IR 05000528/1988012
| ML17303B145 | |
| Person / Time | |
|---|---|
| Site: | Palo Verde  |
| Issue date: | 05/11/1988 |
| From: | Jim Melfi, Richards S NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION V) |
| To: | |
| Shared Package | |
| ML17303B143 | List: |
| References | |
| RTR-REGGD-01.097, RTR-REGGD-1.097 50-528-88-12, 50-529-88-12, 50-530-88-12, NUDOCS 8805310260 | |
| Download: ML17303B145 (27) | |
Text
U.
S.
NUCLEAR REGULATORY COMMISSION
REGION V
Report Nos:
Docket Nos.
License Nos.
Licensee:
50-528/88-12, 50-529/88-13, 50-530/88-12 50-528, 50-529, 50-530 NPF-41, NPF-51, NPF-74 Arizona Nuclear Power Project P.
0.
Box 52034 Phoenix, Arizona, 85072-2034 Facility Name:
Palo Verde Units 1, 2, and
Inspection at:
Palo Verde Nuclear Generating Station Units I, 2, and 3.
Inspection Conducted:
April 4 - April 8, 1988 Inspectors:
g.
F. Melfi, Re ctor Inspector Other Accompanying Personnel:
A.
C.
Udy, NRC Contractor, INEL B. Marcus, Inspec or, SICB, NRR Approved By:
S.
A. Richards, Chief, Engineering Section
~Summa r wii 88 Date Signed li SS Date Signed Ins ection on A ril 4 1988 - A ril 8 1988 Re ort 50-528/88-12 50-529/88-13 50-530/88-12 Areas Ins ected:
A special announced inspection of representative subsystems of the post-accident monitoring system at the Palo Verde Nuclear Generating Station (PVNGS), Units 1, 2, and 3.
This inspection assessed the conformance of, Palo Verde to commitments made to Regulatory Guide 1.97, Revision 2.
Inspection procedures 30703 arid 25587 were used during this inspection.
This report addresses Safety Issue Management System (SIMS) i'ssue number 67.3.3 Results:
Of the area inspected, 1 deviation was identified.
8805310260 880512 PDR ADOCK 0500052S
DETAILS Persons Contacted Arizona Nuclear Power Pro 'ect
"J. Driscoll, Assistant Vice President
"T. Shriver, Compliance Manager
"L. Papworth, gA Director
"K. McCandless-Clark, Compliance Engineer
"W. guinn, Nuclear Safety and Licensing Director
"G. Sowers, Engineering Manager
"R.
Rouse, Compliance Engineer
"E. Sterling, Engineering Manager
"J. Kirby, Site Services Director
"D. Stover, Acting Nuclear Safety Manager A. Hertwig, System Engineer J.
Hebison, I8C Lead Engineer D.
Legg, System Engineer B. McCaskey, Surveillance Program Coordinator G. Anderson, System Engineer R. Black, Instrumentation Engineer K. Cutler, Instrumentation Supervisor T.
Dodge, Computer Systems Engineer B. Preusser, System Engineer C. Schmitt, System Engineer L. Spiers, Procurement guality Supervisor M. VanDop, System Engineer M. Watford, Plant Standards Consultant D. Withers, Electrical Lead Engineer USNRC
"T. Polich, NRC Sr.
Resident Inspector
~Attended Exit Meeting, April 8, 1988.
The inspectors also held discussions with other licensee and contract personnel during the inspection.
This included plant staff engineers, technicians, administrative and clerical assistants.
Introduction The purpose of this inspection was to compare the installed plant instrumentation with the licensee's commitments contained in correspondence related to Post-Accident Instrument'ation as described in the NRC Safety Evaluation Report (SER).
This inspection also assessed if the instrumentation meets the criteria specified in Regulatory Guide 1.97.
Some of the references used to assess the licensee conformance to Regulatory Guide 1.97 were:
Regulatory Guide 1.97, Revision 2, "Instrumentation for Light Water-Cooled Nuclear Power Plants to Assess Project and Environs Conditions During and Following an Accident"
Palo Verde Nuclear Generating Station (PVNGS) Final Safety Analysis Report (FSAR), Chapters 1 and 7.
Technical Evaluation Report prepared for the NRC by EG&G Idaho Inc.,
"Conformance to Regulatory Guide 1.97, Palo Verde Nuclear Generating Station, Unit Nos.
