
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EMBRYEECNNBDENCEJKCRMMUNICAT10NS11NV0lVEMENT i
An indicator to measure the, effectiveness of employee confidence ip communications and involvement as measured through survey and interviews.
EMUIR0NMENTMINNH A weighted index that measures the effectiveness of our environmental' compliance with New Jersey Permit Discharge Elimination Syst (NJPD$S), the provi-sions of the Clean Air Act. and the Discharge Containment and Countermeasure / Discharge Cleanup and Removal Plan.
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IMMEMENTNTIONDE1NHRNAL/ATENNMCBMMUNICATIONSBANS An indicator that measures our adherence to established schedules for the implementation of internal and external NBU communi i
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SUMMARY
The 1996-2000 NBU Business Plan provides e focus on those actions and improvements that wid produce long-term sustained performance at our nuclear generating facilities. During 1995, a Salem' Restart Plan and a Hope Creek Improvement Plan were put into place to produce a step change in the performance and long term plant reliability of the Salem n6 clear units, and return Hope Creek to top quartile performance. These improvement plans are focused on the identifica-tion and resolution of equipment probJems, and improvements in programs, process, and human performance.
During 1996 we will:
a return salem Unit 2 and flope Creek to service; 1
- complete the economic and technical analysis of Salem I steam generators; l
I
- update our competitive and market position with Corporate Strategic Planning,
- expand our competitive analysis th'ro'ugirend of plant life; and
- begin the development of our 1996-2000 action plans to prepare for streamlining the way we do business.
These actions will be focused on select critical success factors goals that must be achieved as we stabilize plant performance. These include improvements in human perfonnance and measures to reduce costs.
I While a business plan is a necessary and reliable road map, it alone is not sufficient to ensure success. The u,ltimate tu'ccess of the NBU depends on each individual employees' commitment to perform in a professional manner consistent with our core values. FJfective'co'mmunications and the commitment to the highest stan-dards in otir relations with regulators, stakeholders and fellow employees is essential.. IDWAFFSFAWbr3ACF/
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s v UNKINGPERFORIRANCE l
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ked to the strategic i'nitiatives of Public Se[picegoals of the NBU in I
I terprise Group and the.1996-2000 NBU Bustness l
. These goals focps og' employee actions, results.
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oals. Ihese goals are identified in the 1996 NBU Busi-i ss Plan with a ($). Theyare the same goals used to termine Management Incentive Plan awards for U company officers. 60% of your total award will j
b ed on achieving these goals.
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'lant(Department Component - The third component i
based on the achievement of specific NBU depart-l nt goals. Goals have been developed at the direct f
j rt to SVP and CNO levels. This represents 40%
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.your total award. Details will be provided by your artment head.
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) THE1096.COMPENSATl0N PR00 RAM 4
W vw A number of change have been made to our previous,comhnsation program.
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- fob Evaluation - During 1995, ajob evaluation process was implemented throughout SSE&G that focused on the
. external competitive Edue ofjobs. This is called'" market pricing." NBlf will bfimpleifisiiting" market pricing"
- this year. As this occu'rs, somejob values will ncrease, some wil{ decrease and manywill remain the same. You "should be awaretthalit s Company policy th t {if ajob value decre l
associate's pay will n change.
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1996 Merit Budgets. nother action that w are taking is to reduce our mer rease budge for associates who will become jncent)ve plan participants forpe first time. This is necessary t shift our com nsation opportu-i
. mty to be more gnarket dompetitive and to focus on results achieved.
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- Common Performance hppraisaland Salary increase!Date - All kA N
ill be
- adjusted to.the first paypH53lieginning in April of ekch yeardhis change is bemg implemented acrostPSE&G
' NBU assdciates will receive this increase in May plus any retroactive amo'unts.
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.cqual to or eater than it was 6 the past. Incentives will be aparded ONL[when specific goals are met. Award pnounts will be based on the awa'n f
percentage and job values. The amount of the total incentive award will be. reduced by fines we receive from
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the NRC. Your actual total compensation will tv based on your individual [Erformance and the performanc,e.of.
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, Public Service Enterpris) Group,.NBU and your department.
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O PSRG Nuclear Business Unit
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Leon R. Eliason
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.e /M Leon R. Eliason was named chief nuclear officer E-
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C and president of the Nuclear Business Unit in W
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October 1994. He is responsible for all opemtional
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ating Station and Hope Creek Generating Station.
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7 As CNO and president, Eliason reports to Public
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Service Enterprise Group CEO d. James Ferland.
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Eliason came to PSE&G's Nuclear Business Unit after serving as president-generation for Northem i
States Power (NSP) in Minnesota, where he oversaw l
the opemtion of fossil and nuclear power generating l
plants and related activities. He previously served at NSP as vice president-nuclear generation, j
general manager-nuclear plants, Monticello plant manager and as a radiation protection engineer.
I He has been involved in the nuclear industry for more than 25 years.
l l
Eliason holds a bachelor of science degree in mechanical engineering from the South Dakota School of Mines and Technology, and is a graduate of the University of Minnesota Management Institute.
He is cunently active in the following professional groups:
l
- Association of Edison Electric Illuminating Companies' Power Generation Committee e Institute of Nuclear Power Operations' National Nuclear Accrediting Board He was chairman of the New York Power Authority Advisory Group, and was a member of the following industry organizations:
e Washington Public Power Supply Corporate Safety Review Board e NRG Energy, Inc.
- American Nuclear Society Eliason also served on the Board of Directors of the St. Croix (Minn.) Catholic Consolidated
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l Schools, and is a member of the Stillwater (Minn.) Knights of Columbus and the Metropolitan q
I' Economic Development Board.
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EXECUTIVE SUStaggyy O~
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TAllLE OF CONTENTS EXECUTIVE
SUMMARY
ii 1.1 Event Overview I
1.2 AIT Formation...
I 1.3 AIT Charter 1
2.0 Event Details...................
I 2.I Annunciator System Description I
2.2 Software (internal)
I 2.3 liardware (interface)
I 2.4 Initial Plant Conditions.
2 2.5 General Sequence of Events....
2 2.6 Next Day Past-Event Actions......
2 2.7 Subsequent Licensee Actions 2
l 3.0 Evaluation of Staff Response 2
3.1 Operator Response 2
3.2 Technical Evaluation 2
3.3 Managerial Performance.
3 3.4 Human Performance Issues 3
4.0 Overhead Annunciator System Failures.
4 4
4.1 Modification Review 4.2
}{istorical Problems and Licensee Actions 5
4.3 Failure During Event 5
i iii
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il 4.4 Cause(s)..............
5 4.5 Corrective Actions.........
5 5.0 Overhead Annunciator System Surveillance Testing 6
1 5.1 Routine 6
5.2 Preventive Maintenance 6
4 5.3 Informal Surveillance..
6 i
6.0 Event Classincation and Reporting.
6 4
7.0 Safety Significance 6
8.0 Overall Conclusions 6
8.1 Cause of Fquipment Failures 6
8.2 Staff Response 6
l 9.0 Additional Information.......
7 j
l 1
9.1 Use at other Plants........
7 LIST OF ATTACIIM EKrS...................................... 8 l
i 4
IV i
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_ ~.... - - -.
4 4
1 4
l DETAIIS d
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-1.1 Event' Overview Pelletier t
3 1.2 AIT Fonnation j
On December 14, 1992, senior NRC managers determined that an AIT was warranted to gather information on l
Ruland i
1.3 AIT Charter 2
Ruland i
A charter was formulated for the AIT and transmitted from to on
, (Enclosure
) with copics to appropriate EDO, NRR,'
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AEOD, and RI personnel. The AIT's objectives were to: (1) conduct a timely, thorough, and sy;t:;natic inspection related to the event, (2) assess the safety significance of the event
.and communicate to Regional and IIcadquarters management the facts and safety concerns related to the event such that appi priate followup actions are taken, and (3) collect, analyze, and document factual information and evidence sufficle'nt to determine the cause(s),
conditions, and circumsaces pertaining to the event.
