ML20136E474
ML20136E474 | |
Person / Time | |
---|---|
Site: | Quad Cities ![]() |
Issue date: | 01/03/1986 |
From: | NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION III) |
To: | |
Shared Package | |
ML20136E459 | List: |
References | |
50-254-85-01, 50-254-85-1, 50-265-85-01, 50-265-85-1, NUDOCS 8601070029 | |
Download: ML20136E474 (38) | |
See also: IR 05000254/1985001
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SALP 5
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SALP BOARD REPORT
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U. S. NUCLEAR REGULATORY COMMISSION
' ; REGION III
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' SYSTEMATIC ASSESSMENT OF LICENSEE PERFORMANCE
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50-254/85001: 50-265/85001
Inspection Report
Commonwealth Edison Company
Name of Licensee
Quad Cities Nuclear Power Station
Name of Facility
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June 1, 1984 through September 30, 1985
Assessment Period
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B601070029 860103
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ADOCK 05000254
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I. INTRODUCTION
The Systematic Assessment of Licensee Performance (SALP) program is an
integrated NRC staff effort to collect available observations and data on a
periodic basis and to evaluate licensee performance based upon this infor-
mation. SALP is supplemental to normal regulatory processes used to ensure
compliance to NRC rules and regulations. SALP is intended to be sufficiently
diagnostic to provide a rational basis for allocating NRC resources and to
provide meaningful guidance to the licensee's management to promote quality
and safety of plant construction and operation.
A NRC SALP Board, composed of staff members listed below, met on November 13,
1985, to review the collection of performance observations and data to assess
the licensee's performance in accordance with the guidance in NRC Manual
Chapter 0516, " Systematic Assessment of Licensee Performance." A summary of
the guidance and evaluation criteria is provided in Section II of this report.
This report is the SALP Board's assessment of the licensee's safety
performance at Quad Cities Nuclear Power Station for the period June 1, 1984
through September 30, 1985.
SALP Board for Quad-Cities Nuclear Power Station:
Name Title
J. A. Hind Director, Division of Radiological
Safety and Safeguards
C. J. Paperiello Director, Division of Reactor Safety
D. Vassallo Chief, Operating Reactors Branch 2, NRR
N. J. Chrissotimos Chief, Reactor Projects Branch 2
R. L. Greger Chief, Facilities Radiation Protection
Section
G. C. Wright Chief, Reactor Projects Section 2C
M. A. Ring Chief, Test Programs Section
R. B. Landsman Project Manager, Reactor Projects
Section 2C
R. Bevan Quad Cities Project Manager, NRR
A. L. Madison Senior Resident Inspector
A. Morrongiello Resident Inspector
P. R. Rescheske Reactor Inspector
R. A. Hasse Reactor Inspector
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II. CRITERIA
The licensee's performance is assessed in selected functional areas
depending on whether the facility is in a construction, preoperational,
or operating phase. Each functional area normally represents areas
significant to nuclear safety and the environment, and are normal
programmatic areas. Some functional areas may not be assessed becauss
of little or no licensee activities or lack of meaningful observations.
Special areas may be added to highlight significant observations.
One or more of the following evaluation criteria were used to assess
each functional area:
1. Management involvement in assuring quality
2. Approach to resolution of technical issues from a safety standpoint
3. Responsiveness to NRC initiatives
4. Enforcement history
5. Reporting and analysis of reportable events
6. Staffing (including management)
7. Training effectiveness and qualification.
However, the SALP Board is not limited to these criteria and others may
have been used where appropriate.
Based upon the SALP Board's assessment, each functional area evaluated
is classified into one of three performance categories. The definition
of these performance categories is:
Category 1: Reduced NRC attention may be appropriate. Licensee manage-
ment attention and involvement are aggressive and oriented toward nuclear
safety. Licensee resources are ample and effectively used so that a high
level of performance with respect to operational safety or construction
is being achieved.
. Category 2: NRC attention should be maintained at normal levels. Licen-
see management attention and involvement are evident and management is
concerned with nuclear safety. Licensee resources are adequate and are
reasonably effective such that satisfactory performance with respect to
operational safety or construction is being achieved.
Category 3: Both NRC and licensee attention should be increased. Licen-
see management attention and involvement is acceptable and considers
nuclear safety, but weaknesses are evident. Licensee resources appear
to be strained or not effectively used so that minimally satisfactory
performance with respect to operational safety or construction is being
achieved.
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Trend: The SALP Board has also categorized the performance trend in each
functional area rated over the course of the SALP assessment period. The
categorization describes the general or prevailing tendency (the perfor-
mance gradient) during the SALP period. The performance trends are
defined as follows:
Improved: Licensee performance has generally improved over the course
of the SALP assessment period.
Same: Licensee performance has remained essentially constant over
the course of the SALP assessment period.
Declined: Licensee performance has generally declined over the course
of the SALP assessment period.
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III. SUMMARY OF RESULTS
The overall regulatory performance of the Quad Cities facility has
continued at a high level during the assessment period. Improved
performance in the area of reactor operations is noted. The Regulatory
Performance Improvement Plan appears to have been a major factor in
bringing about the improvement in regulatory performance.
Rating Last Rating This
Functional Area Period Period Trend
A. Plant Operations 3 2 Improving
B. Radiological Controls 2 2* Same
C. Maintenance / Modifications 2 2 Improving
D. Surveillance and
Inservice Testing 1 2 Same
E. Fire Protection /
Housekeeping 2 2 Same
F. Emergency Preparedness 1 1 Same
G. Security 1 1 Same
H. . Refueling 1 1 Same
I. Quality Programs and
Administrative Controls 2 2 Same
- J. Licensing Activities 1 1 Same
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- The Radiation Protection portion of this functional area-is rated Category 1.
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IV. PERFORMANCE ANALYSIS
A. Plant Operations
1. Analysis
Portions of ten routine inspections were performed by the
resident inspectors covering plant operations. Also, two
special inspections were performed by resident and regional
personnel covering the operations area. Three violations
were identified as follows:
a. Severity Level V - Failure to report automatic actuation
of Engineered Safety Feature (265/85007-01).
b. Severity Level IV - Failure to perform adequate shift
turnover (265/85019-01).
c. Severity Level III - Failure of the Unit 1 operator to be
present at the controls at all times during the operation
of the facility (254/84023-01).
The first violation was due to a misinterpretation of new
reporting requirements and appeared to be isolated in nature.
The second violation was the root cause for a sequence of events
which resulted in the Reactor Core Isolation Cooling (RCIC)
system flow control switch being left in manual. Management
responsiveness was good and no other similar violations were
identified.
The third violation represented a matter of major concern to
the NRC and resulted from a special inspection in response to
the October 25, 1984 scram of Unit 2 during which the Unit 1
operator left the controls of his unit. An Enforcement Con-
ference was held on November 5,1984 with members of corporate
and plant management. There were no additional substantive
events involving operators subsequent to this event, indicating
that management controls instituted were responsive. Escalated
enforcement was taken and a Civil Penalty of $50,000 was levied.
The small number of Violations is a result of an aggressive
effort by licensee management to identify potential problems
before they become regulatory concerns. This coupled with a
cooperative and concientious worker attitude has resulted in
improved performance, especially in the latter half of the
evaluation period.
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Control room behavior had been of concern at Quad Cites due to
past events including the October 25, 1984, scram of Unit 2.
Several problems were noted by the NRC and the licensee as a
result of.these events, and licensee management aggressively
addressed these. This includes the issuance of numerous
procedures and a manual entitled " Good Operating Practices."