1, 2, and 3", December 1984, EGG-EA-6485.
Generic Letter 82-33 issued Supplement 1 to NUREG-0737, which specified those requirements regarding emergency response capability that had been approved by the NRC.
This supplement also discussed in part the application of Regulatory Guide (RG) 1.97 to the emergency response facilities, including the Control Room (CR), Technical Support Center (TSC) and the Emergency Operations Facility (EOF) at power plants.
The licensee's response to RG 1.97 was provided in letters dated April 14, 1983, August 1, 1984, August 30, 1984 and December 5, 1984.
In general, the inspection verified that the licensee had documentation readily available onsite that showed the redundancy, physical and electrical separation, power sources and interfaces for the instrumentation.
The g and Eg master equipment lists were reviewed for the instruments selected, to ascertain whether they had been evaluated and tested to the appropriate environmental, quality assurance (gA) and seismic qualification requirements.
The environmental qualification (Eg)
tests are tabled below for the instruments by showing the Eg listing or the environment that that component is located in.
A mild environment does not need any special qualification.
The seismic listing shown below notes the class to which that equipment is qualified to, Class 1 being the highest.
The gA procurement of these instruments was also reviewed and no problems were identified with the procurement.
Regulatory Guide 1.97 divides Post-Accident instrumentation into 3 categories and 5 types.
The three categories are noted as 1, 2, and 3.
Category 1 has the most stringent requirements and category 3 the least stringent.
The five types of instrumentation identified in the Regulatory Guide are types A, B, C, 0, and E.
Type A are plant specific and classified by the licensee; type B variables provide information to indicate that plant safety functions are being accomplished; type C
variables provide information on the breach of barr'iers for fission product release; type D variables indicate the operation of individual safety systems; and type E variables are those that indicate and determine the magnitude of the release of radioactive materials.
Each variable type can be any category, except for type A, which can only be category l.
The specific information on the instrumentation inspected is discussed in paragraph 3.
Except as noted, the requirements for the Class 1 and Class 2 instruments were me.
Ins ection Details The inspectors held discussions with various members of the licensee's staff, examined drawings, and walked through the control room to assess the implementation of the requirements delineated in Regulatory Guide 1.97, Revision 2.
The Control Room for Units I and 3 were inspected.
All three of these units employ the same design and similar instrument numbers.
For the category I instrumentation, the power is supplied by Class-1E buses.
The licensee has installed a gualified Safety Parameter Display System (gSPDS)
which is a fully qualified data acquisition and display system.
Several of the instruments inspected were recorded on the gSPDS, instead of on separate, individual qualified recorders.
The recording and display on the gSPDS meets the requirements of Regulatory Guide 1.97.
3.1 The following instrumentation was examined.
Neutron Flux Regulatory Guide 1.97 classifies this as a Category I variable.
The licensee's instrumentation for this variable has continuous indication over the range of 2 E-8 percent to 200 percent of full power.
This is displayed on log scale indicators.
There is also a non-seismically qualified recorder which displays this information for both channels.
This non-seismic recorder is optically isolated from both instrument loops by fully qualified Foxboro isolators.
The instrumentation automatically switches from the pulse mode to the current mode for continuous indication.
The seismic recording is done by the gSPDS.
Information on the neutron flux instrumentation was as follows:
Equipment Number Eg Function Listed Seismic Listed Power Instrument Division Ran e
SEA-NE-001A SEA-NT-001A SEA-J I-001A Detector ICE-3553 Class I Preamp Mild Class I Indicator Mild Class I 2 x 10 to 200Ã power SEB-NE-001B Detector ICE-3553 Class
SEB-NT-001B Preamp Mild Class
A SEB-JI-001B Indicator Mild Class I Ins ection Findin s 2 x 10 to 200K power The neutron flux level is provided to the operator on continuous indicators and on a recorder (not listed above) that is common to and
, isolated from both channels.
The channels are also recorded on the gSPDS.
The neutron flux instrumentation was found to meet the Category
recommendations specified in Regulatory Guide 1.97, Revision 2.
The neutron flux instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendation.2 RCS Hot and Cold Le Water Tem erature The licensee has determined this variable to be Type A.
This Category
instrumentation is used, in part, to ensure the proper cooldown rate and to maintain the proper relationship between system temperature and pressure.
