ML20134L091
ML20134L091 | |
Person / Time | |
---|---|
Site: | Hatch |
Issue date: | 01/18/1997 |
From: | NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
To: | |
Shared Package | |
ML20134L070 | List: |
References | |
50-321-96-15, 50-366-96-15, NUDOCS 9702180262 | |
Download: ML20134L091 (46) | |
See also: IR 05000321/1996015
Text
-- -
-
.
'
.
O.S. NUCLEAR REGULATORY COMMISSION
!
'
REGION II
1
Docket Nos: 50-321, 50-366 I
License Nos: DPR-57 and NPF-5 !
Report No: 50-321/96-15, 50-366/96-15 l
!
1
!
Licensee: Georgia Power Company (GPC)
i
i
Facility: E. I. Hatch Units 1 & 2 l
!
Location: P. O. Box 439 i
Baxley' Georgia 31513 :
Dates: December 8, 1996 - January 18, 1997
Inspectors: B. Holbrook. Senior Resident Inspector
E. Christnot. Resident Inspector
J. Canady. Resident Inspector
G. Kuzo. Senior Radiation Specialist (Sections
R1.2 - R8.2)~.
W. Kleinsorge Reactor Inspector (Section M1.4)
Approved by: P. Skinner. Chief. Projects Branch 2
Division of Reactor Projects
Enclosure 2
9702190262 970213
PDR ADOCK 05000321
0 PDR
0
,
EXECUTIVE SUMMARY
Plant Hatch Units 1 and 2
NRC Inspection Report 50-321/96-15, 50-366/96-15
This integrated inspection included aspects of licensee operations,
engineering, maintenance, and plant support. The report covers a 6-week
period of resident inspection. In addition, it includes the results of
an announced inspection by a regional Senior Radiation Specialist and a
Reactor Engineer's inspection of electrical maintenance.
Ooerations
e The inspectors concluded that Unit 2 control room operator's
demonstrated a lack of attention to detail during control room
panel walkdowns. Operators did not observe an incorrect switch
position and a keepfill pump that had automatically started
(Section 01.2).
e The inspectors identified as a strength operations management's
proactive actions with respect to providing operator training to
correct or prevent some deficiencies (Secticn 05.1).
e The inspectors concluded that the shift of operators reviewed for
fire fighting and fire brigade leader training and qualifications
were trained and qualified for their assigned position.
Corrective lenses for o)erator use while wearing Self Contained
Breathing Apparatus (SC3A) during control room emergencies were
readily available in the control room (Sectiori 05.2).
e The inspectors concluded that plant procedures did not include
guidance for removing valves from backseat following plant
transient conditions that resulted in a reactor cooldown. This
was identified as a weakness. After inspector intervention, the
additional guidance and expectations provided to operators during
shift briefings were appropriate (Section M3.2).
e The inspectors concluded that the operations department
demonstrated a commitment to self assessment and a desire for
continued improvement. Although some corrective recunmendations
contained in the self assessment were not completed, they were
under development and the completed items were thorough and
comprehensive. The self assessments were conducted by
knowledgeable personnel (Section 07.1).
Enclosure 2
., .y _ _ _ _ _._ _ _
. _ _ . ,
I
"
., J
l
2 :
e The failure of the traveling water screen system to operate during
cold weather conditions is identified as a significant weakness in
the area of engineering. Engineering personnel failed to identify
that the design and system configuration did not adequately ~
3rotect system components from cold weather conditions. <
iaintenance and operations personnel also failed to identify that '
portions of the system were vulnerable to cold weather conditions
during their system checks and cold weather preparations !
(Section 08.1), j
Maintenance j
!
e The ins)ectors concluded that the maintenance work activities and i
the worc review by the system engineer for the IB Emergency Diesel i
'
Generator (EDG) voltage regulator re) air were thorough and
performed in accordance with applica)1e procedures. Supervisory ;
and engineering oversight were evident. The inspectors also i
concluded that the EDG design function capability was not degraded -
(Section M1.2). >
e The ins)ectors concluded that the maintenance activities on the '
Unit 2 Reactor Core Isolation Cooling turbine identified and ;
corrected the problem with the fluctuations in turbine speed l
control. Maintenance activities observed were generally thorough i
and professional. Supervisory and engineering oversight were ;
evident (Section M1.3). J
t
e The inspectors identified an Inspector Followup Item (IFI)
50-321, 366/96-15-04: Switchyard Maintenance and Material
Condition. This was due to the switchyard housekeeping and
material condition discrepancies and the number and age of the
predictive maintenance backlogged items for the switchyard
(Section M1.4).
e As demonstrated by good performance, the level of 3reventive
maintenance for the Reactor Protection System and Reactor
Recirculation System Motor Generator Sets was appropriate for the
circumstances (Section M1.4).
e The lack of records that support differences from equipment
manufacturers' 3reventive maintenance recommendations and
dependance on t1e collective memory of personnel was not a good
practice (Section M1.4).
e Leaving loose conductive material in electrical panels was
identified as a poor work practice for foreign material exclusion
control with the potential of shorting out components. Some j
housekeeping discrepancies were noted (Section M1.4). i
Enclosure 2
--. . - - -- .
'
.
3
e The inspectors identified Non-Cited Violation (NCV)
50-366/96-15-01: Inadequate Procedures for Replacement of the
Unit 2 Drywell Hydrogen Recombiner Flow Controller Batteries and
Establishing the Required Controller " Dead Band" Following Certain
Maintenance Activities (Section M2.1).
e Operator performance during surveillance activities for the High
Pressure Coolant Injection System and EDG was generally
professional and competent. The inspectors had observed some
improvements in communications in the recent past but observed
that operations * standards were not met by all crews
(Section M3.1)
e The inspectors identified Violation (VIO) 50-321/96-15-02:
Maintenance Personnel Failure To Follow Procedure During Valve
Backseating Activities. This failure to follow procedure was
generally administrative in nature (Section M3.2).
- The inspectors also concluded that some maintenance personnel's
lack of understanding of different types of procedure usage and
implementation demonstrated a weakness (Section M3.2).
e The inspectors concluded that the maintenance procedure for
electrically backseating valves did not fully implement the
requirements of the engineering evaluation. The inspectors
concluded that this deficiency did not result in a
safety-significant concern for the backseated valves
(Section M3.2).
e Inspector Followup Item (IFI) 50-321. 366/96-15-03: Resolution of
Reactor Core Isolation Cooling (RCIC) and High Pressure Coolant
Injection System (HPCI) Turbine Speed Control Drifting, for
Units 1 and 2. respectively, was identified. The inspectors
concluded that the maximum speed drift observed on the both
systems did not affect the safety function of either system. The
inspectors concluded that the speed control drifting could be an
indication of pending failures (Section M3.3).
e The inspectors concluded that the Unit 2 loss of feedwater heating
transient on January 5. due to a jumper grounding error,
demonstrated a poor work practice on the part of one individual.
This problem was identified as an isolated occurrence and not a
generic concern. Reviewing this error for human performance
improvements was appropriate (Section M4.1).
- Personnel who perform mechanical maintenance on safety and non-
safety related valves were trained and qualified in accordance
with the requirements of ANSI N18.1-1971, the Final Safety
Analysis Report, and other applicable plant qualification
procedures (Section M5.1).
Enclosure 2
____J
. ~ . . ~ - s . . . s.,_.. a -~.w - ---. .w - - .n n . . , - - . . .--..n.- -a ..~. .- a. . _ -. - ~ .
=.-3 .
- . - ..
.
, .
,
, 4
Enaineerina i
4
- e The inspectors concluded that the Unit 1 Standby Liquid Control i
'
(SLC) pump tripping was an isolated problem. The inspectors
concluded that engineering personnel from the Nuclear Safety And 3
l
'
Compliance (NS&C) conducted a detailed review of the SLC pump
tripping problem, and was viewed as a positive attribute of the
j department. Replacement of the system components was appropriate
(Section E2.1).
4 :
e The inspectors concluded that the engineering evaluation for !
,
electrically backseating valves located in the drywell was .
. satisfactory. The evaluation considered plant safety and !
> identified actions to ensure continued system and component :
reliability (Section E3.1).
,
Plant Suooort
J e The inspectors identified a Violation 50-321, 366/96-15-05: :
2 Failure to Follow Procedures for Contamination Control and for ;
! Deficiency Card Issuance for Inadequate Bioassay Calibration i
i Guidance. Quality control cross-check analyses were conducted in ;
, accordance with procedural requirements (Sections R1.2 and R7.1). !
.
,
j e General employee training and completed medical certifications for i
2 personnel involved in licensed activities were conducted in <
! accordance with the anlicable procedures and met the requirements
L of 10 CFR 19 and 10 C 120 (Section R.5).
4
- e Radiation protection performance indicators verified that licensee
, actions to control worker dose were effective and radiological ,
,
effluent releases were minimized (Section R8). i
.
3
o The inspectors concluded that the inspected areas of the security ,
'
program met the applicable requirements (Section S2).
) e The inspectors attended various Outage Management Meetings held at
- the site and concluded that the critical path for the refueling ;
j outage was identified and that the refueling outage appeared to be ;
well planned, with realistic goals and adequate support
.
(Section X.2). ,
-
i
- Enclosure 2 ,
I
.
-
.
.
Reoort Details
Summary of Plant Status
Unit 1 operated at 100% rated thermal power (RTP) throughout the report
period, except for routine testing activities.
Unit 2 began the report period at 100% RTP. On January 5, power was
reduced to about 93.5% RTP due to a feedwater heater isolation. Power
was returned to 100% RTP on the same day and operated at this power level
throughout the remainder of the report period, except for routine testing
activities.
I. Operations
01. Conduct of Operations
01.1 General Comments (71707)
i
The inspectors conducted frequent reviews of ongoing plant
operations. In general, the conduct of operations was
professional and safety-conscious: s
are detailed in the sections below. pecific events and observation ;
01.2 Control Room Panel Walkdown
a. Insoection Scooe (71707)
On January 10. the ins)ectors conducted a control room panel
walkdown of Unit 2. T1e walkdown included safety- and
non-safety-related equipment valve lineups, switch positions and i
process instrument indications.
b. Observations and Findinos
l
The inspectors observed that both keepfill pumps on the B loop of i
Residual Heat Removal System (RHR) were in service. One control i
switch was in run and the standby pump control switch was in auto.
This observation was brought to the attention of the control board ;
'
operator. The operator indicated that the B loop of RHR had been
in service for torus cooling during previous surveillance
activities and had been secured earlier that day, following the
completion of the surveillance activities. Tne operator indicated
that securing the RHR pump may have caused a small pressure surge ,
that initiated the automatic start of the standby keepfill pump. !
The operator secured the standby pump and system pressure remained
satisfactory.
The inspectors also observed that the by) ass selector switch for
the A Source Range Monitor (SRM) was in )ypass. This was brought
to the attention of the control board operator. The operator
Enclosure 2 I
l
.- _ _ _ .
_ . - - - - . - . - - - . . .
.
.
!
2
stated that the A SRM instrument cabinet had been removed from the
control room panel on January 9. for Instrumentation and Control
~( I&C) work activities. The SRM instrument cabinet had been
replaced on the previous shift The SRM bypass selector switch
had not been returned to normal. l
The inspectors brought these deficiencies to the attention of
operations' management for resolution. Management's expectations
are in part, that the operators walkdown the control room front
panels once per hour and back panels once per two hours and look
for changing trends and incorrect switch positions. ,
!
c. Conclusions
The inspectors did not consider these deficiencies to be an
immediate concern for plant safety. The inspectors concluded that
control room operators demonstrated a lack of attention to detail
during control room panel walkdowns. Operators failed to observe *
an incorrect switch position and a keepfill pump that had
automatically started.