The professional conduct of operating personnel is of concern
to management and union personnel. Operators are attentive to
their units and alarms are always acknowledged and analyzed
immediately. Reading material is restricted to work / job
related material and other distractions such as radios are not
allowed. Graffiti is not sanctioned at Quad Cities and does
not exist in the control room. Eating is allowed in the
control room, but tais has not proven to be a problem in the
past.
Most operators are concerned with their professional appearance
and maintain reasonable standards. However, there is a minority
that rebel against such restrictions. The licensee is aware of
these anomalies and is working with the union to improve this
condition.
The first special inspection was a team inspection by senior
inspectors to review overall licensee performance and provide
an in-depth assessment of selected areas including operations.
No violations were identified in the operations area and
overall licensee performance was found to be acceptable.
The second special inspection was in response to the
October 25, 1984, scram of Unit 2 during which the Unit 1
operator left the controls of his unit. Also during the scram,
one control rod had failed to insert properly and a valving
error was found to be the cause. The inspection targeted two
concerns: (1) the behavior of control room personnel during
the event, and (2) any damage which may have been caused to
the control rod drive (CRD) as a result of the valving error.
A Confirmatory Action Letter (CAL) was issued on October 26, ,
1984 by Region III delineating several actions the licensee was
to perform prior to restart of Unit 2. These included replace-
ment of the affected CRD and examination of its internals;
verification of all other valves in the CRD system; investigation
of the root cause of the valving error and subsequent lockwiring
of all similar valves in the CRD system; and identification of
any improper control room behavier and appropriate corrective
actions.
The inspection resulted in escalated enforcement as noted
above.
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Corrective actions as a result of this inspection included
those actions taken to comply with the CAL, and the issuance of
-several procedures and procedure changes and a manual entitled
" Good Operating Practices." The procedure changes addressed
the ambiguousness and lack of restrictions on where the unit
operator may go-in the control room, by increased clarification
and the use of diagrams. Also, additional training was given
to supervisory personnel to ensure understanding and compliance.
Additionally, the licensee has instituted a control room task
force to work on further improvements in control room behavior
and performance. This voluntary effort is supported by manage-
ment and union personnel.
Periodic management conferences were held to discuss licensee
progress in the ongoing corporate-wide Regulatory Performance
Improvement Plan (RPIP). The RPIP has resulted in improvement
in overall licensee' performance especially in the latter half
of the evaluation period. The RPIP was well stated, properly
disseminated, and provided understandable policies that required
- decision making be consistently at a level that ensures adequate
management review. Corrective actions associated with violations
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and LERs were prompt and effective and ensured that minor viola-
tions were not repetitive and major violations were rare.
Corporate management was frequently involved in site activities.
Site management's attitude and attention to regulatory matters
and inspector concerns was aggressive and provided for
technically sound, conservative, and thorough responses and
actions in almost all cases. Examples of inspector concerns
which were adequately addressed by the licensee before they
became regulatory issues are: (1) The August 1984 resident
inspection identified a concern that the instrument technicians
were not adequately communicating with operations personnel and
were causing unnecessary actuations of safety equipment. The
licensee provided immediate management attention in this area
and instituted additional controls to eliminate this concern.
(2) Also identified in the August 1984 resident inspection report
was a concern that the maintenance personnel may have the
required procedure available, but not open and being followed
step-by-step. This issue was also immediately resolved and no
further instances were identified.
There was consistent evidence of prior planning and assignment
of work activities. Staffing appeared to be adequate and no
difficulties were identified with overtime or work backlog.
The training program was well defined and was implemented
with dedicated resources for the majority of the staff. The
licensee has committed to comply with the INPO guidelines on
training and is on schedule or ahead in certain instances with
their implementation of this.
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Twenty LERs were submitted in.the operations area during~the.
-assessment period. .This was a reduction by a factor of three
from the previous assessment period. Six of the LER's were
attributed to personnel error of which three resulted in the
violations'noted above. Two of the LERs were due to procedure
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deficiencies andLthe remainder were caused by equipment mal-
function. -While the percentage of personnel errors has
increased, the actual number has remained approximately the
same whereas the significance of _ these errors has been reduced.
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Seven reactor scrams occurred on Unit 1, three of which occurred
while shutdown, and nine on Unit 2, three of which occurred
.while shutdown. ~Six of the sixteen scrams were caused by
personnel error (i.ncluding contractor personnel), one by
. procedural deficiencies,- c ra tna remainder were caused by
. equipment malfunctions. _While the number of operational scrams
. remains the same as the last evaluation period, most occurred
at the beginning of the period. Increased ~ management attention
in this area has resulted.in improvement as. witnessed by the
trouble-free startup of Unit 2 following an extended refueling /
maintenance outage-in June, 1985~, and the absence of reactor
scrams for either unit throughout the latter portion of the.
evaluation period.
During the report period, examinations were administered to nine
reactor operator and nine senior reactor candidates. The overall
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pass rate for the candidates was 77%, which was not significantly
'different from the national average. Requalification
-examinations were not administered by the NRC at the Quad Cities
station.
2. Conclusions
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_The licensee is rated Category 2 in this area. Although
performance in this area was judged to be poor at the
beginning of the assessment period, improvement in both
performance and management involvement have been observed
during the last half of the assessment period.
3. Board Recommendations
None.
B. Radiological Controls
1. Analysis
Eight routine inspections and one special inspection were .
performed during this assessment period by region based ]
. inspectors. These inspections included confirmatory measure- ,
ments, environmental monitoring, chemistry and radiochemistry,
waste generator requirements, operational radiation protection,
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and radwaste management. In addition, the resident inspectors
routinely inspected the licensee's activities in this area,
concentrating on implementation of the ALARA program, and a
special operational team inspection reviewed activities in this
area. Two violations were identified as follows:
Severity Level IV --Failure to control the R gate to the
northeast residual heat removal area (265/84017-02).
Severity Level V - Failure to collect and analyze
technical specification required service water grab
samples due to inoperable service water monitors on both
units (254/85321-01; 265/85024-01)
Management provides good support for the radiation protection
program in manpower, facilities, and equipment as evidenced by
additional contamination control facilities, additional ALARA
staffing, and increased number of ALARA reviews. Onsite
program management and management support in the radiation
protection program along with the continuing good attitude of
the workers appears largely responsible for the licensee's good
performance in this area. Stronger management involyement in
chemistry and radiochemistry is warranted as indicated by
weaknesses in Radchem Technicians (RCT) performance on vendor
supplied blind samples and additional attention is needed in
RCT training as indicated by inspector observed shortcomings in
sample collection and handling practices by RCTs. Stronger
management involvement in radwaste and environmental monitoring
is also needed as indicated by discrepancies noted in this
report in the radiological environmental monitoring program and
by the slow pronress in installation of new service water
monitors. The monitors, originally scheduled for December 1984
installation to coincide with the new Radiological Effluent
Technical Specification (RETS), are still not operable.
Absence of these rsonitors places the plant in an LCO actica
statement requirir.g grab sample surveillance every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. A
failure to take the required sample resulted in a violation
identified during this period.
Station and corporate quality audits are complete, timely, and
thorough; corrective actions are adequate and timely; health
physics expertise is represented in both the onsite and
corporate QA organizations. The need for enhanced RCT training
was identified and is discussed below. The licensee's
radiological occurrence and personal contamination report
systems have been enhanced to ensure correction of internally
identified programmatic problems, including disciplinary
actions. Reportable events are properly identified and analyzed
and reported in a timely manner.