Each of the two hot legs and four cold legs of the reactor is monitored by 200 ohm resistance temperature detectors (RTDs).
Information on the RCS hot and cold leg water temperature instrumentation was as follows:
Equipment Number Function EQ Listed Sei smic Listed Power Instrument Divisi on Rancae RCA-TE-112C1 RCA-TT-112C1 RCA-TR-112 RCA-TE-112H1 RCA-TT-112H1 RTD Transmitter Recorder RTD Transmitter ICE-3541 Mild Mild ICE-3541 Mild Class
Class
Class
Class
Class
A A
50F to 750 F
Recorded on RCA-TR-112 RTD Transmitter Recorder RTD nsmitter RCA-TE-122C1 RCA-TT-122C1 RCA-TR-122 RCA-TE-122H1 RCA-TT-122H1 Transmitter RTD Transmitter RCB-TE-112 H2 RCB-TT-112H2 Tra RGB-TE-112 C2 RTD RCB-TT-112C2 ICE-3541 Class
Mild Class
Mild Class
ICE-3541 Class
Mild Class
ICE-3541 Class
Mild Class
ICE-3541 Class
Mild Class
B
F to 750 F
Recorded on RCA-TR-122 Recorded on QSPDS only Recorded on QSPDS only RCB-TE-122C2 RCB-TT-122C2 RCB-TI-122-1 RCB-TE-122H2 RCB-TT-122H2 RTD Transmitter Indicator RTD Transmitter ICE-3541 Class
Mild Class
Mild Class
ICE-3541 Class
Mild Class
50 F to 750 F
W 0 Indicated on RCB-TI-122-1 Ins ection Findin s
The temperature of the hot legs and the cold legs of the reactor is available to the operator on redundant channels.
One channel has two hot leg and two cold leg temperatures recorded;.the other channel has one hot leg and one cold leg temperature indicated, and one hot leg and one cold leg temperature input to the QSPDS only.
All channels are on the QSPDS.
The instrumentation for these variables was found to meet the Category
recommendations specified in Regulatory Guide 1.97, Revision 2.
All of the above instrumentation was found to be. in calibration.
The inspectors found the instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendation.3 RCS Pressure Seismic Power Instrument Listed Division
~Ren e
The licensee determined this to be a Type A variable.
This Category
instrumentation is used, in part, to verify the correct relation between system pressure and temperature.
Information on the RCS pressure transmitters and recorder follows:
Equipment EQ Number Function Listed RCA-PT-190A RCA-PR-102 RCB-PT-190B Transmitter Recorder (shared)
Transmitter ICE-3535 Class
A Mild Class
A 0 to 4000 psig ICE-3535 Class j.
B Input to QSPDS Ins ection Findin s The A channel is displayed on a recorder that also displays the pressurizer pressure (0 to 3000 psig).
Both channels are also displayed by the QSPDS.
The RCS pressure sensing equipment and readout capabilities meet the Category 1 recommendations as specified in Regulatory Guide 1.97, Revision 2.
All of the above instrument loops were found to be in calibration.
The inspectors found this instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendations.
De rees of Subcoolin The licensee has determined that this is a Type A variable.
One method of calculating this variable is based on the hot leg and cold leg temperatures and the pressurizer pressure.
These channels are referred to as the RCS subcooling channels.
Another method of calculating this variable is based on the core exit temperature (a weighed average)
and pressurizer pressure.
These channels're referred to as the CET subcooling channels.
A third method of calculating this variable is based on the highest temperature of the top three unheated thermocouples in the reactor vessel level instrumentation.
This method is displayed on demand only.
All three methods are recorded on the QSPDS.
Only one channel (the A channel) of the first two methods is displayed on a dedicated indjcator.
RCS subcooling is indicated on SHA-TI-3 with a range of +200 to -200 F.
CET subcooling is indicated on SHA-TI-4 with a range of +200 to -800 F.
All channels are available on QSPDS and plant
0 computer call up displays.
Ins ection Findin s
The inspection revealed two di~crepancies>
The CET subcooling range documented in the FSAR is +700 F to -2100 F.
The indicated range is
+200 F (subcooled)
to -800 F (superheat)
for the CET monitor>
For the RCS monitor, the indicated range is +200 (subcooled) to -200 F
(superheat).
The indicators are labeled subcooled and superheat except for the Unit 3 RCS monitor.