The AIT completed its charter and was terminated on 1992.
2.0 Event Details 2.1 Annunciator System Description 2.2 Software (internal)
Calvert 2.3 Ilardware (interface) -
Ibarra
2 2.3.1 Interface With Other Systeins Ibarra 2.4 Initial Plant Conditions Pelletier 2.5 General Sequence of Events Pelletier 2.6 Next Day Past-Event Actions Cheung
- 2.7 Subsequent Licensee Actions s:heung/Pelletier 2.7.1 Justification for Continued Operation 2.7.2 Fifteen Minute Functional 2.7.3 Call to 11111 Ruland Deceniber 19, 1992 3.0 Evaluation of Staff Response 3.1 Operator Response Spence 3.2 Technical Evaluation Ibarra 1
i 3
3.3 Managerial Perfonnance l
Cheung l
3.3.1 Shift Supervision Spence 3.3.2 Station Management Spence /Cheung 3.4 IIuman Performance Issues Spence 3.4.1 Teamwork and Conununications Spence /Ibarra 3.4.2 Command and Control Spence
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3 /' 'Y 3.4.3 Procedures 7_
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3.4.4 Training Ibarra e 3.4.4J Classroom Training
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s4 Operations - Spence Technical Staff - Ibarra J
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'3.4.4.2 Siinulator Scenario Spence 1
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i 3.4.5 Ilurnan Perforinance Investigation
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3.4.6 Man-Machine Interface
((A Spence l
4.0
. Overhead Annunciator Systein Failures Calvert/lbarra 4.1 Modification Review Calvert/lbarra 4.1.1 Design Calvert/Ibarra/Cheung 4.1.2 Installation Calvert/Ibarra/Cheung i
l 4.1.3 Testing lbarra/Cheung
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4.1.4 Safety Evaluations 4
lbarr.?JCheung i
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1 1
5 4.2 llistorical Probleins and Licensee Actions Pelletier The AIT determined the root cause of the equipment failures as follows:
4.2.1 Salein Unit 2 i
Pelletier t
i 4.2.2 Salern Unit I i
. Pelletier
)
4.2.3 Ilope Creek Pelletier 4.3 Failure During Event Calvert/lbarra 1
4.4 Cause(s)
Calvert/Ibarra 4.5 Corrective Actions 4.5.1 Texas Plan Calvert 4.5.2 Troubleshooting Cheung r
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6
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i 5.0 Overhead Annunciator Systern Surveillance Testing (I&C) i lbarra/Calvert i
5.1 Routine 5.2 Preventive Maintenance 1
5.3 Infonnal Surveillance I
i 6.0 Event Classification and Reporting j
Gordon/ Spence /Ruland i
t j
7.0 Safety SigniGcance Spence /Ibarra l
Everybody provides a paragraph on safety significance 1
f 8.0 Overall Conclusions Ruland 8.1 Cause of Equipinent Failures Calvert/Ibarra 8.2 Staff Response 8.2.1
. Operation Spence
I i
7 8.2.2
'l ulinical Calvert/Ibarra 8.2.3 Ernergency Preparedness Spence /Gordon 8.2.4 Management Ruland i
1 9.0 Additional Information Pelletier l
i 9.1 Use at Other Plants 1
1 1
Pelletier l
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1
M 8
LIST OF A1TACHMENTS Attachment No.
Iille i
Persons Contacted Ruland/Cheung/ Spence /1barra/Calvert/Pelletier/Gordon 2
Acronyms and initialisms R uland/C h eu n g/S pen ce/lba rra/ Cal ve r t / Pel'e tie r/G o rdo n 3
Detailed Sequence of Events Pelletier 4
Block Diagrams liardware/lbarra Software /Calvert 5
6 7
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OTHER INDICATIONS OHA STEP / CONDITION A_g NONE CCW PUMP RUN/ VALVE POSITION AB.CA-0001 D-20,21,22,23 3.1/RCP BRG CLG WTR CC1 BEZEL INDICATIONS AB.CC-0001 FLO LO B-13,14 3.2/ LOW SRVC WTR HDR AUX ALARM PRINTER PRESS C-1 3.48/ CONT SUMP PUMP RUN NONE AB. CHEM-0001 NONE AB.CN-0001 NONE AB.COND-0001 NONE AB. CONT-0001 NONE AB.CR-0001 NONE AB.CR-0002 NONE AB.CR-0003 NONE AB.CW-0001 NONE AB. FUEL-0001 NONE AB. FUEL-0002 NONE AB. GRID-0001 I
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STEP / CONDITION OHA OTHER INDICATIONS AB_
AB. LOOP-0001 3.2/4KV BUS J-17,18,19 LOCAL INDICATION ON BKRS CC3 MIMIC BUS / BEZELS VERIFICATION 3.7/SW AVAILABLE; B-13.14 CC1 BE7EL INDICATIONS HDR PRESS LO 3.15 & 3.20 13KV FAULT K-3,4.11,12,19 LOCAL BKR INDICATIONS K-20 CC3 BEZEL INDICATIONS 500KV BKR FAILURE K-14,22,30,38 SPT PROTECTION H-8,16 4KV BKR FAILURE J-25,26,27,33 J-34,35,41,42 J-43 AB. LOOP-0002 3.1 / 4 K V BUS J-17,18,19 LOCAL INDICATION ON BKRS CC3 MIMIC BUS / BEZELS VERIFICATION 3.11/13KV FAULT K-3,4,11,12,19 CC3 BEZEL INDICATIONS
,20 500KV BKR FAILURE K-14,22,50,38 SPT PROTECTION H-8,16 4KV BKR FAILURE J-25,26,27,33
,34,35,41,42
,43 3.3/PR FAILURE E-7,15,23,31 MONITOR NI RACKS /CC2 BEZELS AB.NIS-0001 39,47,38,46 3.4/SR FAILURE E-5,13 MONITOR NI RACKS /CC2 BEZELS 3.5/lR FAILURE E-6,14,22,30 MONITOR NI RACKS /CC2 BEZELS 3.168/SR TRIP BYPASS E-29 MONITOR N1 RACKS 3.16D/SR HI FLUX @ SD E-21 NO OTHER INDICATION 4
.m.
+
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l i
STEP / CONDITION OHA OTHER INDICATIONS AB AB.PZR-0001 NONE NONE AB. RAD-0001 NONE AB.RC-0001 NONE AB.RC-0002 NONE AB.RC-0004 3.1/RCP CCW LO FLOW D-20,21,22,23 CCW/ VALVE INDICATION AB.RCP-0001 3.14/STOP RCP IF OIL D-12,13,14,15 NO OT:lCn ;NDiCATiGN3 P-1so wmW ~5 LVL LO '
heq h*P r
3.33/RCS LEAKAGE C-26,34 LOCAL AT RHR SUMPS AB.RHR-0001 D-28,30 RVLIS 3.31/RCS LEAKAGE C-26,34 LOCAL AT RHR SUMPS AB.RHR-0002 D-28,30 RVLIS 3.5/ URGENT FAILURE E-40 CC2 URGENT FAILURE ALARM AB. ROD-0001 CLR
- 3. 9,19,3 4 / R O D S E-24 CC2IRPI MISALIGNED > 12 STEPS 3.14/POS CONF ROD E-48 ROD BOTTOM LIGHT /AFD/QPTR AB. ROD-0002 Tayt-Tatr DEV/RX POWER DROP NONE AB. ROD-0003 i
e
.. m m-
AB_
STEP / CONDITION OHA OTHER INDICATIONS AB. ROD 0004 NONE AB.SG-0001 3.23/2R40 IN ALARM G-36 NO ALT INDICATION A-5 RMS/R40 INDICATION AB.STM-0001 3.19/STM LEAK IN CONT.