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There is consistent evidence of responsiveness to NRC concerns
as evidenced by establishment of an enhanced contractor rad / chem
technician training program, and prior planning as evidenced by
enhanced ALARA pre-job reviews and continued effectiveness of
recirculation system decontaminations. In response to an NRC
observed weakness concerning sample collection and handling
practices, licensee management discussed the matter with all
applicable personnel and agreed to increase supervisory
oversight of these activities; the licensee also committed to
make hardware changes to decrease difficulty in sampling the
river discharge tank which contributed to the problem.
Licensee staffing remains relatively strong, although the plant
Radiation Protection Manager (RPM) was transferred to the
licensee's corporate organization and replaced as Rad Chem
Supervisor by the former plant chemist. This and other '
organizational changes during this assessment period have
resulted in three intervening management positions between the
RPM and the Plant Manager. This organizational structure could
hinder communication of radiation protection concerns from the
RPM to upper level management. Key positions are filled on a
priority basis, staffing is ample, and responsibilities are
well defined. Program support was increased with the addition
of a laboratory foreman to direct laboratory activities, two
chemistry coordinators, ALARA health physicists, and an ALARA
planner. During recent outages, the licensee has required
minimal use of contract radiation protection technicians.
There is minimal turnover in the rad / chem department; position
vacancies develop mainly from promotions.
RCT training has been generally satisfactory; although weaknesses
in sample collection and handling practices on the part of two
RCTs were observed during a confirmatory measurements inspection.
The licensee was already in the process of improving RCT training
with development of an OJT Training Manual requiring demonstra-
tion of proficiency in an extensive list of required chemistry
and radiochemistry analyses. The licensee also plans to increase
annual RCT refresher training from one to two weeks. However,
the licensee's long standing policy of rotating chemistry and
health physics assignments could limit RCT proficiency in the
. laboratory. Retraining in radiation protection matters has
been enhanced in response to an internal QA audit finding. The
enhancement includes more extensive classroom presentation of
theory, and routinely conducted " tailgate" sessions where
current radiological plant conditions, changes to procedures
and policies, and industry-wide radiological occurrences are
discussed. Also, the training program for contract technicians
has been enhanced by inclusion of more extensive training of
plant procedures and policies. The training and qualification
program contributes to an adequate understanding of work and
adherence to procedures.
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The licensee's approach to radiological protection issues has
been sound in most cases. For instance, an ongoing contamina-
tion control problem during control rod reworking is being
resolved by construction of a new facility designed specifically.
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for this' work. Also, storage areas, ventilation, shielding, and
work / transfer area separation has improved, and a new tool and
equipment decontamination area, now operational, should minimize
recurrence of previous problems.
' Effectiveness of the ALARA program has continued to improve
during this assessment period. Increased ALARA awareness by
the. stat.fon' staff, periodic meetings with the maintenance
. department, addition of appropriate manpower to support the
ALARA organization, and pervasive management support have
resulted in more extensive pre-job' planning and post-job
reviews. A continuing contamination reduction and control
program has.been enhanced by construction of a tool and equip-
ment decontamination facility, and redesign of the control
rod drive maintenance facility.
Total worker doses during this assessment period, about 770
person-rems per. unit in 1984 and estimated to be about 550
person-rems per unit for 1985, represent significant decreases
(50 to 70 percent) over the licensee's annual average doses
over the last five years, and are 30 to 50 percent below the
average of U.-S. boiling water reactors.
Licensee implementation of 10 CFR 20.311 and 10-CFR 61
requirements for classifying and shipping solid radwaste has
been satisfactory except for minor, easily corrected discrep-
ancies on some manifests. However, completion of procedure
revisions to reflect current practices has been somewhat slow.
Liquid and gaseous radwaste effluents continued in the average
range for U. S. boiling water reactors with a slight downward
trend in liquid effluent owing to improved waste treatroent
techniques. However, repeated occurrence of minor errors and
omissions in the semiannual effluent reports indicated a need
for better review before publication.
. The laboratory QC' program -in chemistry was generally acceptable.
Overall,' laboratory equipment was reasonably well maintained and
adequate to perform necessary analyses. -However, continued
attention is needed in QC to-improve RCT performance. Approxi-
mately 18 percent of 1984 RCT analyses of vendor supplied blind
check samples had to be repeated to meet acceptance criteria.
This failure rate may reflect the long intervals between
successive laboratory assignments for individual RCTs. Improve-
ments are also,needed in the trending of counting room instrument
performance. The licensee's current practice of plotting monthly
average rather than daily QC data is not conducive to timely
recognition of trends in instrument performance.
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The station continued to perform satisfactorily in confirmatory
measurements with 36 agreements out of 39 comparisons during
1984 and 38 agreements out of 40 comparisons during 1985. The
three disagreements during 1984 were resolved after the licensee
recalibrated his gas geometry for effluent samples. A Sr-89
disagreement in the 1984 liquid waste sample resulted primarily
because the sample was not sent to the licensee contractor for
analysis in a timely manner, resulting in decay of Sr-89 through
several half-lives before analysis was performed. The radio-
logical environmental monitoring program (REMP) appears well
implemented, largely under contract. No problems were noted in
the operability or calibration of the environs stations or the
contractor's QC program. Only one minor anomalous result
(slightly elevated gross beta activity in the Spray Canal
Blowdown) was observed and was found to result from a con-
taminated container. However, management oversight of the REMP,
primarily in the corporate office, has been weak with continuing
discrepancies noted for nonroutine reporting levels for fish,
milk, and surface water. Following a special inspection at the
corporate office, the licensee agreed to provide closer manage-
ment oversight of the program and to resolve the discrepancies
between the various documents describing the REMP.
The station was in the process of developing and implementing a
BWR Water Chemical Program in response to corporate management
directives. Reasonable progress has been made in identifying
needed modifications to process instrumentation with contracts
scheduled to be let in the fall of 1985. Revision of analytical
procedures for this program was also in progress and the licensee
had committed to implement standards, in accordance with the BWR
Owners Group guidelines, for chlorides, pH, conductivity, and
solids. These standards were considerably more restrictive than
previous standards.
2. Conclusion
The licensee is rated Category 1 in radiation protection, but .
is rated Category 2 in chemistry, radwaste and environmental
monitoring. The licensee's performance in reducing the plant
radiation environment and in the substantial downward trend in
worker doses reflect SALP 1 performance in the area of radiation
protection. The overall rating for this area is Salp 2.
3. Board Recommendations
None.
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C. Maintenance / Modifications
1. Analysis
The resident and regional inspectors routinely inspected the
licensee's activities in this area, concentrating on implemen-
tation of procedures and design modifications.
In addition, a special inspection was performed by Region based
inspectors to determine the reasons for several faulty plant
modifications which were identified by the resident inspectors
during a major maintenance and refueling outage for Unit 1 at
the beginning of the assessment period. The special inspection
identified one violation with four examples:
Severity Level IV - Failure to adequately control design
changes (254/85002-01; 265/85002-01).
The specific examples involved the improper installation of
jumpers in the standby gas treatment system (SBGTS) resulting
in the system being declared inoperable due to the failure of
the electrical heaters; failure to adequately analyze a piping
modification to the Unit 1 drain line resulting in a vibration
problem; improper installation of anti-hammer circuits for the
Unit 1 LPCI valves resulting in damaged valve stems; and the
improper installation of steam jet air ejector suction valves
in Unit I resulting in the system being inoperable.