The ranges provided by the instrumentation exceed the recommendations in the Regulatory Guid The licensee was informed of these discrepancies.
The documentation will be updated to show the indicated ranges.
The inspectors were informed that the Unit 3 RCS monitor will be labeled for subcooled and superheat.
This will be followed up in a future inspection report (50-528/88-12-01).
The licensee's.instrumentation was otherwise found to be in compliance with the recommendations of Regulatory Guide 1.97, Revision 2.
3.5 Containment Sum Water Level - Wide Ran e
Regulatory Guide 1.97 recommends Category 1 instrumentation for this variable.
Revision 2 of Regulatory Guide, 1.97 recommends a range of 0 to 600,000 gallons.
The licensee's documentation provides assurance that the provided range (6 inches to 150 inches) is inclusive of the upper limit of 600,000 gallons.
The narrow range instrumentation covers the actual sump level and provides overlap with the lower limit (6 inches) of the wide range containment level channels.
The narrow range level instrumentation was not inspected.
Information on the wide range containment level transmitters, indicators and recorder follows:
Equipment Number Function EQListed Seismic Listed Power Instrument Oivision Ran e
SIA-LT-706 SIA-LI-706 UR-9 SIB-LT-707 SIB"LI-707 Transmitter 13-JN-475
'ndicator Mild Recorder Mild Transmitter 12-JN-475 Indicator Mild Class
Class
Cl ass
Class
Class
6 to 150 inches 6 to 150 inches 6 to 150 inches Ins ections Findin s
The wide range containment water level is available to the operator on redundant indicators and on'
recorder for channel A.
The inspectors noted that recorder UR-9 is a dual channel recorder shared with containment hydrogen concentration.
The instrumentation was found to meet the Category 1 recommendations specified in Regulatory Guide 1.97, Revision 2.
The containment water level instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendations.
3.6 Containment Pressure The licensee has determined that this is a Type A variable.
Two Category 1 channels are used to monitor post-accident containment conditions and the performance of those engineered safety features designed to control the post-accident containment environment.
'Information on the wide range pressure transmitters, indicators, and recorder follows:
Equipment Number Function EQ Listed Seismic Power Instrument Listed Oiv.
~Ren e
HCA-PT"353A HCA"P I-353A Transmitter Indicator 13-JM-311 Mild Class
A.
Class
-5 to
+180 psig
e Equipment Number HCA-PR-353A HCB-PT-353B HCB-PI-353B Function Recorder Transmitter Indicator EgListed 13-JN-311 Mild Seismic Listed
~Casa
Class
Class
Power Div.
Instrument Ran e-5 to
+180 psig-5 to
+180 psig Ins ection Findin s
3.7 The containment pressure is available to the operators on redundant indicators and on a recorder for Channel A.
The instrumentation was found to meet the Category 1 recommendations specified in Regulatory Guide 1.97, Revision 2.
The containment pressure instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendations.
Containment H dro en Concentration The licensee has determined this to be a Type A variable.
Some of the uses for this Category 1 instrumentation include long term surveillance of the containment for potentially explosive concentrations of hydrogen and to determine that accident mitigation is being accomplished successfully.
Information on the containment hydrogen concentration instrumentation follows:
Equipment Number Function Eg Listed Seismic Power Instrument Listed Division
~Ran e
HPA-AIT-9 HPA-AI-9 UR-9 HPB-AIT-10 HPB-AI-10 Transmitter and Local Indicator Indicator Recorder Transmitter and Local Indicator Indicator Mi 1 d Mild 13-JN-359 Class
--
0 to 10%
Class
A
'
to 10K Class
B 0 to lOX Mild Class
0 to 10'X 13-JM-359 Class
A 0 to 10K Ins ection Findin s
e 3.8 The containment hydrogen concentration is available to the operator on redundant indicators and on a recorder for channel A.
The inspectors noted that recorder UR-9 is a dual channel recorder shared with wide range containment water level.
The instrumentation was found to meet the Category 1 recommendations specified in Regulatory Guide 1.97, Revision 2.
The containment hydrogen concentration-instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendations.
RHR Flow/LPSI Flow The residual heat removal (RHR) system consists of pumps, valves, heat exchangers and piping used to remove decay heat from the reactor core.
The RHR system motive power consists of the low pressure safety injection (LPSI) pumps (LPSI flow was a variable to be inspected)
and the containment spray (CS)
pumps (CS flow was not a variable included in the
inspection).
