ML17262A140
| ML17262A140 | |
| Person / Time | |
|---|---|
| Site: | Ginna  |
| Issue date: | 09/05/1990 |
| From: | Mccabe E NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| To: | |
| Shared Package | |
| ML17262A139 | List: |
| References | |
| 50-244-90-12, NUDOCS 9009250222 | |
| Download: ML17262A140 (19) | |
See also: IR 05000244/1990012
Text
U.S.
NUCLEAR REGULATORY COMMISSION
REGION I
Report
No:
50-244/90-12
License
No.
Licensee:
'ochester
Gas
and Electric Corporation
(RG&E)
Facility:
Dates:
Inspectors:
Approved by:
R.
E. Ginna Nuclear
Power Plant
July
17 through August 27,
1990
T. A. Moslak, Senior Resident
Inspector,
Ginna
N.
S. Perry,
Resident
Inspector,
Ginna
R. A. McBre t
eactor Engineer,
C.
McCabe,
ief, Reactor
Projects
Section
38
Date
OVERVIEW
PLANT OPERATIONS:
The plant operated
stably at approximately full power!.
Operations
were conducted
in
-a professional
manner, with ap'propriate
management
attention
and involvement.
Overall, plant housekeeping
was, very good.
I
I
RADIOLOGICAL CONTROLS:
Routine observations
of radiological controls were
made
throughout the inspection period.
No significant weaknesses
were noted.
MAINTENANCE/SURVEILLANCE: Review of licensee
actions
concerning
the failure
of the Service Water
Pump
1D Motor indicated timely management
response
in per-
forming a comprehensive
engineeringr evaluation to identify the root cause of
the fai lure.
Additionally, prudent actions
were taken
by licensee
management
to upgrade
the materials
used for the motor rewind and perform additional testing
to assure
increased
motor reliability.
SECURITY:
Observations
of the implementation of site security procedures
for
entry of motor vehicles into the protected
area identified no
weaknesses'MERGENCY
PREPAREDNESS:
The licensee's
Emergency Operations Facility and Media
Center were found to be suitably equipped
and well maintained.
SAFETY ASSESSMENT/
UALITY VERIFICATION:
An assessment
of independent
ver ifica-.
tion of maintenance
by the Nuclear Assurance
group provided useful
information
to plant management.
However,
no specific follow-up was requested
and
no formal
mechanism
was
used to follow-up the concerns identified.
9009250222
9005'05
ADOCK 05000244
TABLE OF
CONTENTS
1.
Plant Operations
(71707)
1. 1
Control
Room Observations.
'I
2.
Radiological
Control (71707)
3.
Maintenance/Surveillance
(62703, 61726,'3755,
92701).
PAGE
~
~
~
~
~
1
~
~
~
~
~
1
3. 1
Maintenance
Observations
.
3.2
Corrective Maintenance
Observations
3.2. 1
Pump
1D Motor Failu
3.3
Surveillance
Observations
3.4
Inservice Inspection
Summary Report..
4.
Securi ty (71707)
4. 1
Vehicle Access Control
5.
Engineering/Technical
Support
(71707,
92701)
1
~
~
~
~
2
re..
.....
.....
2
2
3
5
5
5
5.1
Unresolved
Item 50-244/90-09-02,
AOV-745 Isolation Signal
(Closed).
5.2
Unresolved
Item 50-244/89-04-02,
Major Modification Backlog
( Closed)
.,6
6.
'afety Assessment/equality
Verification (71707,
90712,
90713,
40500)..
6
6. 1
Self-Assessment
Effectiveness
6.2
Personnel
Safety.
6.3
Periodic
and Special
Reports.
6.4
Written Reports of Nonroutine Events..
6.5
Unresolved
Item 50-244/90-11-02,
Unclear
LER 90-008 (Closed)...
7.
TMI Action
Item Fol low.-up (92701)...