Analysis of these events'by the NRC indicated a lack of adequate
design reviews, post-modification testing,- design analysis, and
in the case of the SBGTS, an inadequate procedure for temporary
modifications. These problems were indicative of weaknesses in
. management involvement and training in the design change and
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modification process. Because of the significance of the items,
an Enforcement Conference was held with the licensee on March 15,
1985 in Region III to discuss the violation and licensee
corrective actions. Based upon the licensee's presentation,
previous enforcement history, and relative safety significance
of the individual violations, no escalated enforcement action
was taken by the NRC.
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This was the only violation identified in the Maintenance /
Modification area during this evaluation period. This is a
significant improvement over the six violations identified
during the previous evaluation period.
Significant Regional inspection effort was dedicated to examine
the Quad Cities Inservice Inspection Program. For the areas
examined, the inspectors determined that the management control
systems were effective in that activities had received prior
planning and priorities have been assigned. Policies were
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adequately stated and generally understood. The licensee's
actions in response to NRC initiatives indicated they understood
the issues and their reviews were generally timely, thorough,
with technically sound conservative solutions. Records and
calculations were found to be generally complete, well
maintained, and available. The records also indicate that
equipment and material certifications were current and complete,
and personnel were properly trained and certified. The approach
used to evaluate and analyze piping systems and supports was
generally conservative, technically sound, and thorough. Audits
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were generally complete, timely, and thorough. Observations
indicate personnel have an adequate understanding of work
practices and that procedures were adhered to. Discussions with
personnel indicated they were knowledgeable in their job.
As with all plants, the licensee was required to complete
environmental qualifications by November 30, 1985. The
licensee aggressively worked to complete Environmental
Qualification Modifications on required equipment. Several
small planned outages were accomplished in order to comply with
the dead line. All work was performed in a thorough and
professional manner and management maintained effective control
throughout the process.
As noted earlier, Unit 1 conducted a major maintenance and
refueling outage at the beginning of the refueling outage for
the work to be performed. There was evidence of prior planning
and daily managenent meetings were conducted to ensure proper
priorization and resolution of issues. Maintenance activities
generally were acceptable. However, the resident inspectors
identified several concerns with modification which led to the
special inspection and violation discussed earlier.
Unit 2 also underwent a major maintenance and refueling outage
during the assessment period. There was consistent evidence of
prior planning and assignment of priorities. As with Unit 1,
daily management meetings were held to ensure that activities
were prcperly controlled and to ensure timely resolution to all
technical issues. Adequate staffing levels were maintained to
minimize the amount of overtime required. Contrary to Unit 1,
maintenance activities were well controlled and no modification
concerns were identified indicating the licensee learned from
the experience and improved its performance. The quality of
work performed is evidenced by the smooth return to operation
(ahead of schedule) and the continued uninterrupted operation
of Unit 2 throughout the remainder of the assessment period.
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The licensee has continued to improve throughout the assessment
period because of increased management attention and the
aggressive attitude.of the maintenance staff. Maintenance
order backlogs and overtime have been well controlled. The
condition of plant equipment was consistently monitored and
trending was performed for preventive as well as corrective
maintenance to ensure continued safe operation.
Three LERs were issued as a result of personnel error in the
maintenance area and two were issued concerning modifications.
The safety. significance of the maintenance errors (one caused
by contractors) was not severe and the licensee took prompt and
effective corrective actions. The modification errors were
addressed by regional inspectors as noted above.
2. Conclusion
The licensee is rated Category 2 in this area. The
maintenance / modifications area has improved from the last SALP
rating, but problems continue in the area of modifications.
3. Board Recommendations
None
D. Surveillance and service Testing
1. Analysis
During the assessment period, the resident and regional
inspectors routinely inspected this area, concentrating on
implementation of procedures'. Six violations were identified:
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a. Severity Lewl IV - Two safety-related pressure switches
which provide for a fail safe damper operation were not
calibrated as a result of not being on the safety-related
calibration list (254/84011-01; 265/84010-02).
b. Severity Level V - Failure to provide adequate
administrative instructions, detailed technical
- instructions, or test result evaluation directions to
properly implement the pump and valve inservice test
program under Section XI of the ASME Code (254/85009-01;
265/85010-01).
c. Severity Level 1 - Failure to control a field change
with control measures commensurate with those applied to
the original design (265/85018-05).
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d. Severity Level V - Failure to perform local leak rate
tests on a flange since its original installation
(265/84007-02).
e. Severity Level IV - Failure to measure the leakage rate
of a flange before its repair (265/84007/-01).
f. Severity Level V - Inappropriate written procedures;
numerous examples in which the instructions or the data
sheets were inadequate for performing the required test
(265/85023-01).
This is an increase from the one violation identified in the
previous assessment period. With regards to item a, the
licensee subsequently identified eight more pressure switches
in a similar condition. The corrective action was prompt and
effective as evidenced by the lack of subsequent repetition.
This item is not considered a significant problem.
With one exception (item b above), the licensee implemented an
inservice testing progra'n and was conducting pump and valve
inservice tests in accordance with appropriate schedule and
approved test procedures. Thus, this was considered an isolated
instance and not indicative of a programmtic breakdown.
Item c identified the existance of a field change that had been
installed prior to the updated Quality Assurance program. It
was noted that the current program would not have permitted the
field change. However, the Violation identified the need to
review past practices to ensure complete compliance with newer
requirements.
Items d and e were identified during an inspection of the Unit
2 Containment Integrated Leak Rate Test (CILRT). These items
were considered exceptions in an otherwise acceptable program.
Violation f, and other problems identified during the startup
core performance testing inspections appear to be due to an
inadequate procedure review process. Improvements are needed
with regards to the thoroughness of reviews - specifically, to
correct procedural deficiencies and to maintain procedures to
reflect current methodology. Management involvement and
control in assuring quality of written procedures should be
increased. Also, training for the personnel performing
procedure reviews should be improved.
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Significant Regional Inspection effort was dedicated to the
review of the Inservice Testing and Inservice Inspection
programs. The licensee was noted to have an excellent vibration
program, separate from inservice testing requirements,
implemented by the plant maintenance department. The program
included monthly measurements of both motor and pump vibrations;
horizontal, vertical, and axial measurements were taken using
appropriate equipment and techniques; data was logged such that
trends could be observed; and trends were evaluated by a well
trained, competent individual in the vibration area. The
licensee cited several examples where the testing and data
evaluation was used successfully for the early identification of
equipment degradation. Maintenance was scheduled and corrective
action taken to avert more significant damage. The licensee also
cited an additional benefit in that suspected problems have been
confirmed not to exist by vibration tests, thereby preventing the
need for more extensive preventive maintenance, troubleshooting,
or equipment outage.
In regards to valve surveillance testing, Motor Operated Valve
(MOV) current trace techniques have been under consideration to
monitor valve condition. In addition, maintenance procedures
are currently under development for " environmentally qualified"
valves used in harsh environments; however, no proceduralized,
formal preventive maintenance program has been in effect for.
. valves. The licensee meets the code requirements for a M0V
surveillance and has preventive maintenance procedures under
development, no violations were identified. However, a review
of licensee event reports for this SALP period indicates a
number of valve failures that may have been prevented by a more
effective preventive maintenance program.
One LER was issued ccncerning a missed surveillance found
during a supervisory review. The safety significance of the
missed surveillance was nominal and the performance in this
area has improved over previous assessment periods.
With the exceptions neted above, surveillance procedures were
well stated, and defined and were strictly adhered to. The
management control -systems were effective in that activities
had received prior planning and priorities had been assigned.