The containmen$
spray pumps can be used when the RCS temperature is less than 200 F.
One instrument loop is provided for each redundant flow train.
Information on the flow transmitters and indicators for the variables LPSI flow and containment spray flow follows:
Equipment EQ Power Instrument b
F i
Li d
iii
~R SIA-FT-306 SIA-FI-306 SI 8-FT-307 SI B-FI-307 SIA-FT-338 SIA-FI-338 SIB-FT-348 SI B-FI-348 Transmitter Indicator Transmitter Indicator Transmitter Indicator Transmitter Indicator ICE-3538 Mild ICE-3538 Mild Yes*
Mild Yes*
Mild A
A LPSI Flow - Train A 0 - 10,000 gpm LPSI Flow - Train B
0 - 10,000 gpm CS Flow - Train B
0 - 5,000 gpm CS Flow Train B
0 - 5,000 gpm
- The inspectors noted that these transmitters were environmentally qualified.
As the CS flow was not a variable chosen to be audited, the specification of the environmental qualification for these transmitters was not noted.
Ins ection Findin s
3.9 The insepctors noted that this Category 2 instrumentation is qualified for Class I seismic conditions.
The flow is displayed to the operator for each train on a dedicated indicator.
The instrumentation was found to meet the Category 2 recommendations specified in Regulatory Guide 1.97, Revision 2.
The RHR flow instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendations.
RHR Heat Exchan er Outlet Tem erature Regulatory Guide 1.97 recommends Category 2 instrumentation for this variable.
The regulatory guide states that this instrumentation is used to monitor the operation of the RHR system and for analysis of the reactor coolant system cooling capability.
One instrument loop is provided for each heat exchanger outlet.
Information on the temperature elements, transmitters and indicators follows:
Equipment Number Function EQ Listed Power Instrument Division
~Ran e
S IA-TE-303X SIA-TT-303X SIA-TI-303X SIB-TE-303Y SIB-TT-303Y SI B-TI-303Y Temp.
Element Transmitter Indicator Temp.
Element Transmitter Indicator ICE-3538 Mild Nild ICE-3538 Mild Mild A
F to 400 F
W W
F to 400 Ins ection Findin s
The inspectors found that this Category 2 instrumentation is qualified for Class I seismic conditions.
The flow is displayed to the operator
for each train on a dedicated indicator.
The instrumentation was found to meet the Category 2 recomendations specified in Regulatory Guide 1.97, Revision 2.
The RHR heat exchanger outlet temperature instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendations..
3.10 Accumulator Level Regulatory Guide 1.97 recommends Category 2 instrumentation with a range of 10 to 90 percent for this variable.
The regulatory guide states that this information is to be used to monitor the operation of the accumulators.
Discharge of the accumulators is automatic as the RCS pressure decreases due to a loss of coolant accident, below the normally maintained accumulator pressure.
One wide range channel is provided for each of the four accumulators.
The 0 to 100 percent range indicated covers 84% of the accumulator height.
Information on the level transmitters and indicators follows:
Equipment Number Function EQ Listed Power Instrument
~R S I8-LT-311 SIB-LI-311 Transmitter Indicator ICE-3535 Mild SIA-LT-331 SIA-LI-331 Transmi tter Indicator ICE-3535 Mild SIA-LT-341 Transmi tter ICE-3535 SI 8-LT-321 Transmitter ICE-3535 A
0 to 100K, dual indicator Indicated on SI B-LI-311 0 to 100K, dual indicator Indicated on SIA-LI-331 Ins ection Findin s The inspectors found that this Category 2 instrumentation is qualified for Clas's 1 seismic conditions.
The wide range level of each accumulator is displayed to the operator by way of indicators.
Each dual indicator displays the water Tevel of two accumulators, with divisional independence maintained.
The range, covering 84 percent of the accumulator height, exceeds the recommended range.
The instrumentation was found to meet the Category 2 recommendations specified in Regulatory Guide 1.97, Revision 2.
The accumulator wide range level instrumentation was found to be in calibration.
The inspectors found this instrumentation acceptable for meeting, the Regulatory Guide 1.97 recommendations.
3.11 Hi h Pressure Safet In 'ection Flow Regulatory Guide 1.97 recommends Category 2 instrumentation for this variable to monitor the operation of the high pressur e safety injection (HPSI) system.