7.1
I.D.2.2 and I.D.2.3, Safety
Parameter
Display System...........
7.2
II.K.3.5.B, Reactor Coolant
Pump
(RCP) Trip
7.3
II.E.4. 1, Dedicated
7.4
II.D.3.4.3, Control
Room Habitability.
7.5
II.B.3.4, Post-accident
Sampling.
7.6
II.F. 1.2.C,
Containment
High Range Monitor...........,.........
6
7
7
7
8
8
8
8
8
8
9
1
d[
Table of Contents
PAGE
8.
Administrative (30703,
71707,
82701)
8.1
Licensee Activities.......
8.2
Emergency
Preparedness
~ .
8.3
Inspection
Hours
8.4
Exit Meetings ..
9
9
9
9
9
11
I
~
DETAILS
1.
Plant 0 erations
1.1
Control
Room Observations
The inspectors
found the
R.
E. Ginna Nuclear
Power Plant to be operated
safely
and in conformance with license
and regulatory requirements.
Control
room staffing w'as adequate
and operators
exercised
control
over access
to the control
room.
Operators
adhered
to approved pro-
cedures
and understood
the reasons
for lighted annunciators.
The
inspectors
reviewed control
room log books to obtain information con-
cerning trends
and activities,
and observed
recorder traces for ab-
normalities.
During normal work hours
and
on backshifts,
accessible
areas
of the plant were toured
and plant conditions
and activities
were observed with no inadequacies
identified.
The inspectors verified
compliance with plant technical specifications
and audited
selected
safety-related
tagouts.
Among the documents
reviewed included Ginna Station
Event Reports
(A-25. 1) Nos.
90-74 through 90-83.
Each Ginna Station
Event Report was reviewed to ensure plant personnel
took appropriate
corrective action
and observed
the appropriate
Limit-
ing Conditions for Operation.
No inadequacies
were identified.
2.
Radiolo ical Controls
The resident
inspectors periodically confirmed that radiation work permits
were effectively implemented,
dosimetry
was correctly worn in controlled
areas
and dosimeter
readings
were accurately
recorded,
access
to high radi-
ation areas
was adequately
controlled,
and postings
and labeling were in
compliance with procedures
and regulations.
Through observations
of ongoing
activities
and discussions
with plant personnel,
the inspectors
concluded
that radiological controls were conscientiously
implemented.
3.
Maintenance/Surveillance
3. 1
Maintenance
Observations
The inspectors
observed
portions of various safety-related
maintenance
activities to assess
whether redundant
components
were operable,
ac-
tivities did not violate limiting conditions for operation,
personnel
obtained required administrative
approvals
and tagouts
before initi-
ating work, personnel
used
approved
procedures
or the activity was
within the "skills of the trade," workers
implemented appropriate
radiological controls
and ignition/fire prevention controls,
and
equipment
was tested properly prior to returning it to service.
Por-
tions of the following activity were observed:
Maintenance
Procedure
(M)-11. 10, Major Inspection of Service
'ater
Pump,
Pump:
"D" Service
Water., Revision 20, effective
January
5,
1990,
observed
August 24,
1990.
No'nacceptable
conditions were identified.
3.2
Corrective Maintenance
Observations
3.2. 1
Pum
1D Motor Failure
Following the failure of the Service Water
Pump
1D Motor on
August 4,
1990, the inspector
followed licensee's
actions
to diagnose
the cause
of the failure, oversee
repairs,
and
return the
pump to full service in a timely manner.
Upon determining that the motor required rewinding due to
a
phase-to-phase
short in the stator windings, engineers
and
quality assurance
personnel
from the corporate
and site
staffs were dispatched
to the repair facility (Relia'nce
Electric Company,
Cleveland,
Ohio) to evaluate
material
modifications to the motor stator
and
recommend additional
testing to assure
greater
motor reliabi-lity.