Surveillance records were found to be complete, well maintained,
and readily available for review. Required reports and asso-
ciated analysis were submitted within the line constraint
imposed. In the case involving a report submitted concerning
excessive local leak rate test results, the analysis section was
considered excellent by the Region III staff. Response to NRC
initiatives, inspector-identified concerns and safety issues
were timely, technically sound, and thorough in almost all cases.
An example of thorough resolution was the licensee's prompt
actions pertaining to water in containment pressure sensing
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lines identified during the Unit 2 CILRT. The licensee inspected
all containment pressure sensing lines for the presenese of water
prior to Unit startup. Events and deviations are promptly and
completely reported. Staffing training and qualification is
adequate to minimize ov(rtime and maintain the surveillance
program up to date.
2. Conclusion
The licensee is rated Category 2 in this area. This is a decline
from the last SALP period based on the number and nature of the
violations identified.
3. Board Recommendations
None.
E. Fire Protection / Housekeeping
1. Analysis
Throughout the assessment period, the resident inspectors have
observed the implementation of the licensee program in areas of
fire protection and housekeeping.
- At the start of the assessment period the licensee was involved
in a refueling outage on Unit 1. Also, during the assessment
period the licensee completed a major maintenance and refueling
outage on Unit 2. Observations of general site conditions
throughout the assessment period indicated that an already
effective housekeeping program as noted in SALP 4 had improved.
This is a direct result of management's involvement and
attention in this area.
The resident inspectors also observed that routine fire preven-
tion is practiced at the facility. During this assessment
period, one violation was identified as follows:
Severity Level V - Inadequate fire barrier.
(254/84011-06; 265/84010-06)
This was considered an isolated occurrence and not indicative
of programmatic weaknesses. The licensee has a very effective
fire prevention program as a result of management's aggressive
attitude coupled with the cooperation of the plant staff.
Enhancements to the program include increased staffing with
the addition of a fire protection engineer, the expansion of
l training for fire brigade members and contractor personnel, and
the development and implementation of a maintenance history and
trending program for fire protection equipment.
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With regard to final implementation of the Fire Protection
requirements of 10 CFR 50, Appendix R as they apply to Quad
Cities, there are a number of outstanding issues. These issues
are the subject of ongoing discussion between the licensee and
the NRC.
2. Conclusion
The licensee is rated Category 2 in this area due to the many
open issues of Appendix R.
3. Board Recommendations
The board noted that shortly after the close of the SALP 5
period a fire protection inspection was conducted which
indicated potentially significant weaknesses in the implemen-
tation of existing fire protection requirements. These
weaknesses, some of which were identified by the licensee, are
currently under review by the licensee in an effort to effect
programmatic improvements.
1. Analysis
Four inspections were conducted during the period to evaluate
the following aspects of the licensee's emergency preparedness
program: emergency detection and classification; protective
action decision making; emergency notifications; emergency
communications systems; shift augmentation provisions; emergency
preparedness training; independent audits of emergency prepared-
ness; and implementation of changes to the emergency preparedness
program. Two inspections dealt with observations of annual
exercises.
One violation was identified during these inspections:
Severity Level V - Failure to complete required training
before assigning two persons to key positions in the
onsite emergency organization (254/85010-01; 265/85011-01).
The licensee's corrective actions were thorough and were
scheduled to be completed in a timely manner. The violation
was not indicative of a programmatic breakdown in the scheduling
of emergency preparedness training.
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Management involvement and control in assuring quality generally
remained positive towards improving the emergency preparedness
program, as had been apparent during the previous SALP period.
There are few long standing staff concerns regarding the
licensee's emergency preparedness program. Required corrective
actions to staff concerns were technically sound, thorough,
timely, and demonstrated a clear understanding of the issues.
However, as evident from repeat observations made during the
last two annual exercises, less attention had been given towards
implementing suggested improvements, such as recordkeeping in
some emergency response facilities. Independent audits of the
program were adequate in scope and depth. An effective system
had been implemented for tracking and documenting corrective
measures on action items identified during internal drills, and
exercises. Audit and tracking system records were complete,
well maintained, and readily available. Administrative proce-
dures were adhered to regarding the preparation, review, and
distribution of the emergency plan and implementing procedures.
Records associated with actual Emergency Plan activations
through June 1985 indicated that all situations had been
properly classified. The NRC and the States of Illinois and
Iowa were initially notified of these emergency declarations in
a timely manner.
The licensee has maintained a prioritized roster of adequate
numbers of personnel to fill well-defined, key positions in the
emergency organization. With the exception of the two persons
involved in the aforementioned violation, all persons had
completed the required training prior to being assigned to their
emergency positions. Semiannual, off-hours drills have been
conducted to successfully demonstrate the capability to augment
on shift personnel in a timely manner.
Proficiency of persons assigned to the onsite emergency
organization has largely been mairtained through annual
required reading of relevant procedures and by participation
in drills and exercises. However, walkthroughs at the beginning
of the assessment period with sixteen individuals assigned
emergency duties indicated that most had an inadequate knowledge
of some training program learning objectives stated in the
Emergency Plan. The licensee has committed to adding the
Training Supervisor to the Onsite Review Committee to better
ensure that persons newly assigned to emergency positions will
first have completed required training. Position-specific
lesson plans were being completed by corporate staff to improve
the training given annually to persons ir. the onsite emergency
organization.
21
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2. Conclusion
The licensee is rated Category 1 in this area, with the trend
essentially the same throughout the period.
3. Board Recommendations
None.
G. Security
1. Analysis
-Three inspections were conducted by ragion-based security
specialists during the assessment period. Periodic inspections
of limited scope were also conducted by the resident inspectors.
One violation was identified during the inspection effort in
September 1984 as follows:
Severity Level III - Failure to adequately control access
to a vital area. (214/84020-01; 265/84018-01)
The civil penalty for tFis violation was totally mitigated
because of the licenser's self-identification and prompt
reporting of the event, prompt and extensive corrective
actions, and the past excellent performance in the area of
security. No violations were cited during the previous SALP
period.
The security program continues to be effectively and
efficiently managed by the licensee and tha contract security
management cadre. Liaison between those management elements
appears effective and responsive to resolving issues.
Procedural guidar.ce is detailed and censistently applied.
Security awareness of the plant workforce appears high.
The licensee is consistently responsive to NRC concerns. One
inspection noted concerns about timely maintenarice for certain
security equipment and limited space for security training
administrator functions. Both concerns were totally resolved
in a timely manner. Additional personnel resources and new
equipment purchases resolved the maintenance support concern
and additional office space was constructed for security force
use. Concerns and observations received the same exceptionally
high level of management attention normally associated with
violations. The security management is responsive to all
findings that can strengthen their security program, rather
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than concentrating on just minimum compliance required by the
security plan. There are no unresolved or open items pertaining
to security operations.
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The staffing level for the contract security force is adequate
and overtime is closely monitored and controlled. Day-to-day ,
supervision of the security shift is strong and assures '
consistent performance. A contract security officer has been
assigned, on a full-time basis, to monitor and coordinate
maintenance support for security-related equipment. Recent
emphasis has been placed on safeguards contingency event
training. This emphasis should continue into the next
assessment period.
Corporate security department support has been excellent during
the assessment period. A corporate Assistant Nuclear Security
Administrator position has been established (ANSA) to improve
coordination / liaison of site security acti+.ies and security
licensing issues. The ANSA closely monitor: inspection results
and licensing issues. Effective lines of communication exist
among the site, corporate, and NRC Region III security section.
The previous SALP report noted that corporate security involve-
ment should continue to be increased to relay analyses of
security deficiencies and other issues from other licensee
sites in order that similar deficiencies are prevented in the
Quad Cities security program. This objective has been met by
addition of the ANSA position and the results have been
effective. This high level of corporate security support and
direction should continue.