05 Operator Training and Qualification ;
!
05.1 Review of ooerator "Just in Time" Trainina
'
. a. Insoection Scooe (71707)
A new training initiative, entitled "Just in Time" training
!
commenced to address previous problems associated with activities
i that would affect operators. Operations' management began "Just
in Time" training sessions for 03erators due to previous problems
,
with reverse power trips of the EDGs during surveillance !
i
activities. On December 26. the inspectors observed two sessions !
of "Just In Time" training for EDG manipulations during
i surveillance activities. l
b. Observations and Findinas :
The inspectors observed that the "Just in Time" training was
conducted on the plant simulator. One session provided an
. o)erator the opportunity to review the procedure and manipulate 1
- t1e switches !
surveillance. prior Thetoother
performing
trainingansession
inplant provided
Unit 2 EDG
a different ,
operator the same opportunity prior to performing a Unit 1 EDG !
surveillance. !
i
The inspectors observed that the training sessions were self
directed by the operators and required very little instructor
assistance. The operators reviewed the apolicable procedures and ,
-
1
Enclosure 2 ;
l
'
- - . _ . -
.
-
.
\
l
3
performed the necessary manipulations to complete the ;
surveillances. ;
The inspectors discussed with operations' management if training
on the simulator, which is modeled after Unit 2. may present
additional challenges to operator performance when performing
Unit 1 activities. Operations' management indicated no and
stated that, even though the simulator was modeled for Unit 2 any
switch manipulation practice would be of benefit to the operators.
c. Conclusions
The inspectors concluded that operations' management was proactive
with respect to providing operators training to correct or prevent
some deficiencies by the "Just In Time" training. The inspectors
observed that the "Just in Time" training was not a formal or
proceduralized process; however, operators or super isors may
request training at their discretion.
05.2 00erator Fire Briaade trainina and Qualification
a. Inspection Scooe 71707
The inspectors reviewed fire training requirements and
qualifications for a shift of operations aersonnel. The review
was conducted for fire fighters and fire ]rigade leaders.
b. Observations and Findinas
The inspectors reviewed the licensee's Training Records and
Qualification System Matrix Report and confirmed that operators on
shift were indicated as qualified for their fire fighting
positions. The inspectors also verified that the operators had
successfully completed the required initial and requalification
training to maintain their qualifications.
The inspectors also verified that corrective lenses were available
in the control room for operators' use during emergencies that may
require SCBAs to be worn. The inspectors observed that six
operators that required corrective lenses license restriction did
not have corrective eye glasses stored in the designated storage
location in the control room. The inspectors were informed by
operations supervision that the six operators wore contact lenses
instead of eye glasses. The inspectors reviewed ap)licable
procedures that dealt with wearing contact lenses w111e wearing a
SCBA and concluded that the procedures and training were adequate.
Enclosure 2
-
'
.
I
4
l
c. Conclusions i
4
The inspectors concluded that the shift of operators reviewed for :
fire fighting and fire brigade leader training and qualifications
were trained and qualified for their assigned position. . :
.
Operators' corrective lenses for use while wearing a SCBA. during
i control room emergencies, were readily available in the control !
i room. .
3
07 Quality Assurance in Operations l
. 07.1 Licensee Self-Assessment Activities (40500)
a. Insoection Scooe 40500 i
j The inspectors reviewed two licensee self assessments and followup
actions and a new procedure for Team Observations.
. b. Observations and Findinas '
1
The inspectors reviewed a self assessment for operations
activities with respect to reactivity controls. Following
,
!
1 operator errors during refueling activities, control rod movement '
{ errors, and inattention to detail, the licensee initiated a self
- assessment to identify root causes and recommend corrective
'-
actions. l
The inspectors reviewed the licensee's completed actions with l
, respect to implementing the recommendations. The inspectors ,
observed that 7 of 20 recommendations were not completed.
. However, the licensee's documentation indicated that the remaining
i open items would be com eted prior to the Unit 2 refueling outage '
! scheduled for March 199
'
! The inspectors reviewed an operations department self assessment
. completed on about September 26, 1996 that focused on identifying
' needed enhancements and generating corrective action
recommendations aimed at hel)ing the department achieve its goal
- of excellent performance. T1e assessment was conducted at the ,
.
request of operations' management and conducted by personnel both j
within and outside the parent organization. l
The inspectors observed that the assessment included safety focus. !
management involvement, problem identification, problem :
resolution, quality of operations, programs and procedures, and :
operations efficiencies. The inspectors also observed that the i
assessment provided specific observations and recommendations.
'
.
, The inspectors also reviewed procedure DI-0PS-59-0896N: Team
Observations. Revision 0, and observed that the procedure provided i
Enclosure 2
I
- t
.. -- - -l
,- - . . -- . . - - - - -. - - - - . . - , _ - - . - - . . _ - . - -
4 t
5
i
'
a means of observing and reinforcing the operations department's
expectations by performing supervisory and peer evaluations on ;
routine tasks. Checklists for specific activities were included i
and contained a method of identifying whether or not the j
expectations were met. ,
3
The inspectors reviewed some completed observations, checklists. !
and comments and discussed them with operation's management.
Operations' management stated that the process was still being
improved and a revision of the procedure was being developed.
r
c. Conclusions >
The inspectors concluded that the operations department i
demonstrated a commitment to self assessment and a desire for ;
continued improvement. Although some corrective recommendations l
were not com)leted, they were under development and the completed i
items were t1orough and comprehensive. The self assessments were j
conducted by knowledgeable personnel. i
i
08 Miscellaneous Operations Issues i
08.1 Cold Weather Followuo and Walkdown -
a. Insoection Scooe (71714)(92901) l
The inspectors performed a walkdown of systems and plant
structures during hard freeze warnings.
b. Observation and Findinas ,
The inspectors observed the following during the walkdown: l
!
-
Two of the four wall manual louvers in the Fire Pump House were ;
not closed completely. The louvers were o
inch. The manual roof vent was also open. pen approximately one
-
Three heat trace indicating lights were not illuminated. Two >
were on the fire protection water system and the other was on i
the cooling water to the IB EDG.
'
-
Several automatic louvers in the EDG rooms were not completely
closed as required. ,
The inspectors found from that some deficiencies still existed !
that had been previously observed as documented in ;
IR 50-321. 366/96-14. l
l
Following a hard freeze warning on about December 21. Plant !
Equipment Operators (PE0) could not get the up-river or the down- '
Enclosure 2 ,
l
,
. _ _ _ ,.m . ___ _ _ _. . _ _ _
. . _ - . - - . -- . __ - . - . . . - - - - - - - . . - - - . -
!
.
l
!
!.
-
'
6
. river traveling water screens to operate. Subsequent trouble i
! shooting by maintenance personnel identified that the pressure ,
switches for both screens had frozen. The inspectors observed the i
'
pressure switch installations and observed that the sensing lines
to the switches were heat traced, but a problem existed in that #
switches were not heat traced or insulated in order to read their ;
indication. Maintenance personnel corrected this problem and
later enclosed the switches with insulating material, installed
heat lamas and directed the lamps toward the pressure switches. A
design clange was initiated to make permanent repairs.
The inspectors were informed that operations personnel had tested !
the traveling screens due to information received from industry l
experience. Freezing problems with traveling screens had been i
identified at other sites. l
t
The inspectors found from the reviews and discussions with l
licensee personnel that the traveling water screen system for both
units would not operate in manual or automatic due to the pressure
switch problem. As a result, the support systems affecting plant ,
safety systems, such as Plant Service Water (PSW) and Residual
Heat Removal Service Water "lHRSW). were not available during this !
cold weather condition. The licensee's prompt corrective actions
restored the function of the pressure switches. The affected
plant safety systems would have performed their required >
functions.
c. Conclusions
The inspectors concluded that the deficiencies obser ved during the i
walk downs were not significant for the existing outside ;
temperatures and the cleanliness of the river water and river i
level at the time of the walk downs. Maintenance and operations l
personnel failed to identify that portions of the system were
vulnerable to cold weather conditions during their system checks
and cold weather preparations. Engineering personnel failed to
identify that the design and system configuration did not
adequately protect system components from cold weather conditions.
The failure of the traveling water screen system to operate during
cold weather conditions is identified as a significant weakness in
the area of engineering.
Enclosure 2
l
l
!
_ ... - . - - - . . - . - . - .. .- _ - .. -- - - - - _ . --- -.
l
.
r
!
7
l
II. Maintenance
M1 Conduct of Maintenance !
!
M1.1 General Comments ;
a. Insoection Scooe (62707) j
The inspectors observed all or portions of the following work !
activities * I
\
-
MWO 1-96-4722: Electrically backseat RCIC Inboard J
Isolation Valve 1E51-F007
-
MWO 1-96-4362: Electrically backseat RWCU Inboard
Isolation Valve 1G31-F001 1
-
MWO 2-96-3361: Repair 1B EDG Auto Voltage Regulator i
-
MWO 2-96-0042: Repair Unit 2 RCIC EGM Control Box
-
MWO 2-96-2976: Repair Unit 2 RCIC Data Input to DAAS
-
MWO 1-97-0066: Investigate Tripping of 1A SLC Pump
-
MWO 1-97-0071: Replace Overload Heaters in 1A SLC Pump
-
MWO 1-97-0092: Replace Overload Relay for 1A SLC Pump
b. Observations and Findinas
The inspectors found that the work was performed in accordance
with actively used work packages. Appro)riate post modification
and maintenance tests were performed. Tlese tests consisted of
operating the equipment following the completion of work
activities.
Additional inspector observations are documented in Sections M1.2
and M1.3.
M1 -. 2 Reoairs to 1B EDG Automatic Voltaae Reaulator
a. Insoection Scone (62707) !
l
The inspectors observed work activities performed on the IB l
Emergency Diesel Generator (EDG) automatic voltage regulator under ;
Maintenance Work Order (MWO) 2-96-3361. The inspectors discussed !
the activities with maintenance, engineering and operations !
personnel.
b. Observations and Findinas
The inspectors were informed that while performing 3rocedure l
34SV-R43-002-2S: Diesel Generator IB Monthly Test
'
Rev.18, with
voltage regulation in automatic control and the voltage at 4120
volts alternating current (VAC), the voltage could not be adjusted
Enclosure 2
- . - . . . - - _ , . . -
-
. I
i
1
8 i
to the required 4160 VAC. The automatic voltage adjustment must'
be performed at the local panel due to the design of the system. l
Troubleshooting activities discovered defective diodes in the :
direct current drive motor circuit of the voltage regulator. The !
motor positions the automatic regulator rheostat which sets the
voltage level for automatic control. The inspectors discussed the
failure of the diodes with engineering personnel and were informed
'
that the motor and rheostat were seldom exercised and this may i
have contributed to the failure. The system engineer indicated
'
that a recommendation to exercise the motor and rheostat more
often would be made. ,
,
During the repair activities. the inspectors observed that the new l
diodes were installed by craft personnel using applicable l
procedures with supervisory and engineering oversight. Subsequent i
to the repair, a new motor-rheostat unit was installed and the l
repaired unit was returned to the warehouse as a spare. ]
The inspectors were informed by engineering that the EDG would
have controlled the voltage in automatic at 4120 VAC instead of
4160 VAC and the difference in voltage was not enough to affect
safety-related loads.
c. Conclusion
Maintenance activities observed were generally thorough and
professional. Supervisory and engineering oversight were evident.
The inspectors concluded that the work activities and the review
by the sy'. tem engineer for the IB EDG voltage regulator were
thorough and performed in accordance with applicable procedures.
The inspectors also concluded that the EDG was capable of
performing the required safety functions.