Based
en their
engineering
evaluation
and through disc'ussions
with qVendor
representatives,
the licensee's
staff upgraded
the w'inding
insulation
from Class
F 'to Class
H to enhance
the motor's
thermal
endurance.
To provide assurance
that the changes
in materials did not
affect the motor's operating characteristics,
additional
dynamic testing to augment static
was performed
at
RGEE's request.
Dynamic testing included
a dynamometer
performance test,
a heat
run test,
and several
tests at
full load.
Upon satisfactory
completion of testing,
the
motor was returned
to the site, installed,
tested
in-place
and returned to full service
on August 24,
1990.
Based
upon observation of the licensee's
actions,
discussions
with cognizant licensee
representatives,
and review of sup-
porting documentation,
the inspector concluded that the
licensee
acted expeditiously to repair the motor and took
prudent
measures
to improve motor reliability.
3.3
Surveillance
Observations
Inspectors
observed portions of survei llances to verify proper cali-
bration of test instrumentation,
use of approved
procedures,
perform-
ance of work by qualified personnel,
conformance
to limiting conditions
for operation,
and correct
system restoration
following testing.
Portions of the following survei llances
were observed:
4
Periodic Test (PT)-2.10,
Safety Injection System Quarterly Test,
Revision 2, effective June
29,
1990,
observed
August 1,
1990.
PT-32A, Reactor Trip Breaker Testing - "A" Train," Revision 8,
effective June
8,
1990,
observed
August 3,
1990.
No unacceptable
conditions were identified.
3.4
Inservice Ins ection
Summar
Re ort
The inspector
reviewed the licensee's
inservice inspection
summary
report for the first refueling outage of the third inspection interval.
The
ASME Code,
Section XI, 1986 Edition, is the applicable
code for
the interval
and the report was submitted to the
NRC within the time
frame mandated
by Article 6000 of Section XI.
Examination methods
included visual, liquid penetrant,
magnetic par-
ticle, ultrasonic,
radiographic,
eddy current,
functional,
and,system
pressure
and leakage tests.
Inservice inspection
( ISI)
activities during the
1990 refueling outage
were performed
on Code
Class
1, 2,
& 3 components,
high energy piping,
s'team generator
tubes
and snubbers.
I
Examinations
performed
on Class
1,
2 and
3 components
and
on h'igh
energy piping were as follows.
I
Ninety-three (93) examinations
were performed
on 63 Class
1 com-
ponents.
One hundred nineteen
(119) examinations
were performed
on
75
Class
2 components.
Twenty-one (21) Class
3 components
were examined
by the YT-3
visual examination
technique.
Seventy-four
(74) examinations
were performed
on 23 high energy
components.
tubes in the "A" and "B" steam generators
were examined
with the eddy current method.
The status of the
(S/G)
tubes before
and after the examinations
follows:
"A"
~Pre-outa
e
Post-outa
e
~Chan
e
Total
Tubes
3260
Out of Service
Tubes (plugged)
173
Sleeved
Tubes
172
Open Unsleeved
Tubes
2915
3260
197
223
2840
+24
+51
-75
"B"
Total
Tubes
3260
Out of Service
Tubes (plugged)
340
Sleeved
Tubes
642
Open Unsleeved
Tubes
2278
3260
332
832
.
+190
2096
-182
"Tubes recovered
by removing the plugs
and sleeving
the tubes.
S/G "A" Work Sco
e
Hot Leg to ¹1 Tube Support Plate
Full Length
(20% Random
Sample)
Previous Indications
> 20%
Ninimum
~Re uired
2915
583
9
35
Number
~Ies ected
2915
585
9
35
S/G "B" - Work Sco
e
Hot Leg to ¹1 Tube Support Plate
Full Length
(20% Random
Sampl'e)
Previous Indications
> 20%
4
Replugged
Tubes (Full Length)
Four hydrostatic tests
and associated
performed
on the following:
2278
456
19
129
28
VT-2 visual
2278
460
19
I
129
28
examinations
were
~
Charging
Sy'tem through Regenerative
Heat Exchanger
~
CVCS Holdup Tank "A"
~
CVCS Holdup Tank "B"
~
CVCS Holdup Tank "C"
A total of 147 snubber
components
were inspected
requiring
148 VT-3
examinations.