Licensee reports of Safeguards events are submitted in a timely
manner and in sufficient detail to allow analysis to be
performed. Corrective actions are effective and technically
sound. In the early part of the assessment period, unplanned
security computer outages were a concern. The reports of those
outages represented about 60% of the total. When the scope of
this problem was identified by the licensee significant
corrective action was taken and the issue was resolved. In
the last five months of the assessment period only one outage
was reported. The remaining events did not represent an unusual
or abnormal amount or type of Security Event Reports.
Senior site management has actively supported the security
program through general support of recurity budget items. The
. security computer system was signif cantly upgraded during this
assessment period, all x-ray and ext.losive detector units were
replaced with high grade state-of-the-art equipment, and
several closed circuit television cameras have been replaced.
An alternate alarm monitoring system has been installed and is
undergoing testing. Future security budget plans include
replacement equipment proposals.
In summary, even though one significant violation occurred,
this licensee has demonstrcted consistent performance at a
high level of efficiency, c ontinues to strengthen the security
program by upgrading critical security equipment, and is
responsive to NRC concerns and comments.
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2. Conclusion
The licensee is rated Category 1 in this area. This is the
same rating as in the previous SALP period.
~
3. Board Recommendations
None.
H. Refueling
1. Analysis
Evaluation of this functional area is based on portions of
eight inspections by the resident inspector and one inspection
by a Region III specialist. No significant areas of concern
and no violations were identified in this area during the
assessment period. This is a result of management's involvement
and attention in this area.
The inspection activities consisted of reviewing refueling
equipmrnt, test and check out procedures, fuel handling
procedt.res, refueling related surveillances, and results of
these completed procedures and surveillances. No core
alterations were conducted during the inspection period.
However, work performed during the assessment period included:
removal of spent fuel storage racks and their replacement with
new high density storage racks, removal of old refueling
bridges and replacement with new refueling bridges, as well
as operations related to a refueling outage.
The resident inspectors noted that refueling operations were
conducted very well from plant shutdown to post refueling
startup. It should be noted that no handling problems
occurred and no medical emergencies or overexposures cccurred.
Documentation of completed refueling operations verified that
all work was conducted satisfactorily and within the time frame
required.
-There is consistent evidence of prior planning and assignment
of priorities. Procedures and policies are well stated and
strictly adhered to. Staffing is adequate with positions and
responsibilities clearly delineated.
2. Conclusion
'
The licensee is rated a Category 1 in this area. The licensee
has maintained the same high level of performance as in a
previous SALP assessment.
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3. Board Recommendations
None.
I. Quality Programs and Administrative Controls
1. Analysis
l
This functional area was examined during two regional inspections
within the assessment period. The resident inspectors also
routinely made observations in this area. These inspections
were performed to determine the adequacy of the procurement
program implementation, the adequacy of the offsite review
function and support staff activities, and the adequacy of the
audit, nonroutine reporting, and test and measuring equipment
activities. One of the Regional inspections was a special
inspection of the CECO procurement program and its implementation
at all operating sites.
During these inspections, three violations were disclosed:
a. Severity Level IV - Nine examples of failure to follow
procedures (254/84015-07; 265/84013-07).
b. Severity Level V - Two examples of failure to perform
adequate suitability of application evaluations
(254/84015-09; 265/84013-09).
c. Severity Level V - Failure to provide prcper storage
protection for safety-related valves (254/85017-04;
265/85019-03).
With respect to the first violation, the examples involved
purchase orders failing to impose requirements specified by the
procurement program. While no single example had major safety
significance, collectively they indicate repeated failure to
implement programmatic requirements indicating the need for
added management attention in this area.
With egards to the second violation, one example led to the
use of a breaker not-seismically or environmentally qualified
in a safety-related application. The licensee immediately
replaced the breaker with a qualified breaker. There was some
safety significance to this example since the seismic and
environmental qualification of the breaker was indeterminate.
The second example involved the safety-related use of a 3" gate
valve not meeting the original specifications. The evaluation
performed to justify its use was not accomplished in accordance
with the design change process. This example was of minor
safety significance. The licensee has implemented procedure
changes which should preclude the recurrence of the violations.
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The third violation was identified during routine resident
inspections of storage facilities. It was considered an
isolated occurrence and not indicative of a progammatic
breakdown.
In addition to the Quad Cities specific items addressed above,
six other items of concern were disclosed relating to the CECO
corporate procurement program during the special inspection
noted above. - These items were of concern in that they
represented programmatic weaknesses that provided a potential
for the procurement, installation, and use of unqualified
items. The licensee's proposed actions related to these items
appear.to mitigate some of these weaknesses; however, further
NRC review is required before these items can be dispositioned.
Overall, the procurement area was found to be controlled by
sometimes poorly stated programs containing some weaknesses.
Weaknesses in program implementation indicated the lack of
management attention in the procurement area and the need for
more effective staff training. The licensee has initiated
corrective action in this area during the SALP 'eriod.
The licensee's recent reorganization was designed to strengthen
administrative controls and ensure continued compliance with
NRC requirements and commitments. Specifically, a compliance
coordinator position was established. This position is site
criented but receives corporate support. Also, a realignment
'
of all technical and administrative services under a more
senior management position and the assignment of maintenance
and operation to an equally senior management level should
provide for more positive control of plant administrative
activities. The aggressive attitude demonstrated by enagement
should ensure that decisions are made at an adequat .avel and
that corrective actions are taken promptly with souna technical
solutions.
The licensee has increased the staffing of the Quality Control
(QC) group and has a policy of rotating maintenance personnel
through QC to provide a fresh view and to also provide
maintenance with a greater understanding of the quality
program.
While licensee event reports (LER) specifically related to this
area are not reported as such, LERs from other rated areas must
also be factored into Quality Programs and Administrative
Control, LERs are almost always well written, technically
< accurate and thorough, with only a few minor discrepancies
noted throughout the rating period. While the overall number
of LERs was reduced, the number of personnel errors was not.
Additional management attention in this area is warranted.
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2. Conclusion
The licensee is rated a Category 2 in this area.
3. Board Recommendations
None.
J.
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Licensing Activities
1. Analysis
a. Methodology
The basis for this appraisal was the licensee's performance
in support of licensing actions that were either completed
or had a significant level of activity during the current
rating period. These actions, consisting of amendment
requests, exemption requests, responses to generic letters,
TMI items, and other actions, include the following specific
h
items:
(1) Multiplant Action Items (MPAs) completed or having a
significant level of review action completed include:
-
NUREG-0737 Item (12 items completed for both
units)
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NUREG-0737 Technical Specifications
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NUREG-0737 Supplement 1 items'-
Emergency Facilities, station
.