M1.3 Reoairs to Unit 2 Reactor Core Isolation Coolino (RCIC) Turbine
Soeed Control
a. Insoection Scone (62707)
The inspectors reviewed the results of the maintenance activities
and observed the post maintenance test of the Unit 2 RCIC turbine.
The system had been declared inoperable due to speed control
problems.
b. Observations and Findinos I
The activities were performed under MW0s 2-96-0042 and 2-96-2976.
and ap)licable procedures. Trouble shooting activities indicated
that tie electronic governor motor (EGM) was defective. The EGM l
Control Box was replaced and the RCIC was satisfactorily tested. I
l
Enclosure 2 i
.
.
9
The defective electronic governor was bench tested and confirmed
that the trouble shooting findings were correct. Inspector
observations on the Unit 2 RCIC post maintenance and operability
testing are documented in Section M3.3 of this report.
c. Conclusions
Maintenance activities observed were generally thorough and
professional. Supervisory and engineering oversight were evident.
The ins)ectors concluded that the maintenance activities on the
Unit 2 RCIC identified and corrected the 3roblem with the
fluctuations in turbine speed control. T1e two reversed wires
discovered did not affect system operability but demonstrated a
lack of attention to detail.
M1.4 Electrical Maintenance Imolementation
a. Insoection Scooe (62700)
To evaluate electrical maintenance implementation as it relates to
motor generator (MG) sets and switchyard equipment, the inspectors ,
conducted: walkdown inspections of the Reactor Protection System
(RPS) and Reactor Recirculation System (RR) MG set rooms and
selected areas of the switchyards and the switchyard control !
house; and reviews of equipment manufacturers' technical manuals. l
re)etitive task records, maintenance records, and oil analysis and
vi) ration test data. The inspectors compared the equipment
manufacturers' maintenance recommendations with the licensee's
maintenance program for both scope and periodicity.
b. Observations and Findinas
Reactor Protection System and Reactor Recirculation System MG Sets
Housekeeping was good with the following exceptions:
o A number of structural fasteners were missing from control
panels. The concern was that the missing fasteners could
abrogate the seismic qualification of the pariels.
e The closure devices on a number of panel doors were not secured
such that the weather stripping was compressed. The concern
was that the improper sealing of the panels could abrogate the
environmental qualification.
e Metal shavings (probably the debris left from drilling) and
miscellaneous fasteners were found adrift inside control
panels. Leaving loose conductive material in electrical panels
was identified as a poor work practice control with the
Enclosure 2
_ _ _ _ . _ . _
.
,
.
,
10
potential of shorting out components. The fasteners were
removed by the licensee,
e The Reactor Recirculation System MG set oil circulation systems
leak. To address this issue, the licensee conducts daily wipe
downs and was actively pursuing a permanent repair.
There was a number of areas where the liccnsee's repetitive
preventive maintenance program was not consistent with the <
equipment manufacturer's recommendations. The licensee was unable )
to provide documented justifications for the differences. i
However, the licensee was able to provide anecdotal information j
>
remembered by maintenance personnel that supported the deviations.
Records, examined by the inspectors. reflected that repetitive
- preventive maintenance activities were completed within the
- scheduled time period.
I Records reflect that the repetitive preventive maintenance program !
'
had been effective as few repetitive corrective maintenance
i
activities were required. l
Maintenance in the switchyards was performed by Georgia Power
Company Transmission Maintenance Center with procedures issued by l
l the Transmission Operation and Maintenance Manager. Some *
j surveillances were performed by Plant Hatch Operations Department l
personnel.
- Ins)ection of housekeeping and material condition revealed a I
4
num)er of items that needed attention. Protective coatings on
l exterior equipment had deteriorated, as evidenced by many areas of )
l rust and missing closure fasteners. Inside the switch house, the
inspectors noted un-taped spare electrical leads in the back board
i area, trash, and evidence of feline habitation. Conductive
<
material (metal shavings and fasteners) was found in both exterior l
panels and in the back board area in the switch house. The '
- fasteners were removed on the spot. The effectiveness of rain ,
- gutters on the switch house was minimal in deflecting water away- t
i from the structure, due to advanced corrosion. l
l
There was a number of areas where the licensee's repetitive
maintenance program for switchyard equipment was not consistent !
with the equipment manufacturer's recommendations. The licensee
'
- was unable to 3rovide documented justifications for the !
differences, iowever, the licensee was able to provide anecdotal .
information, remembered by Transmission Maintenance Center
personnel, that supported the differences. l
3
Enclosure 2
_, . _ . _ _. .
. ____ _ _ _ _ _ . _ . . _ _ _ _ . _ ..
. .
,
11
<
Transmission Maintenance Center records reflected that there were ,
19 repetitive maintenance tasks that were overdue, the oldest of
which had a due date of July 23, 1992. The overdue activities ;
were various 3reventative diagnos11c tests of air blast breakers. *
Transmission iaintenance Center records were such that timeliness .
of completed maintenance tasks could not be determined.
!
c. Conclusions
'
As demonstrated by good performance, the level of 3reventive
maintenance for the Reactor Protection System and Reactor
Recirculation System Motor Generators (MG) was a?propriate for the 4
circumstances. Some housekeeping discrepancies were noted. The ,
lack of records that support differences from equipment I
manufacturer's areventive maintenance recommendations, and
dependance on t1e collective memory of personnel was not a good
practice.
Due tc the switchyard housekee)ing and material condition
discrepancies identified and tie number and age of the predictive
maintenance backlogged items, switchyard maintenance will be the
subject of a future NRC inspection. This matter will be
identified as Inspector Followup Item 50-321, 366/96-15-04: ;
Switchyard Maintenance and Material Condition.
'
M2 Maintenance end Material Condition of Facilities and Equipment
! 'M2.1 Hydroaen Recombiner Unit 2
. a. Insoection Scooe (92902)
! On November 21. 1996, the ins)ectors observed that an 18-month
-
surveillance for the Unit 2A )rywell Hydrogen Recombiner System
(HRS) could not be performed to due problems with inlet valve.
2T49-F003A. The controller for the valve was not operating
3roperly. The inspectors reviewed past performance and work
listory for the system. The system had been declared inoperable
so that corrective maintenance could be completed. ;
i
'
b. Observations and Findinas
The inspectors reviewed documentation dated from November 20 ,
to 24, concerning the HRS and observed the following:
1 - On November 20. the HRS 2A, Panel 2T49-P600A was removed from i
service for testing of motor operated valves (MOVs) and the i
replacement of MOV electrical overloads !
Enclosure 2
, , - , .-.y ., ,. _ ,, -
.
m u, .a__._..uua-.m .__..___,.2 -
w.,
I
. o ;
' I
l
12 :
- On November 21, the surveillance for the HRS valve operability l
was satisfactorily completed and the recombiner functional test ]
was started at 3:30 a.m. !
!
-
On November 21. at 5:20 p.m., a functional test was l
unsatisfactory due to a controller memory loss for inlet '
MOV 2T41-F003A. The loss of memory was due to a loss of power. l
The controller loses power when the breaker for the MOV is <
racked out.
-
On November 22 problems continued with valve 2T41-F003A. The I
valve cycled partially open and closed and technicians were !
concerned that the motor on the valve would overheat, causing ,
damage. The gain on the controller was adjusted with no affect
and engineering personnel continued their investigation. ;
Licensee documentation revealed the problem was corrected and the
2A HRS was returned to service at 11:45 p.m. on November 24.
The inspectors identified from reviews and discussions with f
licensee personnel the following: the batteries located in the ;
flow controllers have a service life of five years, and a shelf
'
life of about three to four years, according to vendor !
information: the batteries had not been changed since Unit 2 was
licensed in 1978: and the batteries were installed in order to
protect the controllers from a loss of programming during a loss ,
of power. l
The inspectors also identified that no procedure discussed the
batteries, required that they be functionally tested, nor that
they be changed in accordance with vendor recommendations. EDG
3ersonnel responsible for the system failed to ensure that the l
3attery replacement was specified in plant procedures. :
The inspectors were later informed that, following maintenance
activities on the valve a controller " dead band" was required to ,
be established for proper operation of the valve and valve
controller. This requirement was also not identified in any ,
procedure, post maintenance testing, or calibration activity. l
t
When the maintenance activities on the valve were completed. I&C l
completed the required calibrations and the old battery was >
tested. It satisfactorily performed. Since the licensee did not !
have a spare battery, the old one was left in place. The licensee i
initiated procurement activities to purchase a new battery. .
The inspectors verified that procedures were revised to identifv ~
I
establishing the require " dead band" following maintenance or i
calibration activities. The inspectors verified that procedures ;
Enclosure 2
!
.
i
. -_ . _ . -. - _ - .
,. ..
i
,,
13
were scheduled to be revised to include replacing the battery
within the required vendor recommended frequency.
c. Conclusions
The inspectors concluded from reviews and discussion with licensee
personnel that the Unit 2 Drywell HRS flow controller batteries
exceeded the vendor recommended service life. Procedures were
inadequate in that battery replacement was not identified.
Additionally, the procedures were inadequate for establishing the
required valve controller " dead band" following certain
maintenance activities. This violation constitutes a violation of
minor safety significance and is being identified as
NCV 50-366/96-15-01: Inadequate Procedures for Replacement of the
Unit 2 Drywell Hydrogen Recombiner Flow Controller Batteries and
Establishing the Required Controller " Dead Band" Following Certain
Maintenance Activities, consistent with Section IV of the NRC
M3 Maintenance Procedures and Documentation
M3.1 Surveillance Observations
l
a. Insoection Scooe (61726)
The inspectors observed all or portions of the following Unit 1
and Unit 2 surveillance activities:
- 345V-E41-002-15: HPCI Pump Operability.. Revision (Rev.) 19
- 34SV-R43-001-1S: DG 1A Monthly Test, Rev. 17. ED 1
- 34SV-E41-002-2S: HPCI Pump Operability. Rev. 23
- 34SV-E51-002-1S: RCIC Pump Operability. Rev. 17
- 34SV-E51-002-2S: RCIC Pump Operability. Rev. 16
b. Observations and Findinas
On December 26, the inspectors attended the pre-job briefing in
preparation for the Unit 1 High Pressure Core Injection (HPCI)
surveillar,ce activities and observed operator actions during
portions of the surveillance. The test was also >erformed to meet
the Inservice Testing (IST) requirements for the iPCI system. The
inspectors observed that a member of engineering su) port,
maintenance, health physics (HP), o)erations and t1e system
engineer were present at the pre-jo) briefing. The Assistant
General Manager - Plant Support (AGM-PS) was present for the
majority of the briefing.
During the briefing, operations personnel requested that HP ensure j
that no personnel were in the torus area. This was for personnel l
protection, based upon previous industry operating event history
Enclosure 2
l
l
J
,-
l
.
I
14
i
for failure of small turbine exhaust diaphragms. HP personnel
ensured that no personnel were in the area and posted it.
The inspectors observed that hydrogen injection was lowered to
about 8 standard cubic feed per minute (SCFM) and that the
applicable technical requirements manual (TRM) action statement
for the main steam line radiation monitors being set
3
non-conservatively was entered.
The inspectors observed that a HP technical was present locally
and had identified the HPCI room as a High radiation area. A
minimal number of personnel entered the HPCI room during
operation, consistent with As low As Reasonably Achievable (ALARA)
considerations. Maintenance and other personnel were on standby
at a designated low dose area.
The inspectors observed that operator actions in the control room
were adequate. Appropriate attention to detail, procedural usage,
and supervisory oversight were demonstrated. Communications were
not all 3-part, but did not present any observable problems during
the surveillance. The i'spectors
n discussed operator
communications during the surveillance and general communications :
with operations * management. Operations * management stated that a j
renewed emphasis had been placed on communications and that some
crews demonstrated better communications than others.