The examinations
were performed to comply with the
licensee's
Technical Specification
requirements.
Fifteen (15) snubbers
were functionally tested,
of which
12 were mechanical
and
3
were hydraulic snubbers.
The
summary report identified three
items (one
( 1) Class
1 and two
(2) Class
2 items) which contained unsatisfactory
conditions
and which
resulted
in an expanded
inspection
sample in each
case.
Additionally,
the originally rejected
components
were put into an acceptable
condi-
tion.
A number of Class
1,
2 and
3 items (40) were identified as containing
Code Rejectable
Indications which did not result in expanded
examina-
tion samples.
The components
were either repaired
and
made acceptable
or evaluated
and dispositioned
use-as-is.
The inspector
agreed with
each disposition but questioned
why the rejectable
findings did not
result in an expanded
inspection
sample.
RG&E's repair program covers
both "Service Induced"
and
"Code Reject-
able" repairs.
A "Service
Induced Reject" occurs
when
an item in the
ISI program contains
an indication that exceeds
applicable
acceptance
standards
and was caused
during the service life of the item.
A ser-
vice induced reject results
in an expanded
inspection
sample.
A "Code
Reject" occurs
when
an item contains
indications or other rejectable
.
conditions that were not service
induced.
That type of reject does
not result in an expanded
inspection
sample..
For each of the
code
rejectable
items the licensee
had identified the nature of the reject-
able condition and
had documentation
which confirmed that the condition
was present prior to placing the item in service
and
was not service
induced.
The inspector
had
no further questions
regarding this matter.
The licensee's
summary report was found to be complete,
and information
that is not included in the report is readily available
from the lic-
ensee.
No unacceptable
conditions were identified.
I
e
'~securie
e
i
During this inspection,
the resident
inspectors verified x-ray machines
and metal
and explosive detectors
were operable,
protected
area and'ital
area barriers
were well maintained,
personnel
were properly badged
for
unescorted
or escorted
access,
and compensatory
measures
were implemented
when necessary.
4. 1
Vehicle Access Control
The inspector witnessed,
on three
separate
occasions,
site security
processing
privately owned vehicles'nto
the protected
area.
Through
these
observations,
the inspector determined that site security properly
interrogated
the vehicle's
owner, thoroughly inspected
the vehicles,
and closely escorted
the owner whilein the protected
area.
Security
personnel
meticulously inspected materials off-loaded from the vehicles
and closely monitored escorted
personnel activities.
Overall, the licensee's
security staff rigorously implemented site
security procedures.
En ineerin /Technical
Su
ort
5.1
Unresolved'Item
50-244/90-09-02
AOV-745 Isolation Si nal
Closed
RG&E modified the
Emergency
Procedures
to direct operators
to verify
the valve closed,
or manually close it, and committed to install
a
containment isolation signal
to the valve by the end of the
1992 re-
fueling outage.
The valve was returned to operable
status
and will
be kept normally closed;
alignment procedures
have
been
changed.
NRC
review concluded that the actions
taken
and planned
were conservative
and adequate.-
5.2
Unresolved
Item 50-244/89-04-02
Major Modification Backlo
Closed
The inspector
reviewed the current list of modifications which are
planned to be performed at the site
and di scussed it with cognizant
licensee
representatives.
The list has
been prioritized based
on the
system which became effective
on January
17,
1989.
Guideline
No.
OMG-2, Revision 0, entitled "Integrated Prioritization of Modifications
and Activities" is the controlling document
and identifies the actions
necessary
to implement the plan.
Based
on the assigned priority,
projects
have
been
scheduled for the next five refueling outages
from
1991 through
1995.