C-2,30,38 CC1 INDICATIONS / AUX PRINTER AB.SW-OOO1 3.2/ LEAK IN SW BAY B-29,30 CC1(SW HDR PRESS)/ AUX PRINTER 3.4/ LEAK IN TURB BLDG G-43 LOCAL DETECTION B-48 AB.SW-0002 3.16/
M O NIT O R P-250 LOCAL PARAMETERS ON P-250 H-44 LOCAL 3.18/ TAC ALARMS G-24 AB.SW-0003 NONE AB.TL-0001 NONE AB.TRB-0001 3.2/ TURB BRG OIL LO F-8 CC3 BEZEL IND/ ALARMS AB.ZZ-0001 NONE AB.ZZ-0002 NONE AB.4KV-0001 3.16/SW PRESS LO B-13,14,15 CC1 BEZEL / LOCAL INDICATION 3.18/CCW FLOW LO D-21,22,23,24 AB.4KV-0002 3.6C/ATTCH 5
TURB 3.17,18 ( S E E G-24 Lo> cat, TA(.
TRENDS 4KV-0001) y y_
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u-2
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9 8
ep LOCAL TAC TEMPS TSIPANEL STEP / CONDITION OHA OTHER INDICATIONS AB 3_g (S,gr,_ ps yy_,,e,,g}
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SUPPLEMENTARY REQUIREMENTS EOR LOSE QE OHA'S A) CONTROL ROOM:
BOARD OPERATOR - NORMAL COMPLIMENT, CONTROL OF CONSOLE, ASSISTED BY EXTRA NCO.
DESK OPERATOR - NORMAL COMPLIMENT, INITIATE AND OBSERVE TURBINE TREND, NOTE ALL AUX TW ALAPMS AND P-250 ALARMS.
NCO - EXTRA BOARD OBSERVER FOR CHANGING PARAMETERS AND ALARMS, ASSISTS BOARD OPERATOR.
NEO - DEDICATED TO OBSERVING RP4 PANEL, REPORTS ALL CHANGES IN LAMP STATUS TO BOARD NCO.
.., NEO - BACK PANEL AND RACK ROOM OBSERVER.
ROVE AND REPORT ALL INDICATION CHANGES, SPECIFICALLY ON THE FOLLOWING PANELS:
RMS, RCP VIBRATION FLANGE AND SHAFT, CW SCREEN INDICATION, RP6, MIMS, NI'S, SSPS, AND AMSAC.
B) SECONDARY:
DUTY OPERATOR - ROVE SECONDARY
- . NEO - ASSIST DUTY OPERATOR, ROVE AND MONITOR THE FOLLOWING SPECIFIC AREAS:
,JJ J
MPT'S, APT'S, GEN EXCITATION PANELS,
/ d.f d STATOR / SEAL OIL ALARM PANEL, SGFP
.,.->+e u/'
i ALARM PANELS, TAC TEMP / LEVEL, GEN LIQUID DETECTORS.
C) SWITCHYARD: Q] NEO - MONITOR TRANSFORMERS AND LOCAL BREAKER ALARMS PANELS.
D) CIRC WATER:
DUTY OPERATOR - CONTINUOUS ROVE.
E) SERVICE WATER: NEO - MONITOR BAYS, SCREENS, AND CONTROL ROOMS.
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t VERIFICATION QF OHA'S l
1.
EXTRA PERSONNEL WILL BE STATIONED AT THE FOLLOWING AREAS l
TO PROVIDE VERIFICATION OF CORRECT OVERHEAD ANNUNCIATOR OPERATION:
CONTROL ROOM: 1 EXTRA NCO EACH CONTROL ROOM SECONDARY: 1 EXTRA OPERATOR EACH SECONDARY SERVICE. WATER: 1 EXTRA WATCHSTANDER 2.
NORMAL SHIFT COMPLIMENT, IN THE PERFORMANCE OF THEIR HORMAL DUTIES, SHALL BE EXTRA AWARE OF ENSURING ANY OBSERVED ALARM IN THE FIELD IS COMMUNICATED TO THE CONTROL ROOM SO THAT THEY CAN ENSURE ANY APPROPRIATE OHA HAS FUNCTIONED CORRECTLY.
CONTROL ROOM OPERATORS SHALL BE EXTRA AWARE THAT ANY CONSOLE ALARMS HAS THE CORRESPONDING OHA FUNCTION CORRECTLY.
3.
IF A LOSS OF THE OHA SYSTEM OCCURS AND THE DURATION IS LESS THAN 15 MINUTES, A ONE HOUR REPORT WILL BE MADE PER ECG SECTI0a 10D.
l l
1 e
MONITORING REOUIREMENTS: CONTROL ROOM 1.
THE PURPOSE OF THIS POSITION IS TO CONTINUOUSLY MONITOR THE CONTROL ROOM BACK PANELS AND RACK AREAS TO PROVIDE VERIFICATION OF PROPER OPERATION OF EACH UNITS OVERHEAD ANNUNCIATOR SYSTEM.
2.
CONSTANT SURVEILLANCE OF THIS AREA IS REQUIRED.
THIS POSITION WILL BE CONTINUOUSLY MANNED.
LEAVING THIS AREA REQUIRES A RELIEF WHO WILL ASSUME ALL RESPONSIBILITIES OF THIS POSITION.
THE SNSS OR NSS SHALL DE INFORMED OF WHO IS MANNING THIS POSITION AT ALL TIMES.
3.
ANY ALARMS OR ABNORMAL CONDITIONS SHALL BE REPORTED TO THE BOARD OPERATOR AS SOON AS THE CONDITION IS OBSERVED.
THIS WILL ALLOW THE BOARD OPERATOR TO VERIFY THAT THE OHA SYSTEM IS RESPONDING AS REQUIRED.
4.
RELIEF TO THE NEXT SHIFT WILL BE ON STATION, THIS POSITION SHALL REMAIN ON STATION AT ALL TIMES.
5.
THE FOLLOWING INDICATIONS SHALL BE CONTINUALLY MONITORED:
AUX TYPEWRITER P-250 TYPEWRITER RMS COMPUTER RCP VIBRATION RP4 FIRE PROTECTION CW SCREENS RP6 MIMS NI'S SSPS AMSAC 6.
THE FOLLOWING ADDITIONAL ACTIONS WILL BE TAKEN:
A) VERIFY BETA OHA CRT IS UPDATING THE CORRECT TIME B) OPEN RX PROT. CABINET DOOR AND VERIFY OHA COMES IN.
C) PERFORM A FUNCTIONAL TEST OF THE BETA SYSTEM BY DEPRESSING THE FUNCT.
TEST PUSHBUTTON AND THEN THE ENTER BUTTON.
A SATISFACTORY TEST WILL RESPOND WITH
" FUNCTIONAL TEST COMPLETE".
D) PERFORM AN ALARM
SUMMARY
TEST BY DEPRESSING THE ALARM
SUMMARY
PUSHBUTTON AND THEN THE ENTER BUTTON.
A SAT TEST IS VERIFICATION THAT THE ALARMS AGREE WITH THE CRT POINTS AND " PORT STATUS, SCANNER STATUS COMPLETE" PRINTS OUT.
E) VERIFY THE PRIMARY RED LED'S ARE LIT ABOVE THE OHA COMPUTER.
l MOMITORING REOUIREMENTS: SECONDARY PLANT 1.
THE PURPOSE OF THIS POSITION IS TO MONITOR SPECIFIC SECONDARY ALARM STATIONS TO PROVIDE VERIFICATION OF PROPER OPERATION OF EACH UNITS OVERHEAD ANNUNCIATOR SY ST EM.
2.
CONSTANT SURVEILLANCE OF THIS AREA IS REQUIRED.
THIS POSITION WILL BE CONTINUOUSLY MANNED.
LEAVING THIS AREA REQUIRES A RELIEF WHO WILL ASSUME ALL RESPONSIBILITIES OF THIS POSITION.
THE SNSS OR NSS SHALL BE INFORMED OF WHO IS MANNING THIS POSITION AT ALL TIMES.
3.