The inspectors toured the EDG building and observed the 1A EDG
during the surveillance run. The inspectors identified a small
oil leak on the governor that had not been previously identified.
The leak was brought to the attention of operators stationed at
the EDG who contacted maintenance personnel, who repaired the
leak
c. Conclusions
The Unit 1 HPCI and EDG systems performed as required and met the
ap)licable TS criteria. However, the HPCI pump outboard bearing
vi) ration increased to the alert range. requiring that the
surveillance test frequency for HPCI pump be doubled. The
performance of the operators and crews conducting the
surveillances was generally professional and competent. The
inspectors had observed some improvements in communications in the
recent past but observed that operations * standards were not met
by all crews. No other deficiencies were identified.
Enclosure 2
_ __
,
.
- (
,
!
15 i
t
H3.2 Review of Maintenance Activities to Electrically Backseat Valves. !
a. Insoection Scooe (62703) ;
The inspectors reviewed maintenance activities and documentation i
for electrically backseating two Primary Containment Isolation '
valves. The licensee electrically backseated the valves in an i
attempt to identify and reduce the unidentified drywell leakage- f
for Unit 1. Reactor Water Cleanup (RWCU) Inboard Isolation j
valve 1G31-F001, and RCIC Inboard Isolation valve 1E51-F007. were !
electrically backseated on November 14 and December 27. 1996. i
'
respectfully. The inspectors reviewed the corporate engineering
evaluation (section E3.1 of this report) to ensure that all
a>plicable actions were completed. Additional inspector
o)servations are discussed in section E3.1 of this report.
'
b. Observations and Findinas.
The inspectors reviewed procedure 51GM-MNT-034-05: MOV Electrical f
Backseating With Instantaneous Circuit Breaker Trip Protection, j
Rev. 2. The following are deficiencies that were identified by the
'
inspectors:
'
-
The Evaluation section of the corporate engineering evaluation
stated that procedure 51GM-MNT-034-05, limits the motor current
(of the valve being backseated) to twice the rated current.
However, step 7.6 of the procedure states, in part, to " adjust
breaker 2 on the backseat apparatus to 2 times rated amps
(+/- 50%)." This would allow a maximum of three times rated
motor current, not twice the motor current, as s)ecified in the
engineering evaluation. Engineering concluded tlat this
difference was not a safety concern for the valve since the
engineering evaluation was more concerned with locked rotor
current.
-
Special requirements. Step 4.3.2 of the backseating procedure
and the engineering evaluation, states, in part, that prior to
performing backseating, the Shift Supervisor on duty will
review the engineering evaluation for the impact on stroke time
requirements and will indicate the results cf Ms review in the
work performed section of the MW0.
This documentation was not completed for either of the two
valves that were backseated. The inspectors discussed this
deficiency with maintenance and operations personnel. The
operations supervisor on shift during one of the backseating
activities stated that he did not review the maintenance
procedure and was not aware of the documentation requirement.
The inspectors discussed maintenance activities with respect to
Enclosure 2
_
.
.
.
16
reviewing procedures prior to their use and how maintenance
communicated specific requirements to operations personnel. The
inspectors were informed that if a maintenance procedure
contained specific requirements for operations personnel,
maintenance personnel were required to bring the requirement to
the attention of operations. ,
i
The inspectors reviewed procedure 10AC-MGR-019-05: Procedure l
Use and Adherence Rev. O, and observed that step 4.3.4, !
stated, in part, that all plant personnel were responsible ~for
reviewing and understanding procedures prior to using them. .
The inspectors concluded that in at least one example discussed
above, maintenance personnel responsible for the valve
backseating procedure did not bring the specific documentation
requirement to the attention of operations' supervision. The ,
inspectors noted that after bringing the deficiency to the ;
attention of the maintenance personnel..the documentation was :
later completed. :
i
During the discussion with maintenance personnel concerning !
procedure use, the inspectors were informed that some sections :
of maintenance procedures may be considered continuous use,
-
some sections may be considered reference use, and other parts ;
may be considered information use. The inspectors discussed ;
different procedure usage with at least five different i
maintenance personnel and discovered that no clear
understanding of procedure usage was evident. The inspectors .
reviewed Procedure 10AC-MGR-019-0S. Rev. O. and discussed !
procedure usage with maintenance management. The inspectors i
were informed that improvement in procedure usage continued to
be a challenge and management's expectations were not being !
met. ,
!
It was not clear to the inspectors how some personnel's ;
misunderstanding of procedure usage would ensure effective and i
consistent implementation of the procedures. Procedure usage j
appeared to be very subjective on the part of the user and !
would not necessarily ensure that management's expectations for i
'
procedure usage were consistently met. The inspectors
concluded that maintenance personnel's understanding of
different procedure usage and implementation demonstrated a ,
-
weakness.
-
Procedure step 4.3.4 stated, in part. that the engineering ,
evaluation must be attached to Attachment 1 of the procedure i
and filed in Document Control with a copy attached to the MWD. :
The inspectors observed that during the review of the MWO work [
package for the backseating completed on November 14 the
Enclosure 2
!
I
f
!
L
.- . --- -- -. - . - - - -. . - - ~_.-. _ _ - -
.
!
$ i
.
i
17
. engineering evaluation was not part of the MWO work package and )
was not attached to Attachment 1. The inspectors noted that
!
- the MWO work package was being maintained open until after
- outage work. After bringing this deficiency to the attention
j of maintenance personnel. the engineering evaluation was ;
- included as-part of the MWO package and properly attached to i
! the procedure. j
- ;
.
-
v._adure step 4.3.5 stated. in part, that a MWO must be i
initiated for internal inspection on the valve to be i
j backseated. l
-
The inspectors observed that the engineering evaluation did not l
. specify that an internal inspection of the valve be completed. i
i However, the evaluation identified that the procedure required
an internal inspection of the valve that was backseated. The ,
inspectors observed that a MWO was not initiated for an !
internal inspection of the valve backseated on December 27.
- During a discussion with the system engineer he indicated that i
'
! an internal valve inspection would be completed provided other
inspections of the valve and or actuator indicated that an
j internal inspection was warranted.
i For the valve backseated on November 14. the MWO identified l
l that an internal valve ins)ection be performed but referenced
'
an incorrect procedure. T1e procedure referenced and
! documented on the MWO did not exist. This deficiency was
'
corrected after the ins
4
maintenance personnel. pectors identified the problem to
l -
The engineering evaluation recommended that o)erations
- implement administrative controls to ensure tlat the backseated
l valves would be removed from backseat prior to a 100 degree
Fahrenheit ( F) cooldown of the reactor. Operations placec
caution tags on the valves to meet this recommendation.
i
The inspectors observed the caution tags placed on the
backseated valves and noted that the caution tags stated that
- the valves were electrically backseated. The caution tag book
>
did not contain any additional information. The inspectors
.
reviewed procedure 34G0-0PS-013-2S: Normal Plant Shutdown.
Rev. 21. and observed that step 7.3.26 stated, in part, that
! 3rior to cooldown greater than 100 F. remove all MOVs that have
3een electrically or manually backseated from their backseat.
The procedure did not provide additional instructions for the
activity.
.
The ins)ectors discussed a concern with operations' management
,
as to w1 ether the operators had sufficient guidance for
,
removing valves from their backseated condition during all
. Enclosure 2 i
I
i
'
i
!
_ , _ _ _ . _ , _ . . _ - _
._
~
,
.,
18
plant conditions. The normal method of removing a valve from
its backseat was to close the valve using the control room
handswitch. The inspectors concern was that if operators used
this method of removing valves from their backseat. RCIC and
RWCU system (and other systems with backseated valves) would be
isolated when they may be needed for continued safe unit
shutdown. As a result of this discussion operations'
management provided additional instructions for the beginning
of shift training (BOST) for each operating crew informing
them of expectations and priorities during plant transient
conditions. The inspectors did not identify similar
instructions in the unit's scram proced r e.
c. Conclusions
The inspectors concluded that failure to follow procedures
51GM-MNT-034-OS and 10 AC-MGR-019-0S by maintenance personnel to
ensure that steps were completed was a violation. This was
identified as Violation 50-321/96-15-02: Maintenance Personnel
Failure To Follow Procedure During Valve Backseating Activities.
The inspectors concluded that maintenance personnel's lack of
understandina of the different types of procedure usage
requirements and implementation demonstrated a weakness.
The inspectors concluded that the maintenance procedure for
electrically backseating valves did not fully implement the
requirements of the engineering evaluation. The inspectors
concluded that this deficiency did not result in a safety
significant concern for the backseated valves.
M3.3 Unit 1 RCIC and Unit 2 HPCI Soeed Control Chances
a. Insoection Scooe (92902)
The ins)ectors observed upward drifts in the Unit 1 RCIC and
Unit 2 iPCI turbine speed controls during the 3erformance of
surveillance tests. The drifting occurred wit 1out operator
actions. The inspectors reviewed and discussed the results of the
Unit 2 RCIC test performed on January 9 with operations and
engineering personnel. The inspectors also observed a
post-maintenance test of the Unit 2 RCIC system on January 10 (See
Section M1.3).
b. Observations and Findinas
The inspectors observed, reviewed, and discussed the results of
the operability surveillance tests for the Unit 1 RCIC Pump and
the Unit 2 HPCI Pump. The ins)ectors also observed maintenance
activities for the repair of t1e Unit 2 RCIC pump. The inspectors
Enclosure 2
.m, -. _ -. . - ,...
.
'
,
-
19
attended the operations pre-job and post-job briefings.. The
briefings were thorough and stressed effective communications,
procedure adherence. job assignments, responsibilities, and test
results.
The inspectors observed the following during the Unit 1 RCIC
turbine test:
-
The RCIC pump turbine was manually started and after one minute
into the test the turbine speed appeared to stabilize at about
4460 revolutions per minute (rpm), as required oy procedure
-
At approximately four minutes into the test the turbine speed
drifted up to 4500 rpm
-
The operator took control of the turbine and lowered the speed
to 4460 rpm and at eight minutes into the test the turbine
appeared to stabilize at that speed
-
At approximately 15 minutes into the test the turbine speed
started to drift up again
-
The test was completed at approximately 25 minutes and the
turbine speed had drifted up to 4490 rpm
The inspectors reviewed test results data which verified what the
ins)ectors had observed concerning the upward drift of the RCIC
tur)ine speed. During discussions with operators and engineers,
the inspectors were informed that the Control Room (CR) turbine
speed indication was 100 rpm lower than the actual turbine speed.
The inspectors observed the following during the Unit 2 HPCI
turbine test:
-
The HPCI turbine was started, came up to set speed, and
appeared to stabilize at 3865 rpm
-
Shortly after the speed stabilized, a gradual upward drift
began. At the end of the test, which lasted for 21 minutes,
the turbine appeared to be controlling at 3910 rpm
-
The lowest rpm observed by the inspectors was 3862 and the
highest was 3918 rpm
The inspectors found from the observations, discussions and
reviews taat the upward drift of the Unit 1 RCIC turbine speed was
not expected. The turbine speed drift should not have occurred
because of the design of the system. The system should have
stabilized around 4460 rpm instead of having a constant upward ;
l
l
Enclosure 2 j
l
l
i
l
-
'
.
20
drift. The system engineer, stationed locally at the Unit 1 RCIC
pump, assumed that the upward drift was due to operator action.
The upward drift observed on the Unit 2 HPCI turbine continued
throughout the test. The inspector discussed the observation of
the drift with operations personnel. Licensee personnel discussed
several possibilities for the deficiencies which included out of
calibration electronics, a test valve gradually clogging up with
debris, or a mechanical malfunction of the test valve. !