SPOS in progress review, station
DCRDR in progress review, station
DCRDR Audit Review completed for
station and Report issued
-
Control of Heavy Loads (C-10), Units 1 and 2,
complete
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Appendix I (RETS) Technical Specification
(A-02), Units'1 and 2, complete
-
Environmental Qualifications Exemption (B-60),
Units 1 and 2, complete
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Licensee's Environmental Qualifications Program,
Units 1 and 2, complete
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Mark I Containment LTP review completed for
Units 1 and 2
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Inservice Inspection Program review for Units 1
and 2, nearly complete
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Inservice Testing (Pumps and Valves) Program
review for Units 1 and 2, nearly completed
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Hydrogen Recombiner requirements for Units 1
and 2, in review
(2) Plant Specific Action Items completed or having a
significant level of review include:
-
IGSCC Inspection and Repair program for Unit 1
(Cycle 9), complete
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IGSCC Inspection and Repair program for Unit 2
(Cycle 8), complete
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Environmental Qualification Schedular Extension
for Units 1 and 2, complete
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Environmental Qualification Review, SE, for
Units 1 and 2, complete
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Exemption from ILRT requirement Unit 2, complete
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Process Control Program review Units 1 and 2,
complete
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Administrative Control Technical Specification
Changes, Units 1 and 2, in review
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Appendix J Exemption Requests, Units 1 and 2,
complete
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Containment Pressure Set-Point and MSIV surveil-
lance Technical Specification changes, Units 1
and 2, review complete
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Increased LHGR Technical Specification limit,
. Unit 2, complete
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Cycle 8 operation Technical Specification
revisions, Unit 2, complete
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Hafnium Control Rod use, Technical Specification
changes, Unit 2, complete
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Cycle 9 operation Technical Specification
revision, Unit 1, complete
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b. Management Involvement and Control in Assuring Quality
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Op: Commonwealth Edison management has an awareness of the
.~' various licensing issues by virtue of its extensive i
@ experience in the industry, inhouse technical expertise
'
and active participation in Owners Group and professional
~ organization activities. Commonwealth management takes
actions in a timely manner to ensure safety issues are
properly addressed. Examples of this attribute in'this
report period are the responses to our need for effective
'
-action and/or information regarding their electric power
transient event May 7, 1985, the RHR Pump operability
issues of July-1985, and the 125 VDC power supply
' deficiencies.
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c. gApproach to Resolution of Technical Issues from a
y.~ Safety Standpoint
~" Commonwealth's large and well qualified engineering staff,
, -in concert with an astbte licensing staff, assures that
Is most engineering wcrk, e%her done inhouse or performed
~
under its 'direction by contractors, adequately and timely
addresses complex technic'al issues.
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- During this report period,- satisfactory resolution and
L ,j e , completion of the following major _ programs was accomplished:
'
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Control of Heavy Loads (C-10) Appendix I (A-02)
4
Environmental Qualification of Equipment (B-60) Mark I
'
Long Term Containment Program Implementation (0-01)
i The resolution of the above-stated work demonstrates that
'
f the licensee's staff understands complex technical' issues,
~y ~
not only in terms of their technical nature but also in'
. terms of plant safety, plant operation, and' responsiveness
to regulatory concerns.
'
During the report period severalLissues were identified
for which prompt and effective action was appropriate. In
each case, the licensee promptly evaluated the problem and
.
" took action to provide interim repairs or other appro-
/ priate actions to satisfactorily resolve the issue from a
a safet;; standpoint. The licensee's actions in this case
C , demonstrated sound understanding of and ability to deal
y effectively with complex technical problems. The
- i licensee's proposed program for long-term solution to
'
IGSCC concerns for the Quad Cities Units has yet to be
"
fully evaluated in that a specific plan of action has not
i been proposed. The concept, as presented in their meeting
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with us on July 23, 1985, is a considerable departure from
the conventional aoproach, but demonstrates both careful
technical considerations and originality of approach to
that concern.
d. Responsiveness to NRC Initiatives
Open and effective communication channels exist between
the NRC and Commonwealth Edison licensing staffs.
Effective dialogue between the staffs promote prompt and
technically sound responses to NRC initiatives. The
licensee meets all established commitment dates or
provides a written submittal explaining the circumstances
and establishes a new firm date. Conference calls with
the staff are promptly established and include appropriate
engineering, plant and/or contractor personnel. The
Commonwealth Nuclear Licensing Administrator and/or his
management in almost all cases promptly and effectively
resolve issues.
The Station or Corporate office have rarely if ever failed
to accommodate a NRC-initiated program (such as a special
study, evaluative program, or survey) being conducted by
or for NRC, even where such accommodation is clearly not
obligatory. The Station characteristically makes available
their most knowledgeable people to assist the NRC staff
and/or contractor in such activities.
e. Housekeeping
The NRR Project Manager has had a number of occasions to
observe housekeeping conditions at Quad Cities Station.
The most recent was a site visit October 9-12, 1984,
related to resolution of USI A-45, Decay Heat Removal
Capability. Because of the nature of this visit, sensitive
areas of the plant were visited and observed. During this
visit, areas in the reactor building at all levels were
visited, as was the control room, turbine building at upper
and lower levels, machine shop, administrative offices,
main meeting room, and connecting passageways. Also visited
were the auxiliary electric rooms and associated cable
tunnels under the control room, areas of particular sensi-
tivity from the fire protection standpoint.
It was noted that all the areas visited were clean and
free of trash, with little or no stored or transient
combustibles evident beyond operational requirements. The
control room was clean, orderly, and transactions were
business-like. There was no evidence of food or drink or
reading material not related to plant operation.
Housekeeping at the Station is generally very good.
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f. Fire Protection
Nearly all plant modifications resulting from the NRC
staff fire protection review have been completed, and
exemptions were issued where appropriate.
In late 1983, NRC issued a clarification of the requirements
of Appendix R. In response to the NRC clarification, the
licensee then initiated an independent review of their fire
protection program. This resulted in additional changes in
their fire protection program, and additional exemptions
were requested beyond those resulting from the original NRC
fire protection review. These are currently under NRC
staff review.
2. Conclusion
An overall performance rating of Category 1 has been assigned
in the licensing area.
3. Board Recommendations
None.
.
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V. SUPPORTING DATA AND SUMMARIES
A. Licensee Activities
Units 1 and 2 engaged in routine power operation throughout most of
SALP 5. A major scheduled outage for plant refueling, modification,
maintenance, and inspection of recirculation piping pursuant to
Commission Order 7590-01 was in progress at the beginning of the
assessment period for Unit I and completed on August 16, 1984. A
similar outage began on March 17, 1985 and was completed on Juna 5,
1985 for Unit 2.
The remaining outages throughout the period are summarized below:
Unit 1
December 2 to 4, 1984 Repair recirculation suction
valve
May 7 to 17, 1985 Routine maintenance
May 30 to June 1, 1985 Routine maintenance
Unit 2
June 2 to 4, 1984 Repair Transformer 21
October 25 to 27, 1984 Replace CRD pursuant to CAL
December 21 to 29, 1984 Repair main transformer
January 16 to 22, 1985 Repair main condenser boot
June 15 to June 16, 1985 Repair EHC oil leak
Unit 1 scrammed seven times (three occurred while shutdown) and Unit
2 nine times (three occurred while shutdown). Two of the Unit 1
scrams and five of the Unit 2 scrams were attributed to equipment
malfunction and required minor maintenance prior to returning the
units to service. One of the Unit 2 scrams was caused by a hole in
the main condenser boot ar.d required an extended outage to replace
the boot. Two scrams occurred at power for Unit 1, which were
attributable to perscanel error, including contractors. While
shutdown, two scrams for Unit 1 and two scrams for Unit 2 were
attributed to personnel error. The remaining scram on Unit 2 was
caused by a procedural deficiency. Licensee management corrective
actions following these trips were reviewed by the resident
inspectors and found to be appropriate. The above personnel errors
were taken into account and factored into the licensee's Regulatory
Improvement Plan. In all cases, the plants responded as designed.
32
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.B. Inspection Activities
An Operational Team Inspection was conducted by Region III on
September 24-28, 1984 to assess overall licensee performance and
provide an indepth assessment of selected areas. including
operations. .The inspectors found the operations staff to be an
effective operating organization.