ANY ALARMS OR ABNORMAL CONDITION ON ANY OF THE MONITORED PANELS SHALL BE REPORTED TO THE CONTROL ROOM AS SOON AS THE CONDITION IS OBSERVED.
THIS WILL ALLOW THE CONTROL ROOM TO VERIFY THAT THE OHA ALARMS AND CLEARS AS REQUIRED.
4.
ONCE EACH SHIFT CONTACT THE CONTROL ROOM AND INITIATE AN ALARM FROM EACH UNITS GENERATOR LEADS PANEL AND UNIT 2'S ISOPHASE PANEL, ENSURE THAT THIS ALARM IS RECEIVED AND THEN CLEARED LOCALLY AND IN THE CONTROL ROOM.
5.
REMAIN IN COMMUNICATION WITH *HE CONTROL ROOM VIE THE PAGE AND TELEPHONE AND LISTEN FOR PAGE ANNOUNCEMENTS FROM THE CONTROL ROOM.
6.
RELIEF TO THE NEXT SHIFT WILL BE ON STATION, THIS POSITION SHALL REMAIN ON STATION AT ALL TIMES.
7.
THE FOLLOWING ALARM PANELS WILL BE CONTINUALLY MONITORED:
TSI PANEL ISOPHASE PANEL (U2 ONLY)
STATOR WATER / SEAL OIL PANEL GENERATOR LEADS ANNUNCIATOR CLAND SEAL PANEL SGFP PANELS
.~
i MONITORING REQUIREMENTS: SERVICE WATER 1.
THE PURPOSE OF THIS POSITION IS TO CONTINUOUSLY MONITOR THE SERVICE WATER STRUCTURE FOR ANY SIGNS OF FLOODING OR ABNORMAL EQUIPMENT OPERATION.
THIS POSITION IS BEING ESTABLISHED TO PROVIDE A VERIFICATION OF PROPER OPERATION OF EACH UNITS OVERHEAD ANNUNCIATOR SYSTEM.
2.
CONSTANT SURVEILLANCE OF THE SERVICE WATER STRUCTURE IS REQUIRED.
THIS POSITION WILL BE CONTINUOUSLY MANNED.
LEAVING THIS AREA REQUIRES A RELIEF WHO WILL ASSUME ALL RESPONSIBILITIES OF THIS POSITION.
THE SNSS OR NSS SHALL REMAIN INFORMED OF WHO IS MANNING THIS POSITION AT ALL TIMES.
3.
ANY ABNORMAL INDICATION SHALL BE REPORTED TO THE CONTROL ROOM IMMEDIATELY.
i 4.
EACH SERVICE WATER BAY, EACH CONTROL ROOM AND THE SERVICE WATER SCREEN AREA SHALL BE MONITORED EACH HOUR.
THE SERVICE WATER BAYS SHALL BE MONITORED BY A COMPLETE TOUR OF THE AREA INCLUDING THE OBSERVATION OF THE WATER LEVEL IN EACH SUMP.
5.
REMAIN IN COMMUNICATION WITH THE CONTROL ROOM VIA THE PAGE AND TELEPHONE AND LISTEN FOR PAGE ANNOUNCEMENTS FROM THE CONTROL ROOM.
6.
RELIEF TO THE NEXT SHIFT WILL BE ON STATION, THIS POSITION SHALL REMAIN ON STATION AT ALL TIMES.
i i
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(..
l SUPPLEMENTARY REOUIREMENTS FOR LOSS OE OHA'S A) CONTROL ROOM:
BOARD OPERATOR - NORMAL COMPLIMENT, CONTROL OF CONSOLE, ASSISTED BY EXTRA NCO.
DESK OPERATOR - NORMAL COMPLIMENT, INITIATE AND OBSERVE TURBINE TREND, NOTE ALL AUX TW ALARMS AND P-250 ALARMS.
NCO - EXTRA BOARD OBSERVER FOR CHANGING PARAMETERS AND ALARMS, ASSISTS BOARD OPERATOR.
NEO - DEDICATED TO OBSERVING RP4 PANEL, REPORTS ALL CHANGES IN LAMP STATUS TO BOARD NCO.
NEO - BACK PANEL AND RACK ROOM OBSERVER.
ROVE AND REPORT ALL INDICATION CHANGES, SPECIFICALLY ON THE FOLLOWING PANELS:
RMS, RCP VIBRATION FLANGE AND SHAFT, CW SCREEN INDICATION, RP6, MIMS, NI'S, SSPS, AND AMSAC.
B) SECONDARY.
DUTY OPERATOR - ROVE SECONDARY l
NEO - ASSIST DUTY OPERATOR, ROVE AND MONITOR THE FOLLOWING SPECIFIC AREAS:
MPT'S, APT'S, GEN EXCITATION PANELS, STATOR / SEAL OIL ALARM PANEL, SGFP ALARM PANELS, TAC TEMP / LEVEL, GEN LIQUID DETECTORS.
C) SWITCHYARD:
NEO - MONITOR TRANSFORMERS AND LOCAL BREAKER ALARMS PANELS.
D) CIRC WATER:
DUTY OPERATOR - CONTINUOUS ROVE.
E) SERVICE WATER: NEO - MONITOR BAYS, SCREENS, AND CONTROL ROOMS.
F) AUX BUILDING:
NEO - SPENT FUEL PIT LEVEL AND TEMP, DIESEL GENERATORS.
The RWST Low Level OHA on Unit 1 is the caly audible alarm indication that the RWST is at 15.24 ft. If we should lose the OHA System the Operators in the Control Room must recognize the importance of monitoring RWST console level indication. If an EOP entry is needed all Operators are required to recall at 15.24 ft we must entry EOP-LOCA 3. Unit l
2 has console alarm indication which will provide an audible indication.
l
e The following 2 OHA have no other Control Room Indications.
OHA-C 35 SFP Low Level EOP-LOPA 1 Operator Actions: Operator monitoring Spent Fuel Pit Level and Temperature should notify Control Room Immediately of any level change. Control Room operators should be sensitive to auxiliary typewriter alarm associated with the SFP Sump Level and increases in WHUT's.
OHA-A 46 F.P. Wtr. flow Cont.
EOP-FRCE 2 We should verify if Hope Creeks Fire Pump is running and notify Site Protection to check our Fire Pump for status, e
._._______..m L
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l' MONITORING REOUIREMENTS: CONTROL ROOM 1.
THE PURPOSE OF THIS POSITION IS TO CONTINUOUSLY MONITOR THE CONTROL ROOM BACK PANELS AND. RACK AREAS TO PROVIDE VERIFICATION OF PROPER OPERATION OF EACH. UNITS OVERHEAD ANNUNCIATOR SYSTEM.
2.
CONSTANT SURVEILLANCE OF THIS AREA IS REQUIRED.
THIS POSITION.WILL BE CONTINUOUSLY MANNED.
LEAVING THIS' AREA REQUIRES A RELIEF WHO WILL ASSUME ALL RESPONSIBILITIES OF THIS POSITION.
THE SNSS OR NSS SHALL BE INFORMED OF WHO IS MANNING THIS POSITION AT ALL TIMES.
3.
ANY ALARMS OR ABNORMAL CONDITIONS SHALL BE REPORTED TO THE BOARD OPERATOR AS SOON AS THE CONDITION IS OBSERVED.
THIS WILL ALLOW THE BOARD OPERATOR TO VERIFY THAT THE OHA SYSTEM IS RESPONDING AS REQUIRED.
4.
RELIEF TO THE NEXT SHIFT WILL BE ON STATION, THIS POSITION SHALL REMAIN ON STATION AT ALL TIMES.
5.
THE FOLLOWING. INDICATIONS SHALL BE CONTINUALLY MONITORED:
AUX TYPEWRITER P eJO TYPEWRITER RMS COMPUTER RCP VIBRATION RP4 FIRE PROTECTION
.CW SCREENS RP6 MIMS NI'S SSPS AMSAC 6.