Subsequent to the Unit 1 RCIC turbine test a Unit 2 RCIC turbine
test was performed. During the test the operators observed i
significant changes in the speed of the Unit 2 RCIC turbine. The
I&C technicians informed the operators that the turbine control i
'
valve was receiving full open signals followed by full closed
signals on a continuous basis. The turbine control valve appeared
to go to the fully open position and immediately go to the fully
closed position. This caused observed fluctuations in turbine
speed of up to plus-or-minus 160 rpm. The operators declared the
Unit 2 RCIC system inoperable. The RCIC system engineer informed
the ins)ectors that the Unit 2 RCIC system would operate in this
manner )ut not for very long. The inspectors observed the
post-maintenance test of the Unit 2 RCIC and did not observe any
deficiencies.
c. Conclusions
The inspectors concluded that the maximum drift observed on the
Unit 1 RCIC turbine was 40 rpm. The upward drift of the Unit 2
HPCI turbine was about 45 rpm. The inspectors concluded that the
drifts could be an indication of pending failures. The erratic
speed control of the Unit 2 RCIC was a significant problem. This
was identified as IFI 50-321, 366/96-15-03: Resolution of RCIC
and HPCI Turbine Speed Control Drift Units 1 and 2. respectively.
M4 Maintenance Staff Knowledge and Performance
M4.1 Inadvertent Feedwater Heater Isolation.
a. Insoection Scooe (62707) J
The inspectors conducted a review of maintenance work activities,
reviewed documentation and discussed maintenance personnel
performance with licensee personnel with respect to an inadvertent
isolation of a Unit 2 feedwater heater,
b. Observations and Findinas
On January 5, during maintenance activities to replace a relay on
the 6th stage A heater steam trap bypass to the condenser. a fuse
Enclosure 2
.
. .. . - . _ - _ . .-. -- -- - _ ..- - -
.
.
.
.
21
blew. As a result, steam from the high pressure turbine to the
6th stage heaters was isolated, causing feedwater heater levels to
become erratic.
Operators observed that feedwater temperature decreased and
entered the abnormal procedure for loss of feedwater temperature.
Power was reduced to about 93.5% RTP. The blown fuse was
replaced, heater levels were stabilized and power was later
returned to 100% RTP. The relay, which remained in the energized
state even though the relay fuse had blown, was not immediately
replaced. The relay was replaced the following day after a work
plan was completed by engineering and maintenance personnel. The
inspectors noted that while similar relays had failed, sticking in
the energized condition was an unusual case.
The inspectors reviewed procedure 34AB-N21-001-2S: Loss of
Feedwater Heating. Revision 2. and observed that operators
initiated the correct actions for the plant transient.
The inspectors discussed maintenance personnel's actions involved
with the relay replacement with maintenance supervision. The
inspectors were informed that an I&C technician was in the process
of jumpering out the relay to be replaced had connected one end
of the jumper to a hot lead, and was routing the jumper through
the panel toward the other lead that was to be jumpered. The
jumper was inadvertently grounded blowing the fuse, and
initiating the transient.
The inspectors discussed expectations for jumper usage with
maintenance management. Management indicated that connecting a
jumper to a hot lead and then routing it through a panel did not
meet their expectations. The inspectors reviewed several
maintenance procedures and observed that general jumper usage and
expectations for jumper usage was lacking.
In April and May 1995. the licensee conducted an extensive review
of jumper types, and jumper usage at the site. This review was
conducted as a result of a reactor scram following operator
deficiencies using jumpers. The inspectors observed that as a
result of this licensee review, several recommendations for jumper
types and jumper usage, and written expectations were developed.
Most departments held special training sessions for jumper usage
and the proper types of jumpers to be used. Operations issued a
special procedure detailing operations management's expectations
for jumper usage.
The inspectors observed that maintenance management issued a
Maintenance Training Bulletin, dated April 1995, that dealt with
jum3er usage. The bulletin stated, in part, that personnel
autlorized to use jumper wires are expected to know and use the
Enclosure 2 1
__ __ _ _ _ _ _ _ _ _ _ _ ._ _ __ _ _ . _ _ ___
i
'
?
1 ..
-
_;
i
)
$ 22 :
~
,
correct type. Maintenance management informed the inspectors that i
proper jumper usage was taught in craft training and was primarily l
i considered skill of the craft. This maintenance jumper error that !
j initiated this feedwater level transient was being reviewed for ;
j human performance improvements. l
1 i
q c. Conclusions ;
I The inspectors concluded that this maintenance jumper error
demonstrated a poor work practice on the part of one individual. -
- Similar jumper usage error has not been a concern and this error
J was an isolated occurrence. Reviewing this error for human
j performance improvements was appropriate. ,
'
i M5 Maintenance Staff Training and Qualification
- MS.1 Maintenance Trainina and Qualification Review ,
j a. Insoection Scooe (62707) ,
'
. A review of maintenance training documentation was conducted to
! verify that personnel involved in the repair and maintenance of :
valves were appropriately trained and qualified. Also, the
training and qualification recuirements for valve maintenance were
- discussed with Maintenance anc Training staff members.
i
l. b. Observations and Findinas
- A review of training documentation for mechanics was conducted by )
i the inspectors. This review was conducted to determine the :
. qualification status of personnel assigned to perform valve )
- maintenance on safety-related and those non-safety-related valves
i that are within the purview of the Maintenance Rule. The
mechanical maintenance training staff informed the inspectors that
the training and cualification requirements were the same for work
l on both safety anc non-safety-related valves. The training staff
j maintains the training and qualification status of personnel in a
! computer data base referred to as the Training Records and
j Qualification System (TRAQS).
!
t The inspectors reviewed the following documents which provided the
] training and qualification requirements:
-
ANSI N18.1-1971: Selection and Training of Nuclear Power Plant
j Personnel
- -
HNP-2-FSAR-13: Section 13.1.3 Qualification Requirements for
Nuclear Plant Personnel and Section 13.1.3.1.16 Maintenance
'
l Personnel
Enclosure 2
2.
i
. . _
.,
23
-
10AC-MGR-007-05: Personnel Qualification Requirements. Rev. 5
-
DI-MNT-11-0287N: Qualification of Maintenance Personnel. Rev. 2
The inspectors were informed during a discussion with maintenance
staff members that there were some Building and Grounds (B&G)
personnel who were trained and qualified to perform valve packing.
These individuals are assigned to the various performance teams.
.
They perform valve packing activities as well as laborer type
work. A followup discussion with the mechanical maintenance
training staff indicated that these individuals attend a special
course to become qualified as Valve Packing Technicians. They are
provided training in mathematics, precision tools, torquing,
gasket replacement and valve packing. The instructions in this
special course is an excer)t from the curriculum for the mechanics
and the content of each su) ject area is the same. The successful
completion of this special course qualifies a B&G individual for a
Valve Packing Technician position on the Performance Team. The
names of these individuals are entered into the TRAQS computer
data base as being qualified.
The inspectors reviewed a sampling of MW0s associated with
mechanical work activities performed on valves by Mechanics and
B&G personnel. The MWO sampling included the following MW0s:
-
MWO 2-94-3430: 2B21-F013A. Replace SRV Top Works and Stump
-
MWO 1-95-2627: Prepare SRV Solenoid Valve Assembly and Stump
for Shipment to Wyle Laboratory ,
-
MWO 2-95-1035: Remove. Test. Replace / Repair RCIC Suction
Relief Valve l
-
MWO 1-95-2942: Clean and Torque Valve IN22-F6081
-
MWO 1-96-0089: Repack Valve Per 52CM-MME-001-0S I
'
-
MWO 1-95-2934: Inspect Valve IN22-F1114A for Packing
Adjustment / Repacking
! -
MWO 2-95-3370: Repair Galled Valve Stem on 2E11-F015B
! -
MWO 2-95-3639: Repair LPCI Valve 2 Ell-F015A Ball Stem / Valve
- Stem Coupler
-
MWO-2-94-1732: Perform Mechanical Portion of 52SV-T48-001-0S
,
!
i
Enclosure 2
i
!
_ . . _ .
a
.,
24
-
MWO-1-94-5335: Repair / Replace and/or Bench Test Relief Valve
IN22-F070A
-
MWO-1-96-1000: Repack Valve IN21-F023A
The names of the persons who aerformed the work activity as listed
in the MWO were compared to t1ose on the list of individuals
qualified to perform the work activity on TRAQS. No discrepancies
were identified in this comparison.
c. Conclusions
Personnel who perform mechanical maintenance on safety and
non-safety-related valves are trained and qualified in accordance
with the requirements of ANSI N18.1-1971. the FSAR, and other
applicable plant qualification procedures.
M8 Miscellaneous Maintenance Issues (92700) (92902)
M8.1 (Closed) VIO 50-321/96-06-04: Failure to Meet TS Surveillance
Recuirements Prior to Withdrawal of a Control Rod While in Cold
Shutdown
This Violation was identified when, on two occasions, licensee
personnel withdrew a control rod with accumulator pressure below
the TS requirement. The activities were performed for maintenance
purposes.
The licensee's response was provided in correspondence dated
July 10. 1996. The response indicated that procedure
34G0-0PS-066-05: Single Control Rod Withdrawal in Shutdown or
Refueling, was revised to clarify the requirement that an
accumulator pressure of equal to or greater then 940 pounds per
square inch gauge (psig) must be present before any rod
withdrawal. The inspectors reviewed the revised procedure. Based
on the reviews by the inspectors and the actions taken by the
licensee, this violation is closed.
M8.2 (Closed) LER 50-321/96-06: Inadeauate Procedure and lack of Work
Coordination Result in Withdrawal of Inocerable Control Rod
.
This problem was discussed in IR 50-321.366/96-06. No new issues
were revealed by the LER. This LER is closed.
Enclosure 2
_ _ _ . . _ ._ . . . _ _ _ _ _ _ _ _ _ . . _ _ _ .
!
.,
25
III. Enaineerina !
!
E2 Engineering Support of Facilities and Equipment
'
E2.1 Trio and failure to Start Problems For the Unit 1 A Standby liauid
Control (SLC) Pumo ,
a. Insoection Scooe (92903)
'
The inspectors reviewed engineering activities of an investigation
of the 1A SLC pump tripping and failure to start. A review of the ;
MW0s, work completed, procedures, and discussions with engineering
personnel were conducted.
b. Observations and Findinas
On January 10, during operations performance of a routine
operability surveillance, the 1A SLC pump tripped. The system was
declared ino)erable and actions to investigate the problem were 4
initiated. ,iaintenance found the motor overloads trip)ed. !
Maintenance later replaced a pump control switch and clanged the
overload relay setting from 100% to 115%, per a telephone
conversation with engineering personrel, and in addition meggered
the pump motor. Later, operations personnel ran the pump for
about 20 minutes and it ran properly.
On January 12. operations began another operability surveillance
during which the pump did not start on three attempts.
Maintenance personnel were contacted to investigate. A worn i
control switch block was identified as the problem and was
replaced. The pump then started properly.
,
During the investigation of this problem, technicians identified
4 that the overload heaters were not the size s?ecified in procedure
- '
52PM-R24-001-05: Allis Chalmers Low Voltage iCC Inspection,
Revision 12. The procedure specified that the overload heaters
should be size H80s, and size H78s had been installed.
'
,
Maintenance personnel installed the correct heaters and later
changed the relay setting to 125%. Engineering personnel were
'
contacted to investigate the problem with the overload heaters and
to further investigate the SLC pump tripping problem to ensure
that the correct failure mechanism was identified.
The inspectors discussed the discrepancy of the installed overload
l heaters with respect to procedural requirements with engineering
! personnel. The inspectors were informed that a work history
'
review had been completed back to about 1984 and no evidence of
heater overload changeout was observed. Documentation reviewed
'
did not indicate what size overload heaters should be installed or
when size H78 overload heaters were placed in the system.
i
,
Enclosure 2 !
i
l
'
l
.__ _
.