Additionally, the list has
been
broken
down to
pre-outage
and outage activities for each of the five years.
Activi-
ties which can
be performed
when the plant is operating
are listed
under pre-outage activities,
and those which cannot
be accomplished
until the plant is shut
down are listed as outage activities.
The
published five year schedule
is periodically updated
and revised
based
on work activity progress
and changing plant conditions which affect
the established priorities.
Planning
and scheduling of modifications appeared
to be adequately
controlled to assure
that work activities are properly performed
and
that sufficient resources
are allocated to the scheduled activities.
6.
Safet
Assessment/
ualit
Verification
6.1
Self-Assessment
Effectiveness
The inspector
reviewed the status of findings identified in a self-
assessment
performed
by the Nuclear Assurance
group.
In April 1990,
the Nuclear Assurance
group performed
an assessment
of the use of
independent verification when performing certain maintenance activities.
The assessment
credited the maintenance
planners with satisfactorily
implementing the program,
but was critical of the lack of formal,
integrated training for all Maintenance
Department
personnel
to assure
a
common understanding
of independent verification methods.
It con-
cluded that procedural
guidance
on independent verification and the
procedures
that utilize it need clarification.
Comprehensive
formal
training was
recommended.
Though the assessment
provided useful in-
formation to plant management,
no follow-up was requested
and
no formal
mechanism
was
used to follow-up these
concerns.
Although a standard corrective action tracking system exists for regu-
latory and licensee-identified
findings, this system
was not used for
follow-up on the self-assessment
findings.
Not using the formal
0
mechanism
to address
these findings provides
an inconsistent
approach
to problem resolution
and
was assessed
as
a weakness
in administrative
control.
6.2
Personnel
Safet
On July 17,
1990, for the
second
time since
1967,
the Ginna Nuclear
Power Plant achieved
one million work conservative
hours without an
accident.
Senior corporate
and plant management
were. outside
the
guard
house that morning at 5:30 to greet
and congratulate all plant
.
workers.
Plant management attributes this good record to the awareness
of management
and workers of the importance of safety.
NRC review
assessed
this achievement
and its recognition
by management
as indica-
tors of good performance.
6.3
Periodic
and
S ecial
Re orts
Periodic
and special
reports
submitted
by the licensee
pursuant to
Technical Specifications 6.9. 1 and 6.9.3 were reviewed.
Inspectors
verified that the reports
contained
information required
by the
HRC,
that test results
and/or supporting information w'ere consistent with
design predictions
and performance
specifications,
and that reported
information was accurate.
The following report
w'as reviewed:
>
Monthly Operating
Report for 'July 1990.
No unacceptable
conditions were identified.
6.4
Written
Re orts of Nonroutine Events
Written reports
submitted to the
NRC were reviewed to determine
whether
details were clear ly reported,
causes
properly identified and correc-
tive actions
were appropriate.
The inspectors
also
assessed
whether
potential
safety
consequences
had
been properly evaluated,
generic
implications were indicated,
events warranted onsite follow-up, re-
porting requirements
of 10
CFR 50.72 were applicable,
and requirements
of 10
CFR 73 had been properly met.
The following LERs were reviewed (Note:
date indicated .is event date):
90-008 (Revision 01), Safeguards
Buses
Degraded
Voltage Relays
Miscalibrated
Due To Procedure
Inadequacy
Causes
a Condition
Prohibited
By Plant Technical Specifications,
May 24,
1990.
This
LER is closed out in Detail 6.5 of this report.90-010,
Inadvertent
Closure of "A" Steam Generator
Main Feedwater
Regulating
Valve Due to Controller Malfunction Causes
a Reactor
Trip on
Low Steam Generator
Water Level, June 9,
1990.
This event
was reviewed in
NRC Inspection
Report 50-244/90-09.90-011, Fire Damper
Found Missing During Surveillance Test
PT-13.26,
Due to Not Being Installed,
Causes
a Condition Pro-
hibited By Technical Specification,
June
19,
1990.