THE FOLLOWING ADDITIONAL ACTIONS WILL BE TAKEN:
A) VERIFY BETA OHA CRT IS UPDATING THE CORRECT TIME B) OPEN RX PROT. CABINET DOOR AND VERIFY OHA COMES IN.
C) PERFORM A FUNCTIONAL TEST OF THE BETA SYSTEM BY DEPRESSING THE FUNCT.
TEST PUSHBUTTON AND THEN THE i
ENTER BUTTON.
A SATISFACTORY TEST WILL RESPOND WITH
" FUNCTIONAL TEST COMPLETE".
t D) PERFORM AN ALARM
SUMMARY
TEST BY DEPRESSING THE ALARM
SUMMARY
PUSHBUTTON AND THEN THE ENTER BUTTON.
A SAT TEST IS VERIFICATION THAT THE ALARMS AGREE WITH THE CRT POINTS AND " PORT STATUS, SCANNER STATUS COMPLETE" PRINTS OUT.
E) VERIFY THE PRIMARY RED LED'S ARE LIT ABOVE THE OHA L
COMPUTER.
'M '8 a
g Unit 2 OHA Windows with no alternate indication in the CR or CR Equipment Room o
Window Nomenclature OHA As c,
A-15 Fire Pump 1/2 Run -- c ' L "'l-
- \\
A-21 213 Panel Door Open i
A-23 Fire Pump 1/2 Trouble'O' Fire Prot Wtr Press Lo )],
A-31
')
,,/[-'
H i
A-32 Fire Prot 28VDC Loss N
I.-M'~',, v A-39 Fire Prot CO, Press Hi or Lo i-
-ym%~d
(
OHA B:
B - 1 _ _. ___.
Fresh Water System Trouble / ' u B-3, 11,.
19, 27 2A, E,
C, D Vt1 Instr Bus Invert f
d'/
Fail se B-7, 15 Turb Area SW Hdr Press Hi, Lo /
..('t(B Y ~
B-8,-
16 21-23, 24-26 SW Strainer Trouble'
- p B-9 Htg Wtr Stm Sys Trouble /' '
B-17 Aux E]iler Trouble,.
B-21, 22 21-23, 24-26 SW Screenwash Troublee'-
J.3,
B73, 2P [#2 i 21-23, 24-26 SW Pmp Brg Wtr Press Lo
$ 'f O
-;.g.
B-29, 30 21-23, 24-26 SW Pmp Sump Area Level y Hi B-31, 32 21-23, 24-26 SW Pmp Room Temp Hi or,_/,
Lo B-37, 38 21, 22 CC Hx SW Flow Hi -,'
~
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.._._.___.__._._m.m.m._.-_
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Window Nomenclature l
t OHA-C:
i C-1 Gas Analyzer Trouble l
C-9 104 Panel Trouble Q 1-23 CVCS HUT Level h
C-17 C-18 Rx Sump Overflow C-19 SFP Temp Hi C-25 BA.Evap Trouble C-26, 34 21, 22 RHR Sump Overflow C-27, 35 SFP Level Hi, Lo C-33 RWST/PWST Overflow C-46 Personnel Access Door Open OHA-D:
//
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D-4 thru 7 21 thru 24 RCP Brg Oil Lvl Hi D-12 thru 15 21 thru 24 RCP Brg Oil Lvl Lo D-20 thru 23 21 thru 24 RCP Brg Clg Wtr Flo Lo (backed up by Seal Water Out Temps
- g g
yN
' on the P-250)
['[RCP Vib Hi' k
?
D-36
,?{
3,,9~
w
\\i RCP Brg Clg Hdr Temp Hi D-37 N
l D-38 Therm Barrier Temp Hi D-39 RCP Seal Wtr Byp Flo Lo l
1
Window Nomenclat.11J_g OPA-E p
(pc. A _
E-1, 9
21, 22 Seal Wtr Inj-Fitr-dfp-Hi-Ldw 1
J E-17
..BA-Batch Tk Lvl---Lo E-25 BA._ Batch-Tk-Temp !!i 04 Lo E-32 Rod Drive Pwr Sply Gnd Fault OHA-G:
G-8 TAC Expansion Tank Level Hi or Lo
/M N
G-16 TAC Exp Tk N, Press Hi G-24 TAC Temp Hi or Lo C I'"~
G-32 TAC Pmp Disch Press Hi or Lo G-23 CW Scrnwash Strainer d/p Hi n
. ' d C_bh-t G-31 CW Sunwash Press Lo G-39 1 & 3 CW Brg Lube Presss Lo G-47 NaClO Trouble G-29 4r-ime -Tank Vac D G-37 Prime Tank Level---Mi G-35 TSI Trouble
<(,c._,,c,c.. C, -" "
1 s
G-36 Cond Pol Byp Alert's,
)
G-44 Cond Pol Trouble v ; w. c s-G-43
-Turb.^_rea Lvl Hi Pmp Start G-45 Ccnd-Ret--Tank--Level M4 nr u-
l
.c Wigdgy Nomenclature f
OEA-5:
i H-1 Gen Liq Dets Lvl Hi H-2 Seal Oil Skid Mtrs Trb1 s
k Seal Oil Stor Tk Lvl Hi or Lo H-9 i
lY Main Seal Oil Pmp Emer Bkr Clsd H-10 O,b g
H-26 Emer Seal Oil Press Lo H-34 Seal Oil d/p Lo H-15, 23, 31 MPT Phase 1,
2, 3
Trouble (no lockout actuations) i H-16 APT Trouble (no lockout actuations) i H-28 Gen /Exc F1d Gnd t
f H-29 VReg Mismatch H-44 Gen Stat Coil in/out Temp Hi H-45 Gen Stat Clg Sys Trbl I
I H-46 Gen Stat Wtr Flow / Press Lo H-48 Transient Data Recorder Trouble l
l OEA-J:
I J-28 FO Day Tank Level Trouble ORA-K:
K-11, 19 21, 22 Sta Xfmr Trouble (no lockout actuations)
K-21 2
Sta Xfmr Trouble (no lockout actuations)
K-22 500KV Breaker Trouble (no Breaker trips)
~
l S2.Op.AR.zz.0001(q)9 mammme I
l l I l PWR l
I I FAIL 6
mmmmmm l
DEVICES:
N/A SETPOINT:
N/A
1.0 CAUSE(S)
1.1 Either of the following:
A.
Imss of one or both of the Annunciator AC power supplies B.
Annunciator Internal Power Supply Failure 2.0 AUTOMATIC ACTION:
NOlh
+
'Ihe RCW Computer, Printer, Operator panel, and Annunciator CRT receive power from 21 MAC only. The rest of the System either has a redundant circuit or automatically transfers to a redundant power source.
+-
A SER transfer from the Main to the Aux Contruller, or back again, (such as would occur on a loss or re=InIng of the 21MAC power supply),
will cause all currently alanning OHA Windows to undergo a FLASHING /OFF/REFLASH evolution. 'Ihis is normal and will not affect operability.
2.1 None 3.0 OPERATOR ACTIONS:
3.1 IF AT ANY TIME it is determined that any annunciators or annunciator peripherals have lost power, THEN MAINTAIN Plant Conditions stable as directed by the SNSS/NSS.
(Continued) h l
Page 1 of 3
// /
A-1
/
Salem 2 eage 5 of 82 acv. 2
S2.OP-AR.zz.ooouq) 3.2 NOltFY the SNSS/NSS to REFER to the ECG.
3.3 E the Annunciator CRT is deenergized, THEN perform either or both of the following to restore Computer Point monitoring:
A.
RESTORE the CRT by unplugging the CRT (inside 2CC1), and plugging it into any available 120VAC outlet.
i M
B.
RESTORE the printer as follows:
\\
l.
PLACE the Printer Switch in Position B (BACKUP).
2.
UNPLUG the printer from its normal location and plug the. printer into any available 120VAC outlet.
3.