There is one flow instrument loop per injection path.
Information on the flow transmitters and indicators follows:
Equipment Number Function EQListed Power Instrument SIB-FT-311 SI B-FI-311 Transmitter Indicator ICE-3538 Mild SIB-FI-311-1 Indicator Mi1 d SIB-FT-321 Transmitter ICC-3538 B
SIA-FT-331 S IA-FI-331 Transmitter Indicator ICE"3538 Mild SIA-FI-331-1 Indicator Mild SIA-FI-341 Transmitter ICE-3538 A
0 to 750 gpm, dual indicator 0 to 750 gpm, dual indicator Indicated on SIB-FI-311 and 311-1 0 to 750 gpm, dual indicator 0 to 750 gpm, dual indicator Indicated on SIB-FT-331 and 331-1 Ins ection Findin s
The inspectors noted that this Category 2 instrumentation is qualified for Class 1 seismic conditions.
The flow is displayed to the operator by way of indicators.
Each indicator displays 2 channels of the same division, with duplicate indicators on vertical boards 2 and 3.
The instrumentation was found to meet the Category 2 recommendations specified in Regulatory Guide 1.97, Revision 2.
The HPSI flow instrumentation was found to be in calibration.
The inspectors found this instrumentation acceptable for meeting the Regulatory Guide 1.97 recommendations.
3. 12 Pressurizer Level The licensee has designated this as a Type A variable.
Regulatory Guide 1.97 recommends Category 1 instrumentation with a range from the bottom to the top of the pressurizer.
The licensee's range covers 431.3 inches out of a total height ot 475.75 inches, or 90s6 percent of the pressurizer height.
The range of the pressurizer is further discussed in the findings section.
This instrumentation is to aid the operator in the proper operation of the pressurizer and the reactor coolant system.
Information on the pressurizer level transmitters, indicators, and recorder follows:
RCA-LT"110X RCA-LI-110X RCA"LR-110X RCB"LT-110Y RCB"LI-110Y Transmitter Indicator Recorder Transmitter Indicator Equipment Number Function EQListed ICE-3535 Mild Mild ICE-3535 Mi 1 d Seismic Listed Class
Class
Class
Class
Class
Power Division
'A Instrument
~Ren e
0 to 100X 0 to 100X 0 to lOOX
Ins ection Findin s
The pressurizer level is displayed on redundant indicators.
In addition, Channel A has a dedicated recorder.
The instrumentation was found to meet the Category I recommendations specified in Regulatory Guide 1.97, Revision 2.
The pressurizer level instrumentation was found to be in calibration.
Regulatory Guide 1.97 recommends instrumentation for this variable with a range covering from the bottom to the top of the vessel.
The Palo Yerde instrumentation does not indicate the volume in the hemispherical ends of the vessel.
Level indication is provided for the cylindrical portion of the pressurizer vessel.
Outside of the supplied instrument range, in the hemispherical vessel ends, the volume to level ratio is not linear (approximately 4.7 percent of the vessel height on each end is not monitored).
We find this deviation minor and acceptable.
The inspectors found the pressurizer level instrumentation'acceptable for meeting the Regulatory Guide 1.97 recommendations.
3. 13 Pressurizer Heater Status Regulatory Guide 1.97 recommends that the current used by the pressurizer heaters be monitored by Category 2 instrumentation.
The licensee has provided current monitoring for all eight pressurizer heater banks to the ERFDS.
All instrumentation is located in a mild envi ronment.
All heaters are powered by 480 VAC.
Buses E-PGA-L32 and E-PGA-L33 are Class lE and are backed by diesel generator power.
The information on this instrumentation follows:
Power Source 480 VAC Bus Power Capacity ERFDS Indicator KII I di i
~R
~TN b
E-PGB-L32 E-PGA-L33 E-NGN-L12 E-NGN-L12 E-NGN-L12 E-NGN-Lll E-NGN-Lll E-NGN-Ll1 On/Off 150 On/Off 150 On/Off 300 On/Off 300 Proportional 183 On/Off 300 On/Off 300 Proportional 183 Yes Yes Yes Yes Yes Yes Yes Yes 0 - 300A 0 - 300A RCB-HS-100-5 RCA-HS-100-4 Ins ection Findin s The current drawn by each heater bank is available to the operator as indicated above.