FEMA issued a' report addressing the emergency exercise, which
concluded that an adequate level of offsite radiological prepared-
ness-had been demonstrated-to protect the public in the event of a
radiological accident at the Quad Cities Nuclear Power Station.
Violation data for Quad Cities is presented in Table I which
includes inspection reports 84008 through 85026 for Unit 1 and
84007 through 85029 for Unit 2.
TABLE 1
INSPECTION ACTIVITY AND ENFORCEMENT
No. of Violations in Each Severity Level
Functional Unit 1 Unit 2 Site
' Areas III IV V III IV V III IV V.
A. Plant Operations 1 1 1 1 1
B. Radiological Controls 1 1 1 1 1
C. Maintenance / Modifications 1 1 2
D. Surveillance and
Inservice Testing 1 1 1 4 1 4
E. Fire Protection 1 1 1
F. Emergency Preparedness 1 1 1
G. Security 1 1 1
H. Refueling
I. Quality Programe and
Administrative Cuatrols 1 2 1 2 1 2
J. Licensing Activi"o; _ _ _ _ _ _ _ _ _
TOTALS 2 3 6 1 6 10 2 6 10 l
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C. Investigations and Allegations Review
During a radiation protection inspection, reviews were made as followups
to inquiries from attorneys representing a former contractor employee who
claimed injuries while working at Quad Cities Station during the third
and ' fourth calendar quarters of 1983. No violations of regulatory
requirements were identified; the attorneys and the U. S. Representative
were so informed.
An inspection was also performed to investigate allegations
anonymously made by a formerly employed contract radiation
protection technician. No violations related to the allegations
were identified. Possible programmatic improvements were discussed
with licensee personnel. Since then, improvements in contract
radiation protection training, respiratory protective equipment
cleaning and handling, and radioactive materials handling have been
made by the licensee.
D. Escalated Enforcement Actions
A Civil Penalty in the amount of $50,000 was issued in 1985 for a
violation involving the Unit 1 operator not being at the Unit
Controls. Details are to be found in Inspection Report (254/84023).
E. Management Conferences Held During Appraisal Period
1. Confirmatory Action Letters (CAL)
A CAL was issued October 26, 1984 to confirm licensee action
regarding replacement of CRD 38-51 and resolution of concern
with operator at controls.
2. Management Conferences
a. September 7, 1984 (Glen Ellyn, Illinois)
Meeting to discuss licensee performance in regards to
their Regulatory Performance Improvement Plan (RPIP).
b. September 17, 1984 (Glen Ellyn, Illinois)
.
Management meeting to review Systematic Assessment of
Licensee Performance (SALP 4).
c. January 18, 1985 (Glen Ellyn, Illinois)
Meeting to discuss various items related to emergency
preparedness.
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d. March 7, 1985 (Glen Ellyn, Illinois)
Meeting to discuss licensee performance in regard to their
RPIP.
e. June 24,1985 (LaSalle County Station)
Meeting to discuss licensee performance in regard to their
RPIP.
f. July 16,1985 (Glen Ellyn, Illinois)
Meeting to discuss additional aspects of the licensee's
RPIP.
3. Enforcement Conferences
a. October 18, 1984 (Telephone)
Discussion to review the security event of September 1984
where the licensee failed to control access to a vital
area.
b. November 5, 1984 (Glen Ellyn, Illinois)
Meeting to discuss the Unit 2 event of October 25, 1984,
and the associated control room operations staff
activities. -
.
c. March 15, 1985 (Glen Ellyn, Illinois)
Meeting to discuss design control deficiencies.
F. Review of Licensee Event Reports and 10 CFR 21 Reports
1. Licensee Event Reports (LERs)
LERs issued during the 16 month Salp 5 period are presented
below:
Unit 1 Unit 2
LERs No. LERs No.
84-06 through 84-18 84-05 through 84-14
85-01 through 85-16 85-01 through 85-20
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Proximate Cause Code * Number During Salp 5
Personnel Error (A) 15
Design Deficiency (B) 5
Defective Manufacturing,
Construction / Installation (D) 2
Others (X) 37
TOTAL 59
- Proximate cause is the cause assigned by the licensee according
-to NUREG-1022, " Licensee Event Report System."
LERs were issued at a slower rate during the SALP 5 assessment
period than during SALP 4. The increase in personnel errors
was partly due to the increased reporting requirements
concerning scrams while shutdown and errors found in the
modifications area. Additional discussion on modification
problems is presented in Section IV.3. The reduction in
overall LERs is significant and, especially in the equipment
failure area, indicative of an improving trend.
The Office for Analysis and Evaluation of Operational Data
(AEOD) reviewed the LERs for this period and concluded that,
in general, these LERs are of acceptable quality. However,
they identified some minor deficiencies. A copy of the AE00
report has been provided to the licensee so that the specific
deficiencies noted can be corrected in future reports.
2. 10 CFR 21 Reports
No 10 CFR 21 reports were submitted during the assessment
period.
G. Licensing Actions
1. NRR Site and Corporate Office Visits
October 9-12, 1984 Site Visit on USIA-45, Ultimate Decay
Heat Removal Requirements.
January 28, 1985 Site Visit on USIA-45, Ultimate Decay
Heat Removal Requirements.
March 4, 1985 Meeting at Corporate Office on current
regulatory requirements for LWRs.
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April 12-13, 1985 Site Visit to get information on
Decontamination Study.
June 10-13, 1985 Site Visit for DCRDR Audit Review.
2. Commission Briefing
None.
3. Schedular Extension Granted
July 30, 1984 Equipment Qualification, Units 1 and 2.
4. Relief Granted
None.
5. Exemption Granted
July 6, 1984, certain requirements of Appendix J, Units 1 and
2.
6. License Amendments Issued
Unit 1
Amendment No. 88, issued June 6, 1984; Revised Technical
Specification on Time Delay Settings for HPCI and RCIC
actuation.
Amendment No. 89, issued June 19, 1984; Radiological Effluent
Technical Specifications (RETS) to satisfy Appendix I
requirements.
Amendment No. 90, issued August 2, 1984; Technical Specification
changes and additions for MAPLHGR limits; changes for newly
installed Analog Trip System; and changes for newly installed
Scram Discharge Systen.
Unit 2
Amendment No. 83, revised June 6, 1984; Revised Technical
Specification on Time Delay Settings for HPCI and RCIC
actuations.
Amendment No. 84, revised June 19, 1984; Radiological Effluent
Technical Specification (RETS) to satisfy Appendix I
requirements.
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Y _ ___ _ _ _ _ _ - _ - _ _ _ _ - _ - _ _ . _ -
-
o- ..
,
... -
.. ( ,
Amendment No. 85, issued February 25, 1985; Temporary increase
in LHGR limits to perr:it Barrier Fuel Ramp testing.
Amendment No.-86, issued May 30, 1985; new and extended MAPLHGR
limits; changes for newly installed Analog Trip System; and
changes for newly installed Scram Discharge System.
Amendment No. 87, issued May 30, 1985; Technical Specification
change to allow use of Hafnium control rod material.
7. Emergency / Exigent Technical Specification
Exigent Technical Specification on RHR Pump Operability
completed (but not-issued when licensee was able to restore
operability at the'last moment) for issuance July 30, 1985.
8. Orders Issued
June 12, 1984, Order confirming licensee commitments on
Emergency Response capability, Units 1 and 2.
9. NRR/ Licensee Management Conference
Conference in Bethesda on July 23, 1985 regarding Commonwealth
Edison's proposed alternative plan for IGSCC-susceptible pipe
replacement.
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