MONITOR the printer (instead of the CRT), to determine CRT points when any alann is received.
l 3.4 DETERMINE the source of the alarm as follows:
b CRT Point Desenption 1
Armunciator Main AC Power Feed Failure 9
Annunciator Internal Power Failure 1
3.5 E CRT Point 1 is in alarm, THEN SEND an operator to checi Ge status of 21 MAC, Bkr # 17 (Normal Source) and 24 MAC, Bkr # 1 (Backup Source).
A.
E either of the above sources are lost and cannot be restored, THEN IN111 ATE a Work Order Request to correct the cause of the alarm.
B.
E 21MAC is lost and cannot be restored, THEN PLACE the " Black Box" switch, (in Cab 72-2), in the SER-B position.
3.6 E CRT Point 9 is in alarm, THEN perform the following at Cabinet 116-2 in the Rack Room to attempt to determine the cause and the affected equipment:
A.
CHECK the status of the four +5VDC, the two +12VDC, and the two
-12VDC red lights for the SER I.ogic Power Supply canis at the front panel.
Page 2 of 3 A-1 S&m 2 Page 6 of 82 Rev.2 l
S2.oP-AR.zza0icq) O; I
B.
E any of the Logic Power Supply lights are off, IDEN VERIFY the PS toggle switch for the affected card, (in the back of the cabinet) is ON.
CAUTION Loss of any 1E2 of the Logic Power Supplies listed below will result in inoperable Windows.
l
+
If the +5VDC power supplies for both PS1 and PS2 are deenergized, Scanners 9 through 11 will be inoperable.
+-
If the +5VDC power supplies for both PS7 and PS8 are deenergized, Scanners 1 through 8 will be inoperable.
+
If both +12VDC power supplies are deenergized, all OHA Windows will be inoperable. (The historical Buffer will still 1
process data)
+
If both -12VDC power supplies are deenergized, all OHA Windows will be inoperable. (*Ihe historical Buffer will still process data) i C.
E any of the conditions of the caution above exist, THEN perform the following steps:
1.
DEFERMINE which OIIA Windows are affected IAW Attachment 3 of S2.OP-SO. ANN-0001(Q), Annunciator System Operations.
2.
NOTIFY the SNSS/NSS to refer to the ECG.
3.
MAINTAIN Plant Conditions stable.
3.7 INTIIATE a Work Order Request to determine and correct the cause of the power failure alartn. (7he Power Distribution list in Attachment 4 of S2.OP-SO. ANN-0001(Q), Annunciator System Operations may aid I&C)
References:
Dwg.
232976 Salem 2 Pa,e 7 of 82 -
Rev. 2
A./ - I Q f,oc. ~ Ja, a.
S2.OP.AR.zz.oool(o) l l
w LD w.. L ALARM 9
mummmmmm E222222. _
ANNUN LOGIC FAIL mummmmme l
I DEVICES:
N/A SETPOINT:
N/A
1.0 CAUSE(S)
1.1 Logic Failum in one or more of the ten Logic A Cards or the ten redundant Logic Cards of the Annunciator System 2.0 AUTOMATIC ACTION:
2.1 Logic A Card (s) only:
Initiates a SER transfer which causes a FLASHING /OFF/REFLASH of all alarming OHA Windows (Does nel affect System operability) 2.2 Logic B Card (s) only:
None 2.3 Logic A and B Cards:
Loss of multiple Overhead Alarms (exactly which depends on the specific Cards lost) 3.0 OPERATOR ACTIONS:
1 3.1 E Window A-1 is alarming, THEN GO TO to that alarm.
3.2 PERFORM an OHA Test (at the Consoles) on all five groups to confum all Windows operable.
A.
E any Windows fail to light, THEN perform the following:
1.
MAINTAIN Plant Conditions stabie.
2.
NOTIFY the SNSS/NSS to refer to the ECG.
3.3 NOTIFY Maintenance to determine and cormet the cause of the alarm.
Page 1 cf1 A-9 i
References:
Dwg.
232976 i
Salem 2 Page 19 of 82 Rev.2
l S2.Or.azz.oooia unu mmmmmmme 17 i
i l
E_________
ANNUN GND DET mammmmme DEVICES:
N/A SETPOINT:
N/A
1.0 CAUSE(S)
1.1 A gmund on wiring fmm either of the following:
A.
Any of the DC field inputs to the Overhead Annunciator System B.
Any of the inputs to the Console Gmup Annunciator System @ezel alanns) 2.0 AUTOMATIC ACTION:
NO m One ground detector moniton the DC Field Inputs to the Overhead Annunciator alarms and another detector monitors the inputs to the Console Group Alarm System (Bezel alarms). A single ground on either systern should not have any effect on the affected alanns. If a second ground occurs on the j
I same system, it may cause erronious alarms, p. event a valid input from causing an alarm, or even blow a fuse and remove power from the field inputs. (The Held inputs to the Bezel alanns come from Alarm Relay contacts in the Bailey Cabinets) 2.1 None (Contirmed)
Page 1 of 2 A-17 Salem 2 ease 30 of 82 m.2
l S2.OP.AR.zz.000ico) 3.0 OPERATOR ACTIONS:
3.1 DETERMINE the source of the alarm as follows:
CRT Point Descriotion 17 Annunciator Ground Detector - Overhead Annun System 412 Annunciator Ground Detector - Console Group Alarm Sys 3.2 IF AT ANY_ TIME, any annunciators or annunciator auxiliary circuits are inoperable, THEN perform the following:
A.
MAINTAIN Plant Conditions stable.
B.
NOTtFY the SNSS/NSS to refer to the ECG.
3.3 E the source of the alarm is CRT Point 17, THEN GO TO S2.OP-SO. ANN-0002(Q), Overtiend Annunciators Ground Detection.
)
3.4 E the source of the alarm is CRT Point 412, THEN INITIATE a Work Order Request to determine and correct the cause of the alarm.
4 i
i Page 2 of 2 A-17
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I To. Cal Vondra i
General Manager - Salem Station d
From: Michael Morroni Manager - Salem Technical Department
Subject:
Overhead Annunciator l
our investigation into the lockup of the overhead annunciator on December 13, 1992 and the discrete annunciator window i
problems known to date is at a point that the compensatory actions identified in the justification for continued operation should be re-evaluated.
a l
It has been determined that the Unit #2 overhead annunciator operates in accordance with its present design based on the troubleshooting which was performed via TS2.IC-ZZ.0HA-0001(O) i REV. O on December 18, 1992. The SER A main controller card which was removed during the troubleshooting procedure was extensively tested at Hathaway/ Beta and found not to be at i
fault for the lockup condition. It has been concluded that the overhead annunciator locked up due to manipulations on the keyboard of the RCW workstation when the " Black Box" switch was in the RCW A position. This event was duplicated i
at the factory of Hathaway/ Beta. This conclusion is also i
concurred with by our engineering department. (See attachment l
"A")
All of the discrete overhead annunciator window malfunctions have been investigated. The details of the troubleshooting, l-the causes identified and engineering judgements are included in attachment "B".
Although specific root causes have not 1
been identified for each malfunction, it can be concluded i
that each of these malfunctions was a discrete window I
problem. These problems were readily identified by the operators who initiated corrective actions. Since these failures did not represent a complete annunciator failure, we conclude that the failures are random and overall annunciator functionality was maintained.
The overhead annunciator system has been evaluated for j
viruses by our Methods and Systems Department and found to be i
free of viruses. (See Attachment "C")
l The keyboard for the engineering workstation has been disconnected from the RCW workstation and RED TAGGED for the Nuclear Shift Supervisor with instructions from the Technical Department to prevent people other than the System Engineer from operating this keyboard.
Li Based upon the above information it is concluded that the
/
overhead annunciator system is fully functional and the immediate corrective action to disconnect the PC keyboard will prevent the lockup failure from reccuring. It is also i
\\
d 4
concluded that the compensatory actions put in place by the Justification for Continued Operation are no longer required.
Therefore we recommend that the compensatory actions be terminated.