Regulatory Guide 1.97 allows Category 2 instrumentation to have a digital display on demand where essential transient information is not needed for operator use.
The instrumentation was generally found to meet the Category 2 recommendations specified in Regulatory Guide 1.97, Revision 2.
The inspectors noted, however, that tag numbers were not displayed adjacent to the dedicated indicators.
The control room operators should have rapid means of identifying the variables.
The licensee's action to provide the proper labeling for these indicators will be followed up in a future inspection report (50-528/88-12-02).
e Another potential problem was that the licensee was not able to verify the current calibration of this instrumentation.
It appears that this instrumentation is maintained by electrical maintenance personnel rather than instrumentation personnel.
The calibration of this variable is further discussed in Paragraph 4.
3. 14 Steam Generator Level - wide Ran e
The licensee has designated this a Type A variable.
Regulatory Guide 1.97 recommends Category 1 instrumentation for this variable with a range from the tube sheet to the separators.
This instrumentation helps verify the operation of the feedwater and auxiliary feedwater systems in maintaining the steam generator as a heat sink for the reactor coolant system.
Information on the wide r ange steam generator level instrumentation follows:
Equipment Number Function EQListed Seismic Listed
.
Power Div.
Steam Gen.
Instrument
~Ren e
Class
A Class
A SGA-LI-1113A Indicator SGA-LI-1113A-2 Indicator SGB-LT-1113B Transmitter Mi 1 d Mild Class
Class
ICE-3535 Class
B SGA-LT-1113A Transmitter ICE-3535 SGA-LR-1113A Recorder Mi 1 d
1/2 1/2 1/2 0 to lOOX, dual recorder 0 to lOOX, dual indicator 0 to 100X, dual indicator SGB-LI-1113B Indicator Mild SGB-LI-1113B"2 Indicator Mild SGC-LT-1113C SGC"LI-1113C Transmitter ICE-3535 Indicator Mild SGD-LT-1113D SGD-LI-1113D Transmitter ICE-3535 Indicator Mild Class
Class
Cl ass
Class
Class
Class
SGA-LT-1123A Transmitter ICE-3535 Class
A SGB-LT-1123B Transmitter ICE-3535 Class
B SGC-LT-1123C Transmitter ICE-3535 Class
C SGD-LT-1123D Transmitter ICE-3535 Class
D
'1/2 1/2
1/2
1/2 0 to lOOX, dual indicator 0 to 100K, dual indicator 0 to 100K, dual indicator 0 to 100K, dual indicator recorded on SGA-LR-1113A, indicated on SGA"LI-1113A and 1113A-2 indicated on SGB-LI-1113B and 1113B-2 indicated on SGC"LI-1113C indicated on SGD-LI"1113D
Ins ection Findin s The wide range steam generator level is available to the operator on a dual scale recorder (one scale for each steam generator)
and on seven dual scale indicators.
Both steam generators are displayed on the recorder and on each indicator.
The steam generator level instrumentation was found to meet the Category 1 recommendations specified in Regulatory Guide 1.97, Revision 2.
The instrumentation was found to be in calibration.
A problem was identified with the Steam Generator level range.
The upper tap, corresponding to lOOX level, is located at 662.5 inches, some '55.5 inches above the bottom of the separators.
This exceeds the range specified in RG 1.97, and therefore meets the range for the upper tap.
The lower tap is located 143 inches above the tube sheet.
This does not meet the recommendations of the regulatory guide.
There remains approximately 143 inches of water in the steam generator when the level indicated is OX.
This was not previously identified to the NRC for the range of the Steam Generator Wide Range Level, which gives an indication of the ultimate heat sink from the reactor.
The location of the taps should be justified and documented.
This is a deviation from the Regulatory Guide (50-528/88-12-03).
3. 15 Steam Generator Pressure The licensee has des)gnated this as a Type A variable.
With this designation, Regulatory Guide 1.97 recommends Category 1 instrumentation.
This instrumentation is used to monitor the operation of the steam supply system.
Information on the steam generator pressure instrumentation follows:
Equipment Number Function EQ Listed Sei smic Power Listed Div.
Steam Gen.