'
..
i
26 i
!
Engineering personnel stated that at some time P the past, size t
H78s may have been the correct size. Engineering personnel did l
not determine how the size H78 become installed in the system.
Engineering also indicated that the overload relay was suspected !
as the cause of the problem and not the size of the overload t
heaters. Maintenance personnel replaced the overload relay. Both i
the overload heaters and the overload relay that was replaced were
tested by engineering and revealed that the pump motor would have !
o)erated properly and within the expected overload condition of i
t1e pump motor.
During the procedure review and through discussions with
engineering personnel, the inspectors observed that procedure
guidance for determining the correct size of overload heaters was -
not clear. Engineering personnel stated that procedure
clarifications would be recommended.
c. Conclusions
l
The inspectors concluded that engineering personnel from NS&C -!
conducted a detailed review of the SLC pum) tripping problem and ;
consider this as a positive attribute of t1e engineering i
department effort. The inspectors also concluded that the SLC l
pump tripping problem was an isolated occurrence. The inspectors
-
did not consider that this installation of incorrect size overload
heaters was an example of poor configuration control or
contributed to the tripping problem.
E3 Engineering Procedures and Documentation l
l
E3.1 Review of Engineering Evaluations l
!
a. InsDeCtion SCoDe (37551) (92903)
'
The inspectors reviewed licensee activities and engineering
evaluations completed for electrically backseating two Primary
Containment Isolation valves. The licensee electrically
~
backseated the valves in an attemat to identify and reduce the
unidentified drywell leakage for Jnit 1. Reactor Water Cleanup .
(RWCU) Inboard Isolation valve 1G31-F001, and Reactor Core !
Isolation Cooling (RCIC) Inboard Isolation valve 1E51-F007, were !
electrically backseated on November 14 and December 27, 1996. i
respectfully. l
t
b. Observations and Findinas !
!
The inspectors reviewed an engineering evaluation conducted by I
corporate engineering and transmitted to the site by interoffice !
correspondence, dated February 21, 1994, for Backseating of ;
Enclosure 2 f
i
!
I
i
>
- - _- -- --- - _ ._
-
'
.
27
Motor-0perated Valves (MOVs) in the Drywell. The engineering
evaluation identified a total of 16 valves that were evaluated and
included both Unit 1 and Unit 2 valves. Post backseating
inspections were identified for some valves and no inspection was
identified for others. The evaluation specified the correct !
maintenance procedure used for electrically backseating the valves i
and identified that the plant maintenance procedure used to
backseat the valves currently required that the backseated valves
be disassembled and inspected for damage at the next opportunity.
The evaluation also identified the actuators for both valves were
to be inspected for damage to thrust components. ;
The evaluation addressed valve actuator torque ratings, active
thrust ratings and valve thrust limit in the open direction. The :
evaluation concluded that "the backseat may be damaged on many of 1
the valves in cuestion if they are electrically backseated. ,
However, this camage is not postulated to prevent the valve from i
performing its safety functions. Other valve components are not I
likely to be damaged by electrically backseating." '
The inspectors reviewed table 7.3-1 of the Unit 1 FSAR and
observed that the safety function of the valves was in the closed
direction. The safety evaluation satisfactorily addressed valve
closing requirements and stated that deformation of the backseat
would not prevent the valves from closing.
The inspectors also reviewed the interoffice correspondence
(memorandum) from site engineering to operations endorsing the
1994 corporate engineering evaluation and identified other
specific stipulations. The memorandum identified that the valves
duty cycle was 15 minutes and provided guidance for not exceeding
the duty cycle time. Also recommended was that administrative
controls be placed on a valve to inform operators that the valve
was backseated and to take actions to prevent thermal binding
during cooldown. The inspectors identified a weakness with the
administrative control placed on the valves. This and other
inspector identified deficiencies are discussed in section M3.2.
Also stipulated was that maintenance must generate or confirm the
existence of MW0's to perform repacking of the backseated valve.
The inspectors observed that the memorandum referenced maintenance
procedure. 52GM-MNT-034-05, as the procedure used to backseat the
valves. The correct procedure reference was 51GM-MNT-034-0S.
The inspectors discussed with engineering whether any changes to
the valves, valve motors or actuators were made since 1994 that
affected the evaluation. Engineering personnel stated that no
changes were made that affected the previously completed
evaluation.
1
Enclosure 2
l
.
-
.,
28
c. Conclusions
The inspectors concluded that the engineering evaluation for
electrically backseating valves located in the drywell was ,
satisfactory. The evaluation considered plant safety and !
identified actions to ensure continued system and component !
reliability. The typographical error on the procedure reference
'
in the memorandum was not a significant concern. j
E8 Miscellaneous Engineering Issues (92700) (92903)
l
E8.1 (Closed) LER Licensee Event Reoort (LER) 50-321/96-14: Incorrect :
Circuit Breaker Settina Results in Emeraency Diesel Generator l
Beina Inocerable. l
This problem was discussed in IR 50-321, 366/96-14. Sections M2.2
and E2.2, and was identified as an example of Violation
50-321. 366/96-14-03: Failure to Implement Configuration Control i
Requirements. The licensee determined during a system walkdown
that the overcurrent protection trip setpoint for the normal
sup}ly breaker to Motor Control Center (MCC) 1R24-S026. from the
IB 1mergency Diesel Generator (EDG). was not set properly. The
problem occurred as the result of a failure to incorporate
information developed in a design calculation into appropriate
electrical single line drawings and plant maintenance procedures.
Poor labeling for setting the breaker trip device was also a
contributor. The long time delay pickup of the trip device should
have been set at 450 amps but was left at 300 amps instead. This
problem made the IB EDG inoperable.
The licensee promptly initiated a temporary modification to remove
the largest load from this MCC and powered it from another source.
The trip device installed on the Unit 1 600-volt feeder breaker to
the subject MCC was disabled, leaving the upstream 4160-volt
feeder breaker to the MCC to provide overcurrent 3rotection.
Additional corrective actions will be to remove tie trip devices
from the primary and alternate feeder breakers on the bus by
June 15, 1997. The inspectors will review licensee activities to
complete the corrective actions, which are documented as IFI l
50-321/96-14-05: Restoration of IB EDG Motor Control Center. l
Based upon the inspectors review and licensee actions, the
issuance of an NOV and IFI. this LER is closed. I
E8.2 (Closed) LER 50-321/96-14. Rev 1.: Incorrect Circuit Breaker
Settina Results in Emeraency Diesel Generator Beina : nooerable. ]
This LER was discussed in Section E8.1 of this report. The LER j
corrected a date that licensee corrective actions will be ;
completed. No new issues were revealed by this revision to the l
LER. This LER is closed.
Enclosure 2
l
vr- w w m --
.
--- - . __.
-
.
\
,
29
E8.3 (Closed) IFI 321/96-07-03: Dearadation and Reolacement of Unit 2
Station Service Batterv 28 Due to Builduo of Cell Sediment.
This item addressed an observation of sediment buildup in the
cells of the Unit 2 Station Service Battery (SSB) 28. The vendor ,
determined that the buildup was due to a curing 3rocess at the !
factory. Of the 248 battery cells supplied for )oth trains of i
Unit 2. 56' cells showed signs of sediment. All of the cells were j
located among the 120 cells in SSB 28. At the end of the report
period sediment had not been observed in the cells of SSB 2A. The ,
licensee has received replacement cells from the vendor.
MWO 2-96-1929 has been issued to replace all 120 cells of SSB 2B -
during the upcoming Spring 1997 Unit 2 refueling outage. The MWO :
will be followed up as part of the inspectors * alanned outage ;
inspection activities. Based on the actions tacen by the
licensee, this item is closed.
E8.4 JClosed) LER 50-321/96-07: Failed Comoonent Results in i
- nadvertent Emeraency Diesel Generator Start. ;
'
This LER was issued on May 21, 1996, when the 1A EDG was
inadvertently started. Based on the actions taken by the
licensee, this item is closed.
E8.5 (Closed) LER 50-321.366/96-08: Inadeouate Procedure Results in
Reactor Pressure Increase and Automatic Reactor Scram.
This problem was discussed in IR 50-321.366/96-06. The inspectors
reviewed the revised procedure 3450-N32-001-1S: EHC Hydraulic
. System. Rev. 17. The inspectors also reviewed the previous
i revision. The inspectors observed that sections 7.3.1. System .
- Isolation With Bypass Capacity, and 7.3.2 Restoring the System to l
, Operation, had been deleted. This would preclude isolating l
1 portions of the Electro Hydraulic Control (EHC) system which )
! caused the increase in reactor pressure. Based on the actions
- taken by the licensee, this item is closed.
'
,
IV Plant Support
R1 Radiological Protection and Chemistry Controls
. 1
'
R1.1 General Radiological Controls
Insoection Scone (71750)
'
General Health Physics (HP) activities were observed during the
report period. This included locked high radiation area doors,
proper radiological postings, and personnel frisking upon exiting
the Radiologically Controlled Area (RCA). The inspectors made
i
Enclosure 2
1
. . . . _ . _ _ _ _ _ - _ _ _ _ _
-
.
,
30
frequent tours of the RCA and discussed radiological controls with l
HP technicians and HP management. No significant deficiencies '
were identified.
R1.2 Radiological Controls j
a. Insoection Scooe (83750) l
Radiological controls associated with ongoing operational
activities were reviewed and evaluated. Controls for both routine
operations and specific non-routine tasks were included in the
review In particular. housekeeping and cleanliness, area
postin s radioactive waste (radwaste) container labels, and
contro s for high radiation areas were reviewed for adequacy.
Licensee controls for ongoing operations were compared against
documented requirements in applicable sections of Technical i
Specifications (TSs). Final Safety Analysis Report (FSAR). and l
l
The inspectors made frequent tours of the RCAs. In addition. l
specific radiation work permit (RWP) procedural guidance and !
selected survey results were reviewed and discussed with
responsible HP staff and supervisors. Operations and radiological
controls associated with the low-level radioactive waste storage j
building were observed and evaluated. Controls for specific tasks '
performed in accordance with the following RWPs were evaluated in
detail.
e RWP 197-0005. Remove old obsolete drum capping equipment and
support work, effective January 10. 1997.
e RWP 097-0017. Process / ship / receive / load out/ transport
radioactive materials and support work including alpha trending
and Waste Separation and Temporary Storage Facility (WSTSF)
work, effective January 10, 1997.
In addition the inspectors reviewed and discussed program
guidance and results of internal exposure evaluations made by the
licensee during 1996.
b. Observations and Findinas
High and locked high radiation area controls were verified to be
implemented in accordance with TS requirements. Postings of
radwaste storage areas were proper and in accordance with TS or
10 CFR 20 Subpart J requirements. Overall, containers holding
radwaste, contaminated materials, and equipment were labeled in
accordance with 10 C.FR 20.1904 requirements. Excluding activities
associated with construction of a hot tool room and an isolated
example of trash and debris in the Unit 2 (U2) Radioactive Waste
Enclosure 2
.
.
'
.
,
l
31
(RW) building area 164 foot (*) elevation floor, cleanliness and
housekeeping within the RCAs. outside radwaste ]rocessing and
storage areas, and the low-level waste storage Juilding were
acceptable. Radiation control activities associated with ongoing
radwaste processing, storage and shipping operations were adequate
and conducted in accordance with applicable RWPs and procedures.
During facility tours, the inspectors observed several poor
radiological control practices associated with demolition of a
concrete wall located in the Unit 1 (U1) RW area 132' elevation. '
Demolition activities were in preparation for construction of a
hot tool room and were performed under RWP 197-0005. Remove Old ;
Obsolete Drum Capping Equi) ment and Support Work. effective
January 10.197 The wort area was roped-off equipped with a
step-off pad, cad posted as a Contaminated Area. On !