N c.c. Vince Polizzi - Operations Manager i
i
I O PSEG Arr4cuseAlr
'A i
Public Serwce Electne and Gas Company P O. Box 236 Hancocks Bndge. New Jersey 08038 j
Nuclear Department l
ELE-92-0693 i
TO:
D.
W.
Lyons
' gp Technical Liaison to NRC Augmented Inspection Team Regarding Overhead Annunciator Lockup k
i FROM:
M.
L.
Bursztcin Nuclear Electrical Engineering Manager
SUBJECT:
ENGINEERING POSITION REGARDING SYSTEM LOCKUP f
DATE:
December 21, 1992 Attached you will find two letters regarding the Nucicar Electrical Engineering Department's position on the overhead Annunciator System.
The first letter addresses the functional of the system and includes two support letters from the vendor, Hathaway/ Beta.
The second letter discusses our preliminary review of the system's ability to indicate and annunciato failures.
I concur with the position presented in the attached letters and expect that they will be of assistance to you in the development of your engineering evaluation regarding Overhead Annunciator Lockup issue.
If you have questions regarding the information provided herein, please do not hesitate to call myself at extension 1875 or Jack carey at extension 5080.
JDC: sri C
General Manager - Engineering & Plant Bettorment Technical Manager - Salem i;q,
,iinmt.no
.b 46-bes Mty DPP
.w u.
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,e ATTAaanwr " A" i
TO:
Moises L.
Bursztein Manager Nuclear Electrical Engineering FROM:
John D.
Carey, Jr.
-f Salem IEC Supervis
/
i i
l
SUBJECT:
Functional Status of the Salem Overhead Annunciator j
System j
DATE:
Dec. 21, 1992 In a letter to myself from Mr. Michael van der Helm of Hathway/ Beta (ref attached), Mr van der Helm informs me that through testing at the factory in Carrollton, Tx.,
Beta has been able to repeat the lockup failure of our OHA through commands from the RCW while using "Procom Plus*.
Beta personnel have been on site for a week troublesnooting the system with station technical department and have investigated what they believe are all reasonable potential software and hardware problems.
As a result of their efforts to date, they have not identified any hardware or equipment.c__
problems with the system.
It is now their opinion, t sed upon the repeatability of the forced lockup a,t the factory, and the statements from the station operations personnel regarding their interfaces with the system just prior to the event, that the transmission of the " Control L's" from the computer was the cause of the system lockup.
Mr. Rossi McDade. Systems Engineering Manager for Beta, has stated to me that this is not a random failure (ref attached letter from BETA dated 12-21-92), but rather an inadvertently induced ta11ure via keyboard operation that was corrected by resetting the S4Rs.
It is his opinion regarding the lockup concern that the system is fully functional at this time. and i
the system's normal functional tests adequately demonstrate the perfortsance on an hourly basis.
He further believes that
)
the system is not subject to additional lockups as long as the computer access is appropriately controlled.
Based on the above explanation, the expert opinion of Mr.
van der Helm and Mr. McDade, and on the information I am aware of regarding the design of the system and the events surrounding the occurrence. I believe that the OHA system is tully functional, regarding the potential for a locxup situation, and I do not see a need to continue the compensatory actions implemented by the station.
I do recommend that strict controls be placed upon the use or the computer to interface with the OHA.
In addition, I recommend that a system functional test be performed after any use of the computer keyboard and that test should be followed up with the initiation of'an actual valid input such as openinu a cabinet door in th % ay room) With these precautions. :
sm confident that the operar.or will have adequately ver2fied the Page of
AcdMcl0T I' operation of the system.
I have discussed these recommendations with Mr. McDade of BETA and Dave Herrell of the computer group and they concur with these recommendations.
i k
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' ') Y U
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L.
i kTMC,N M TO:
J.
D. Carey Salem I&C Supervisor FROM:
R.
L. McDade l
Engineering Manager Hathaway/ Beta 4
1
SUBJECT:
FUNCTIONAL STATUS OF THE HATHAWAY/ BETA SER 4100R AND
}
1500 DISTRIBUTED ANNUNCIATOR DATE:
December 21, 1992 I
The question posed to Hathaway/ Beta concerning the operational I
status of the above referenced equipment is as follows*
i Hathaway/ Beta has demonstrated at the factory that the 3113.
anomalv experienced by PSE&G with the sequential events recorder j
and associated distributed lamp boxes is not a random failure, nor an intermittent failure.
We feel it is an inadvertent i
problem introduced by human intervention that caused the Main j
l Controller to go into a command mode and wait for additional L
instructions.
While waiting for the additional instructions, the i
i Main Controller was not outputting to the annunciator port.
1 Hathaway/ Beta has explained the theory of operation to PSE&G personnel and can say at this point, we fully declare the events i
recording system is fully operable and will perform its published capabilities and its design function.
The statement is made j
conditionally upon the belief that strict'and adequate c.ontrols will be implemented governing the access and use of the computer i
interface to the events recording system and related hardware.
Hathaway/ Beta is also prepared to suggest and help determine ways to best utilize the additional hardware and software diagnostic capabilities designed into the 4100R Events Recording System and 1500 Distributed Annunciator System.
l
. W{~
wf. f c.
l l
et ATrAc4He4T 4 so Hathaway I
t To: Jack Carey oSE&G C::: Dave Lyons PSE&G From: Michaei van der Helm Hathaway/8 eta Date: 12/20/92 Cn 12/19/92 Hathaway/ Beta cemonstrated that sending two Control L 's in a row from a PC attached to the system ( in PSE&G'a configuration) to the RCWA cort of, the SER/
Annunciator system could cause an anomaly similar to cne one of '2/10/92 at Salem.
Hathaway/ Beta was askeo wnetner the annunciator system could be affectea ey the transmission of Control cnaracters to other ports of the SER system, whether Control characters other than Control L would affect the RCWA
( or RCWB ) port, anc whether control characters sent to other PC accessible ports would affect the SER/ Annunciator vstem.
The first cuestion can ce answered by reviewing cne system wiring diagram (PSE&G drawing no. 232?77 8 4051-4).
The anomaly is believec to have been caused by the transmission of Control L 's from the computer while it was running the program "procomm Plus*.
The system wiring diagram will show that the configuration port of the overhead annunciators, and four ports of the SER can be addressec by the computer.
All other corts of the SER/ Annunciator system can not be acoressee by the comeuter.
The first of the five mentionec above. the annuncistor configuration port (Config.), will only accept two control characters which it considers valid: Control M (which is Carriage Return ) anc Control C (which is usea to abort from a configuration list ).
All other Control characters are ignored by the configuration cort of tne overhead annunciators.
The four SER oorts wnicn can be accresseo by the computer are SERA. SERS, RCWA, and RCW8.
The ports. SERA anc SERB, are on different contro'lers but are the same type of cort, anc therefore will be ciscussea togetner.
The same is true of tne ports RCWA a no RCWB. ano so they will also be ciscusseo together.
The typical resconse of the SER to BETA PRODUCTS DIVISION 0029 McKenzie Drive #150. P.O. Box 115004 Canoitton. rx 75011 5004 releonone: 214 241-2lllD0
- Fax: 214 241-6752
4 e
tt p
hkN Control characters sent f rom procomm Plus to tna SERA /5ERS port is as felicws:
PUBLIC SERVICE ELECTRIC & GAS UNIT 2 ANNUNCIATOR SYSTEM Station number 2 19 Dec 1992 17:08:25 m Improper entry J
complete The greater Onan sign () ) is the cromet the SER issues o
indicate that a commanc may be enterec.
The perioc (
following the firrt =romot is the typical esponse e
-a
- ~R d
it receives a Contrei cnaracter.
The remainder :f the when text in the soove exammie ( Station Name, Station Numoer.
Time, Improper Entry, and Commiete ) is typical for any i npu t to this cort, althougn if a valid entry has oeen enterec, the
- !morocer Entry' woulo be reolacec by the commanc name anc the Como l e t e " message would have the command name in front of it.
i The SERA / SERE cort is intenced to accept and resoonc to four Contrcl cnaracters: M ( Sacxscace ), M ( Carriage Return ),
o (X-on), a nd S ( X-Of f ).
of the remaining Control characters, thirteen will generate a response like the one shown aoove, seven will generate a variation of tne response shown above, and two will not generate any response.