Instrument
~Ran e
SGA-PT-1013A SGA-PI"1013A Transmitter ICE-3535 Class
A Indicator Mild Class
SGB-PT-1013B Transmitter ICE-3535 SGB"PI-1013B Indicator Mild Class
B Class
SGC-PT-1013C Transmitter ICE-3535 SGC-PI-1013C Indicator Mi 1 d Class
C Class
SGD-PT-1013D Transmitter ICE-3535 SGD-PI-1013D Indicator Mild Class
D Class
SGA-PT-1023A Transmitter ICE-3535 Class
A SGA-PI-1023A Indicator Mild Class
SGA-PR-1013A Recorder Mi1d Class
A 1/2 0 " 1524 psia 0 - 1524 psia, dual recorder 0 - 1524 psia 0 " 1524 psia 0 - 1524 psia recorded on SGA"PR-1013A 0 - 1524 psia
Equipment Number Function Eg Listed Seismic Listed Power DiV.
Steam Gen.
Instrument
~Rao e
SGB-PT-10238 SGB-PI-10238 SGC-PT-1023C SGC-PI-1023C SGD-PT-1023D SGD-PI-1023D Transmitter ICE-3535 Cl ass
Indicator Mild
.
Class
Transmitter ICE-3535 Class
Indicator Mild Class
Transmitter ICE-3535 Class
Indicator Mild Class
2
0 - 1524 psia 0 - 1524 psia 0 - 1524 psia Ins ection Findin s
The steam generator pressure of each steam generator is available to the operator on a single dual pen recorder.
All four pressure channels for both steam generators are also available on individual indicators.
The instrumentation for this variable was found to meet the Category
recommendations specified in Regulatory Guide 1.97, Revision 2.
All of the above instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable for meeting the RG 1.97
~
~
recommendatsons.
3. 16 Containment Atmos here Tem erature Regulatory Guide 1.97 recommends Category 2 instrumentation for this variable to indicate the accomplishment of containment cooling.
Information on the containment atmosphere temperature instrumentation follows:
Equipment Number HCN-TE-42A1 HCN-TE-4281 HCN-TE-42C1 HCN-TE-42D1 HCN-TE-42El Function Element Element Element Element Element EgListed 13-NN-598 13-MM-598 13-MM-598 13-MM-598 13-MM-598 Power Non-IE Non-1E Non-lE Non-1E Non-1E
~Dis la ERF, 40 F - 400 F
F 400oF ERF 40oF 400oF ERF, 40 F - 400 F
Ins ection Findin s Each temperature element is located in a separate area of containment, and is input directly to the Emergency Response Facility (ERF) computer.
Regulatory Guide 1.97 allows a call up display on demand with no dedicated display for Category 2 variables.
All Category
recommendations specified in Regulatory Guide 1.97, Revision 2, are met.
The containment atmosphere temperature instrumentation was found to be in calibration.
The inspectors found the instrumentation acceptable in meeting the requirements of Regulatory Guide 1.9. 17 Status of Standb Power As part of this inspection, the team requested documentation regarding the variable 'Status of Standby Power.'hile in the control rooms the inspector noted that indication is available on voltages, currents, power, and frequency for many of the buses and power sources.
The licensee had not determined which instruments fall under the classification of this variable.
A list of the control room electric power instrumentation was provided.
The licensee was unable to provide evidence of current calibration or of scheduled recall for calibration.
The calibration of this variable is further discusse'd in paragraph 4.
The conformance of this variable to the Regulatory Guide has not been assessed.
The inspectors consider the inspection of this variable unresolved which will be fol'lowed up in a future inspection report (50-528/88-12-04).
The licensee has agreed to provide the requested information.
Surveillance, Testin and Calibration 5.
A computer maintains the surveillance records for Regulatory Guide 1.97 instrumentation, except for the variables
'status of standby power'nd
'pressurizer heater status'.
The dates of any surveillance, maintenance, testing, calibration, or other work performed on a instrument loop is available.
It also identifies the recalibration intervals and the date the next surveillance is necessary.
All of the RG-1.97 instrumentation inspected was found to be in calibration at the time of the inspection, except for the variables
'status of standby power'nd
'pressurizer heater status'.
The licensee has yet to provide information on these variables, which are maintained by a separate licensee organization.
This is an unresolved item (50-528/88-12-05).
Exit Interview The inspectors met with the licensee representatives identified in paragraph 1 on April 8, 1988.
The scope of the inspection and the findings up to that date were discussed.
The inspecteors identified that he had requested some additional information from the licensee.
The inspector's findings are documented in this repor