January 15. 1997, the ins)ectors noted that the demolition
activities generated visi)le and potentially contaminated dust
which subsequently became airborne and also covered the step-off
pad and areas surrounding the posted area. The only established
engineering control provided was use of a High Efficiency
Particulate Air (HEPA) filtered portable exhaust ventilation i
system but without an enclosure surrounding the work area. The
most recent quantitative contamination and air sample survey
results conducted on January 11, 1997, verified contamination on l
the wall. approximately 1000 to 3000
2
disintegration per minute per l
100 centimeters square (dpm/100cm ) but did not identify an
airborne hazard. However, the inspectors noted that no additional
airborne surveys were conducted within the work area and that the
most recent quantitative radiation surveys completed on
January 13. 1997, were in response to unexpectedly elevated
electronic dosimeter readings. !
Discussions with responsible HP and maintenance personnel
indicated that the tools used for the demolition changed and that
the staff was aware of the increased levels of potentially
contaminated dust outside of the designated area. Licensee
representatives stated that additional gross contamination surveys
of the floor conducted outside of the posted area using Masslin
cloth were conducted but not documented. Responsible HP personnel
stated that the gross surveys did not indicate any contamination
outside of the roped-off area. TS 5.4 requires that written
procedures be established implemented, and maintained covering
activities delineated in Appendix A of Regulatory Guide (RG) 1.33.
Rev. 2. dated February 1978. Regulatory Guide 1.33. Appendix A.
" Typical Procedures for Pressurized Water Reactor and Boiling
Water Reactors." Paragraph 7.e. requires radiation protection
procedures for Radiation Work Permit System and for Contamination
Control. Health Physics procedure 60AC-HPX-004-0S, Radiation and
Contamination Control. Revision (Rev.) 14. effective October 15,
1996, specifies that HP will: initiate controls, e.g..
Enclosure 2
L
_ ___ _ _ _ _.
.
. :
32
l
engineering controls, to ensure that spread of contamination is
minimized; will perform non-routine radiation and contamination
surveys as required, to support operation and maintenance: will -
perform airborne su veys during radioactive work which is expected
to cause airborne radioactivity unless constant air monitors are ,
provided: and perform periodic air sampling to evaluate the ;
effectiveness of filtered ventilation used to control airborne
radioactivity. The inspectors noted that the established
engineering controls and the contamination and airborne surveys
conducted for the observed demolition activities were not in ,
accordance with the established procedure.
]
The inspectors did not identify any significant concerns regarding ;
use of the whole body counter (WBC) equipment used for in vivo .
analyses and results. Excluding concerns identified for WBC
calibration guidance detailed in Paragraph R7.1. the applicable
licensee procedures were determined to be satisfactory and staff
knowledge adequate to implement the current program. Potential
procedural enhancements discussed with responsible licensee
representatives included: improved guidance for evaluating ;
potential internal exposure resulting from non-gamma-emitting i
radionuclides; collection methods for bioassay sam)les and
associated vendor capabilities; and inclusion of t1e standup WBC, t
currently used for qualitative (screening) analyses, in the l
crosscheck program. Results of all )ositive internal ex)osures of
workers analyzed in 1996 were less tlan one percent of tie Annual
Limits of Intake (ALIs) documented in 10 CFR Part 20.
'
c. Conclusions
Radiological controls for high and locked high radiation areas
were maintained in accordance with TS requirements. Area postings
and container radiation labels were appro)riate. Housekeeping and
cleanliness were adequate. In general, t1e licensee was
controlling internal exposure effectively. The poor engineering
controls and survey practices observed were identified as an
example of VIO 50-321, 366/96-15-05: Failure to Follow Procedures
for Contamination Control and for Deficiency Card Issuance for
Inadequate Bioassay Calibration Guidance.
R5 Staff Training and Qualifications in Radiation Protection and
Chemistry
a. Insoection Scone (83750)
General employee training provided to meet the requirements of
10 CFR Part 19. and specific training and medical certification.
required by 10 CFR Part 20 for persons who used or were designated
to wear respiratory protective equipment. were reviewed and
evaluated during the onsite inspection.
Enclosure 2
,
,
33
Selected 1996 training and medical certification records for
selected personnel within the following groups were reviewed and
discussed with responsible licensee representatives.-
e Personnel evaluated by the licensee for potential internal
exposure during 1996.
e All licensee and contract personnel involved in the transfer of
a full radwaste liner from the radwaste processing facilities
to a shipping cask during the week of January 13. 1997.
e All contract personnel involved with routine operations at the
low-level radioactive waste storage building.
b. Observations and Findinas
The inspectors verified that general employee and respiratory
protection training, and medical certifications were conducted in
accordance with training procedure 73TR-T-RN-001-0S General
Employee Training Programs. Rev. 9. effective June 1. 1996. The
guidance met the requirements of 10 CFR 19.13 and 10 CFR 20.1703.
Review and discussion of training records verified that all
)ersonnel met the required general employee training requirements.
rom review of training records and selected Respirator Device
Issuance Reports, the inspectors verified that all persons who
used respiratory protection equipment were trained and medically
certified in accordance with the applicable procedures.
c. Conclusions
General employee training and completed medical certifications for
personnel involved in licensed activities were conducted in
accordance with the a)plicable procedures and met the applicable
requirements of 10 CFR 19 and 10 CFR 20.
R7 Quality Assurance in Radiation Protection and Chemistry Activities
R7.1 In Vivo Ouality Control Analyses
a. Insoection Scooe (83750. 84750)
During the inspection, the 1996 quarterly Quality Control (OC)
cross-check results for the in vivo WBC quantitative (chair
geometry) radionuclide analyses were reviewed and discussed.
b. Observations and Findinos
For the first and fourth quarter cross-check samples, all results
for torso, lung and thyroid were in agreement with the vendor
Enclosure 2
j
-.. _ ._ ._ _ _ . _ _ _ ._._. . . _ _ . __. _.
!
.
l
.
i
!
34 !
i
values. Disagreements between selected licensee analysis results i
and the known values were identified for the second and third :
cuarters of 1996. -For the second quarter samples analyzed on !
Fay 23, 1996, the identified disagreements resulted from an <
improper calibration conducted April 23, 1996. Responsible i
licensee representatives stated that the improper calibration ,
resulted from misinterpretation of calibration guidance provided l
by the vendor software-driven calibration menu. .
!
From review of the applicable procedure and discus. ions with
cognizant licensee representatives, the inspectors determined that i
no changes to, nor 3rocedural warnings regarding applicable i
computer-based cali] ration menu were implemerted. A licensee ;
review of.the WBC chair in vivo analysis results determined that
the improper calibration had no significant effect on assignment l
of internal exposure for the two individuals who were evaluated i
using the WBC chair between the dates of the improper calibration l
and when the deficiency was identified and corrected. However,
the inspectors noted that the subject evaluations were not
documented. The inspectors noted that RG 1.33 recommends written
procedures for bioassay programs and that contrary to ,
administrative control procedure 10AC-MGR-004-05. Deficiency l
Control System, Rev.10. dated March 3,1996, a Deficiency Card i
for the calibration procedural inadequacy was not initiated. For
the third quarter, disagreements in results of the crosscheck
comparisons resulted from failure to load all the provided cross-
i check samples and did not affect the calibration accuracy.
1
'
c. Conclusions
Quality control cross-check analyses were conducted in accordance
with procedural requirements. However, the failure to issue a
. deficiency card was identified as an additional example of
procedural VIO 50-321, 366/96-15-05: Failure to Follow Procedures
- for Issuance of a Deficiency Card for Inadequate Bioassay
'
Calibration Procedural Guidance.
{ R8 Miscellaneous Radiation Protection and Chemistry Issues
l a. Insoection Scooe (83750. 84750. 86750)
I The status of selected radiation control and radwaste performance
, indicators was reviewed and discussed with licensee
j representatives.
i'
b. Observations and Findinas
i
'
Since 1993, annual dose expenditure per unit outage continued to
decrease. For 1996, dose expenditure was approximately 441
person-rem and was within the established goal of 575 person-rem.
,
Enclosure 2
i
w - - , , , , . . .r. , ,,.,-.r , .-
-v-- , . - - - - - - - -
. . - - . - - _ . - - _-- . _ _ - . _ - . - . - - - - - .- _
< .- l
i
35
For 1996, licensee representatives informed the inspectors that no I
abnormal effluent releases were identified. The 1996 dose !
estimates from both liquid and gaseous effluents were small l
percentages of the Offsite Dose Calculation Manual (ODCM) limits. l
No significant trends or changes in radiological environmental i
monitoring program sample radiological analyses were identified. l
!
c. Conclusions j
Radiation protection performance indicators verified that licensee ;
actions to control worker dose were effective and radiological ;
effluent releases were minimized. j
R8.1 (Closed) Insoector Followuo Item (IFI) 50-321. 366/95-05-01: -
Review Post Accident Samolina System (PASS) Proaram Enhancements. [
This item was opened pending completion of equipment modifications
and procedural changes identified for the PASS system by the !
licensee. From selected comparison of installed PASS equipment ,
with configuration control documents arid review of current j
procedures, the inspectors verified completion of modifications ,
and procedural revisions. On January 16, 1997, the inspectors ;
observed licensee representatives successfully demonstrate PASS ;
operability by collecting, processing, and analyzing a U2 reactor l
coolant system (RCS) liquid sample in accordance with Chemistry )
(CH) Sampling (SAM) procedure 64CH-SAM-020-0S, Rev. 1. From
review of selected August 1996 through January 1997 PASS In-Line
Analyses records and discussions with the licensee, the ins)ectors
verified that both containment air and RCS samples from bot 1 U1
and U2 were collected and processed by chemistry personnel using
the PASS equipment on a routine basis. Excluding several
instances of low RCS pH determinations relative to reference
samples, no other analysis accuracy issues were identified. The
licensee stated that a review of the low pH values would be
conducted. As of November 1996. PASS availability was listed as
95 percent in licensee maintenance records. Based on licensee
actions and current system reliability. this item is closed.
R8.2 (Closed) Unresolved Item (URI) 50-321. 366/96-14-07: Determine if
Certificate of Comoliance (C0C) and Associated Vendor Documents
for Packaae No. USA /5805/B() Were Controlled in Accordance with
Administrative Procedure 20AC-ADM-003-05. Vendor Manual Review and
Control.
During review of C0Cs and associated documentation for package
type USA /5805/B() used for an August 7, 1996 Type B shipment of
irradiated hardware to a licensed burial facility, the inspectors
determined that current manuals and procedures were received
directly by the radaaste staff from the vendor. However, the
inspectors noted that the subject documents may not have been
Enclosure 2
..- .- - - - . . -- . --- . . - .- - . - - . -
u *
,
,, j
36
i
reviewed and controlled in accordance with the applicable
administrative procedure, and thus may not have met the intent of i
10 CFR 70.113 quality assurance (0A) requirements for shipping
program activities. A review of licensee records identified that
the C0C and procedures were maintained in accordance with the
applicable administrative procedure. However, the licensee was
unable to demonstrate that the subject manual was received. !
reviewed, processed, and maintained in accordance with the subject
administrative control procedure. All other documents associated
with shi) ping containers which were, or could be used to make ,
Type B slipments were maintained in accordance with the licensee *s
procedure. 1
Prior to the current inspection. the licensee requested all
uncontrolled copies of C0Cs. and associated documents from staff
members involved in transportation activities. The inspectors
reviewed a January 7.1997, letter confirming that a single copy
of shipping container documents would be sent to the licensee.