In all cases where an illegal control character is sent to the 3
SERA / SERB port, it does not cause the SER to lock up.
When Procomm Plus is connected to the RCWA/RCWB port. and two of the following Control cnaracters:
J.
K.
L.
O.
E-I-
and V.
are sent, the SER is affectec.
Characters
.c. and V will cause the SER to stoo displaying avents on :ne color CRT and Annunciator wincows for two to five minutes, but in all cases the SER times cut and resenc itself.
The result of this reset is that the overheac annunciator wincows will be clearea and then re-s:stmeo, anc the Color CRT screen will be re painted with all the current alarms, The ena result of sencing two Control M's to the RCWA cort is the same as aoove, but in this case the control of the evernead annunciator wincows anc the Color CRT will be transferrec to the cacKuo main contreiler ( Main Controller "S").
Then two to five minutes later
~ hen tne SER times out. One control tr, the oserneac annunciators enc color CRT will be re-assumeo by the crimary main controller (Main Controller "A*).
Sencing two Ccntrol K*s to the port RCWB, will cause the Main Controller
- S*
to =to= cis=isying events ( crovided it 15 connected to a cis=isy cevice; #or two to five minutes.
cefore it times out anc esetc.
l' 4
Transmitting t.wo Control O's to the RCWA/RCWS cort will 1
cause that Main controller ( A or B) to reset.
a reset of Main Controller "A*
Will result in the clearing and tnen re-alarmins of the overheac annunciators, and a re-painting of the Color CRT screen.
The transmission of two Control ~*s to the RCWA/RCWB port Will clear the 6000 coint historical buffer resident on the Main Controller ( A or S).
None of the results of the amove six Control characters will result i n the indefinite lock up of the SER, as is the case when two Control L's are sent to the RCWA/RCWB cort.
When two control
's are sent to the ACWA/RCWB eort, :he Main controller Will stop sencins events to any display devices that are connectsd. and wait indefinitaly for a response to data-i; has sent.
n the CEse of the crimary Main Controller
("A"1..;his will esui, in an snomaly like the one seen on 12/13/92.
sencing twc of any other Control enaracter :: the C: CWA /RCUB cort oill
.ot cause the SER s steo displaying
- events, i
i i
i l
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i 1
-.c.
"-M+
P-m+4g-+.,,
l bTRO4h/\\EJO T
[
h i
i There were several individual problems that occurred recently on the OHA System which caused the NRC to question the overall functionality of the OHA system. It has i
been determined that these were discrete problems and had no affect on the overall functionality of the system.
- A45 & G45 WINDOWS ILLUMINATED i
Over e weekend of December 12 & 13,1992, a spare window, A45, fit up, also, th G45 window alarmed with no printout on the computer and no indication the Control Room CRT. These windows were cleared during the event later S day night. The System Engineer and the vendor's representative L
have reviewed il the available information from the memories of the OHA System. They h e confirmed there is no SER point number assigned to the A45 window, there e the SER can not generate an alarm to the window. The l
printouts do not show ny signals generated from the SER's to illuminate the G45 window at the time f occurrence. Between the SER, the brains of the system, and the lampboxes re the distributor boards. The vendor's rep has stated that the illumination of spare window without an SER signal could be i
a problem with noise in the syst or with the distributor boards.
Troubleshooting of these windows Sunday, December 20,1992 and Monday, December 21,1992, revealed igher than desired level of noise on the cables and an increase in. level whenev the light test was initiated. This level of noise,265 millivolts, could produce s rious actuations when a noise 4
spike occurs.
Rearranging of cables within e cabinet has reduced the
- background noise level to approximately 236 milliv s and eliminated the level shift. Accordance to the vendor,it would be desirabi o reduce the noise level further, therfore E&PB will be directed to add additional ielding or reroute of j
cables. The problem does not exist on Unit 1 because th cable routings are different.
4 l
Since this was a discrete problem that occurred downstream of t
's, it is not a problem with overall functionality of the OHA system, 4
4 k
I
LAMP BOXES DID NOT SIMULTANEOUSLY LIGHT DURING TEST On December 17,1992, the operators reported that several lampboxes were delayed in lighting when the lamp test was initiated. Each of the lampboxes has two separate microprocessors. Each microprocessor receives its own signal when a lamp test is initiated. Usually all the lampboxes process the signals close enough together to give the operator the impression of lighting simultaneously. The System Engineer and Vendor Rep initiated twelve tests of the lamp test circuits and once observed a slight lag in lighting of the A lampbox, not to the extent described in the IR but observable. It is felt the heightened awareness of the operators toward the functionality of the OHA system caused them to notice this delay.
This is normal for the OHA system.
FAILURE OF A10 & A11 TO RESET Whe restoring the containment pressure bistable, the associated windows A10 &
11, did not clear.
This problem could not be duplicated during troublesh ting on Saturday, December 19,1992. The alarm wa:..:ycled three times and ared each time.
Testing involved cycling the bistable and manually initiati a functional test simultaneously to duplicate the conditions.
4 When the incident occu d, the SER had received the sign 91 that the bistable was restored and issued th ammand to the OHA system to clear the alarm.
This command was received the CRT in the control room and transmitted through the RCW to the printer, e have been unable to determine why the 4
message was not received by the lah box. The theory that the signal was disrupted because it was generated ing the 500 microsecond (.0005 second) functional test can not be supporte 4
This is a discrete problem on the circuits for this do nd does not affect the overall functionality of the OHA system, if th recurs, it will be investigated.
l PROBLEMS WITH ACKNOWLEDGE AND SILENCE PUSHBUTTONS l
Operators have recently had repeated problems with the ability to acknowledge, i
reset and silence alarms on Unit 2. The computer memories do not record the operation of the pushbuttons. Investigation revealed problems with three pushbuttons not a problem with the electronic portions of the OHA system. On Sunday, December 20,1992, the operators on Unit 2 again experienced a failure to acknowledge.
The System Engineer and Vendor Rep began immediate troubleshooting and identified a malfunctioning pushbutton. The problem was several loose set screws, these were tightened. On Monday, December 21,1992, testing of all the pushbuttons on Unit 2 was conducted, this testing identified the two " kick buttons" in the center of the control console failed to make contact greater than 20% of the time. A Work Request l
has been issued to Maintenance to replace them.
1 All pushbuttons on Unit 2 were Loc tited on Monday, December 21,1992. All pushbuttons on Unit 1 were Loc-tited as part of the initial install:':on.
Since this was a physical problem with peripherals to the OHA system and not integral to it, there was no affect on the overall functionality of the system. All I
incoming and clearing alarms would have been received.
l l
. ~.
..- ~.
&CQgg et Put*c Service Electnc ana Gas Company P O Box 236 Hancocks Bndge, New Jersey 08038.
Nuclear Department To:
David Lyor.s - Technical Engineer, Salem i
From:
David Silver - Lead Systems Analyst. Methods & Systems Date.
December 21.11992 i
Subject:
Overhead Enunciator Workstation Virus Scan Outcome i
On Sunday mornmg, December 21st,1 performed a Virus scan on both unit 1 & 2's Compuadd 80286 IBM compatible personal computers which control the overhead enunciator panel as requested The following procedures were performed:
l l
l Reboot on Workstation (s) to check CMOS and RAM validity.
1 Command com for MS-DOS 5.0 file size check.
- i i
l CHKDSK command issued to check for hard drive errors.
i Virus scan of the hard drive (s) and R AM memory for viruscs with a program called SCAN / CLEAN by McAfee Associates version 3.4889 Ader completing the above, I found that both machines were vinns free.
If you have any questions, please feel free to call me at 339-1056 i
David Silver d<'(-
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R. Gehret C.W. Bogert i
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