This event
was reviewed in
NRC Inspection
Report 50-244/90-11.
The inspectors
concluded that the reports
were accurate
and met regu-
latory requirements.
No unacceptable
conditions were identified.
6.5
Unresolved
Item 50-244/90-11-02
Unclear
LER 90-008
Closed
RGKE submitted
a revision to the
LER to address
applicable Technical
Specification action statements
and to clarify recalibration
method-
ology.
NRC review of this
LER revision concluded that the additional
information was adequate
to address
the concerns.
Licensee corrective
actions
were acceptable.
7.
TMI Action Item Follow-u
7. 1
I.D.2.2 and I.D.2.3
Safet
Parameter
Dis la
S stem
The
NRC staff concluded that
RGEE .has satisfactorily met all r'equire-
ments for an
SPDS specified in NUREG-0737,
Supple'ment
1,
as documented
in June
29,
1990 letter from Allen Johnson,
NRC Project Manage'r to
Dr. Robert
C. Mecredy,
RG&E.
This'tem is closed.
7.2
II.K.3.5;B
Reactor
Coolant
Pum
Tri
As stated
in an April 24,
1989 letter from Mr. Patrick Sears,
NRC
Project Manager,
to Dr. Robert
C. Mecredy,
the
NRC staff found RG5E's
plant-specific
RCP trip setpoint development
acceptable.
This item
is closed.
7.3
II.E.4. 1
Dedicated
H dro en Penetration
As stated
in
NRC Inspection
Report 50-244/81-13,
the hydrogen
recom-
biners are located inside containment,
therefore this requirement is
not applicable.
This item is closed.
7.4
III.D.3.4'
Control
Room Habitabilit
NRC Inspection
Report 5-244/84-22 initially reviewed this requirement
and left two concerns
open.
One concern
was closed
in
NRC Inspection
Report 50-244/85-10
and the other in 86-07.
This item is closed.
7.5
II.B.3.4
Post-accident
Sam lin
I
NRC Inspection
Report 50-244/85-08 initially reviewed this requirement
and left four concerns
open.
Two concerns
were closed in
NRC Inspec-
tion Report 50-244/87-05,
one in 87-20,
and
one in 88-20.
This item
i s closed.
7.6
II.F. 1.2.C
Containment
Hi
h
Ran
e Monitor
NRC Inspection
Report 50-244/85-08 initially reviewed this requirement
and left two concerns
open.
One concern
was closed in
NRC Inspection
Report 50-244/87-05
and the other in 87-20.
This item is closed.
8.
Administrative
8. 1
Licensee Activities
The plant operated
at approximately full power throughout the inspec-
tion period.
On August 4,
1990 the "D" service water
pump breaker
tripped due to
a short in the motor's windings.
The
pump motor was
rewound
and more extensive testing
was conducted
before the
pump was
returned to service
on August .25,
1990.
No further problems
were
encountered
during this inspection
period.
8.2
Emer enc
Pre aredness
On August 14,
1990,
the inspector toured the
RGKE Emergency Operations
Facility at 49 East Avenue,
Rochester,
with the
RGKE Emergency
Pre-
paredness
staff.
The facility was found to be fully equipped,and
well maintained.
The most current revisions of controlled copies of
procedures
and drawings were
on file.
Communication
systems
were in
working order.
No problem areas
were identified.
8.3
Ins ection
Hours
This inspection
involved
145 inspection
hours,
including
5 backshift
and 3.5 deep backshift hours.
At periodic intervals
and at the conclusion of the inspection,
meetings
were held with senior station
management
to discuss
the
scope
and
findings of this inspection.
In addition,
NRC exit meetings
were
held for the following inspections
during this inspection period:
50-244/90-15
on August 17,
1990,
50-244/90-16
on August 10,
1990,
and
50-244/90-17
on August
18,
1990.