Consistent with Section IV of the Enforcement Policy based on !
corrective actions taken prior to the end of the inspection, this i
issue was identified as Non-cited Violation (NCV) t
50-321, 366/96-15-06: Failure to Maintain Shipping Cask Manuals in !
Accordance with Established Procedures to Meet 10 CFR Part 70.113.
52 Status of Security Facilities and Equipment !
The inspectors toured the protected area and observed that the ;
perimeter fence was intact and not compromised by erosion nor i
disrepair. The fence fabric was secured and barbed wire was i
angled as required by the licensee's Plant Security Program (PSP).
Isolation zones were maintained on both sides of the barrier and ;
were free of objects which could shield or conceal an individual. !
The inspectors observed personnel and packages entering the
protected area were searched either by special purpose detectors
or by a physical patdown for firearms, explosives and contraband. ;
Badge issuance was observed, as was the processing and escorting ,
of visitors. Vehicles were searched, escorted and secured as !
described in the PSP. )
The inspectors concluded that the areas of the PSP inspected met
the PSP requirements.
V. Manaaement Meetinos ,
X. Review of UFSAR Commitments l
A recent discovery of a licensee operating its facility in a i
manner contrary to the Updated Final Safety Analysis Report
(UFSAR) description highlighted the need for a special focused
review that compares plant practices, procedures and/or parameters
Enclosure 2
l
l
.
'
k e,
37
to the UFSAR description. While performing the ins)ections
discussed in this re) ort, the inspectors reviewed t1e applicable
portions of the UFSAR that related to the areas inspected. The
inspectors verified that the UFSAR wording was consistent with the
observed plant practices procedures, and/or parameters.
X.1 Exit Meeting Summary
The inspectors presented the inspection results to members of the
licensee management-at the conclusion of the inspection on
January 31, 1997. The licensee acknowledged the findings
presented. An interim exit was conducted on January 17, 1997.
The inspectors asked the licensee whether any materials examined
during the inspection should be considered proprietary. No
proprietary information was identified.
X.2 Refueling Outage Management Meeting
The inspectors attended several Outage Management Meetings
conducted at the site. Among the items discussed were: The
Fall 1997. Unit 1 outage status: the Spring 1997. Unit 2 outage
status: the Unit 2 maintenance planning update: the Unit 2 scope
additions: the status of outage requisitions; and the status of
design changes. The ins ectors observed that the critical path
was identified as the hi h pressure turbine modifications. A fuel
'
shuffle, and not a fuel ff load, will be performed. However. the
>
visual inspection of the vessel internal core spray piping could
'
impact the outage schedule. The inspectors concluded that the
. outage is well planned. with realistic goals, with adequate
support.
! X.3 Management Meeting in Region II Office
i
i A licensee-requested meeting was held in the Nuclear Regulatory
Commission (NRC) office in Atlanta. Georgia on January 8.1997.
.
The purpose of the meeting was to discuss Georgia Power Company's
! Self-Assessment for the Hatch nuclear plant. The NRC concluded
>
that the meeting was beneficial in that it provided a better
t understanding of accomplishments and improvement initiatives at
the Hatch facility. A meeting summary was documented under
separate correspondence dated January 9. 1997.
l
.
4
Enclosure 2
- --_
.
i
,
, ..
!
1
38 ,
\
PARTIAL LIST OF PERSONS CONTACTED )
Licensee
Anderson, J., Unit Superintendent ;
Betsill, J., Operations Manager !
Coggin C., Engineering Support Manager i
Curtis, S., Operations Support Superintendent !
Davis D., Plant Administration Manager !
Fornel, P., Performance Team Manager *
Fraser, 0., Safety Audit and Engineering Review Supervisor
Hammonds, J., Regulatory Compliance Supervisor
Kirkley, W., Health Physics and Chemistry Manager
Lewis, J., Training and Emergency Preparedness Manager
Moore, C,. Assistant General Manager - Plant Support
Reddick, R., Site Emergency Preparedness Coordinator
Roberts, P., Outages and Planning Manager ;
Sumner, H., General Manager - Nuclear Plant !
Thompson, J., Nuclear Security Manager :
Tipps, S., Nuclear Safety and Compliance Manager >
,
Wells, P., Assistant General Manager - Operations
l
!
-
'
INSPECTION PROCEDURES USED
IP '551: Onsite Engineering
IP 90500: Effectiveness of Licensee Controls in -
Identifying, Resolving, and Preventing Problems l
IP 61726: Surveillance Observations
IP 62700: Maintenance Implementation
IP 62703: Maintenance Observations
IP 62707: Maintenance Observations
IP 71707: Plant Operations
IP 71714: Cold Weather Preparations
IP 71750: Plant Support Activities
IP 83750: Occupational Radiation Exposure
IP 84750: Radioactive Waste Treatment and Effluent and
Environmental Monitoring
IP 86750: Solid Radioactive Waste Management and
Transportation of Radioactive Materials
IP 92700: Onsite Follow-up of Written Reports of Nonroutine
Events at Power Reactor Facilities
IP 92901: Followup - Operations
IP 92902: Followup - Maintenance / Surveillance
IP 92903: Followup - Followup Engineering I
IP 92904: Followup - Plant Support j
l
I
Enclosure 2
!
. ._ _ _ - _.a
_ . _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ . _ _ _. . - _ _
,
_7
s . .. ' ?
!
l
39
i
ITEMS OPENED. CLOSED. AND DISCUSSED '
l
Ooened j
50-366/96-15-01 NCV Inadequate Procedures for Replacement of the
Unit 2 Drywell Hydrogen Recombiner Flow
Controller Batteries and Establishing the l
j
Required Controller " Dead Band" Following
Certain Maintenance Activities identified
(Section M2.1). j
50-321/96-15-02 VIO Maintenance Personnel Failure To Follow
Procedure During Valve backseating Activities i
(Section M3.2). I
!
'
50-321.366/96-15-03 IFI Resolution of RCIC and HPC1 Turbine Speed
Control Drift Units 1 and 2. respectively ;
(Section M3.3).
50-321.366/96-15-04 IFI Switchyard Maintenance and Material Condition
(Section M1.4).
50-321.366/96-15-05 VIO Failure to Follow Procedures for Contamination l
Control and for Deficiency Card Issuance for 1
Inadequate Bioassay Calibration Guidance l
(Sections R1.2 and R7.1). l
50-321.366/96-15-06 NCV Failure to Maintain Ship)ing Cask Manuals in l
accordance with Establisled Procedures to Meet '
10 CFR Part 70.113 (Section R8.2). !
Closed
50-366/96-15-01 NCV Inadequate Procedures for Repl6 cement of the
Unit 2 Drywell Hydrogen Recombiner Flow ,
Controller Batteries and Establishing the ,
Required Controller " Dead Band" Following
Certain Maintenance Activities (Section M2.1).
50-321.366/96-15-06 NCV Failure to Maintain Ship)ing Cask Manuals in
Accordance with Establisled Procedures to Meet
10 CFR Part 70.113 (Section R8.2).
50-321.366/96-14-07 URI Deteimine if Certificate of Compliance (C0C) and
Associated Vendor Documents for Package
No. USA /5805/B() Were Controlled in Accordance
with Administrative Procedure 20AC-ADM-003-0S.
Vendor Manual Review and Control (Section R8.2).
Enclosure 2
.
.
. ..
40
50-321/96-14 LER Incorrect Circuit Breaker Setting
Results in Emergency Diesel Generator Being
Inoperable (Section EB.1).
50-321/96-14. R1 LER Incorrect Circuit Breaker Setting
Results in Emergency Diesel Gcnerator Being
Inoperable (Section E8.2).
50-321.366/96-08 LER Inadequate Procedure Results in Reactor Pressure
Increate and Automatic Reactor Scram
(Section E8.5).
50-321/96-07 LER Failed Com)onent Results in Inadvertent
Emergency )iesel Generator Start (Section E8.4).
50-321/96-07-03 IFI Degradation and Replacement of Unit 2 Station
Service Battery 2B Due to Buildup of Cell
Sediment (Section E8.3).
50-321/96-06 LER Inadequate Procedure and Lack of Work
Coordination Result in Withdrawal of Inoperable !
Control Rod (Section M8.2).
50-321.366/95-05-01 IFI Review Post Accident Sampling System (PASS)
Program Enhancements (Section R8.1). l
S0-321/96-06-04 VIO Failure to Meet TS Surveillance Requirements
Prior to Withdrawal of a Control Rod While in
Cold Shutdown (Section M8.1).
1
!
!
!
Enclosure 2
!
-- .
- .. *
,
41
LIST OF ACRONYMS USED l
l
ALARA- As Low as Reasonably Achievable ;
ALI -
Annual Limit of Intake i
ANSI - American National Standards Institute i
B&G - Building and Grounds l
BOST - Beginning Of Shift Training
CFR - Code of Federal Regulations
AGM-PS- Assistant General Manager, Plant Support 1
CH - Chemistry ;
cm - centimeter l
C0C - Certificate of Compliance :
CR -
Control Room ;
- F - degrees Fahrenheit j
DC - Deficiency Card t
DG - Diesel Generator
dpm -
disintegrations per minute
ECCS - Emergency Core Cooling Systems i
EDG - Emergency Diesel Generator !
EGM -
Electronic Governor Motor i
EHC - Electro Hydraulic Control
FME - Foreign Material Exclusion
FSAR - Final Safety Analysis Report
GPC -
Georgia Power Company
HEPA - High-Efficiency Particulate Air Filters
HNP -
Hatch Nuclear Plant
HP - Health Physics
HPCI - High Pressure Coolant Irjection
HRS - Hydrogen Recombiner System
I&C -
Instrument and Control
IFI -
Inspector Followup Item
IR -
Inspection Report
IST -
Inservice Testing
KW -
Kilowatt
KVAR - Kilovolts Ampere Reactive
LER - Licensee Event Report
LPCI - Low Pressure Coolant Injection
MCC - Motor Control Center
MG - Motor Generator
MOV - Motor Operated Valve
MWO - Maintenance Work Order
NCV -
Non-Cited Violation
NRC - Nuclear Regulatory Commission
, NRR - Nuclear Reactor Regulation
i NS&C - Nuclear Safety and Compliance ,
ODCM - Offsite Dose Calculation Manual l
i PASS - Post Accident Sample System
PDR -
Public Document Room
, PE0 -
Plant Equipment Operator
PM - Preventative Maintenance
.
- Enclosure 2
l
,
h-
- -
. - _ - - .. . - - . - _ , , . - , _ _ . _ - . - - _ - _ . _ , _ _ _
t
"
..
3
42
PSIG - Pounds Per Square Inch Gauge
PSP - Plant Security Program
PSW - Plant Service Water System
OA - Quality Assurance
QC - Quality Control
RCA - Radiologic 61 Controlled Area
RCIC - Reactor Core Isolation Cooling
Rev - Revision
RG - Regulatory Guide
RHRSW- Residual Heat Removal Service Water
RPM - Revolutions Per Minute
RPS - Reactor Protection System
RR - Reactor Recirculation
RTP - Rated Thermal Power
RW - Radioactive Waste
RWCU - Reactor Water Clean-up
RWP - Radiation Work Permit
SAM - Sampling
SCBA - Self Contained Breathing Apparatus
SCFM - Standard Cubic Feed Per Minute
SLC - Ltandby Liquid Control
SRM - Source Range Monitor
SSB - Station Service Battery
TRAQS- Training Record and Qualification System
TRM - Technical Requirements Manual
TS - Technical Specifications
Ul.U2- Unit 1. Unit 2
UFSAR- Updated Final Safety Analysis Report
URI - Unresolved Item
VAC - Volts Alternating Current
VIO - Violation
WBC - Whole Body Counter
WSTSF- Waste Separation and Temporary Storage Facility ,
I
1
1
Enclosure 2