ML17299B110
| ML17299B110 | |
| Person / Time | |
|---|---|
| Site: | Palo Verde  |
| Issue date: | 03/13/1986 |
| From: | ARIZONA PUBLIC SERVICE CO. (FORMERLY ARIZONA NUCLEAR |
| To: | |
| Shared Package | |
| ML17299B109 | List: |
| References | |
| TAC-60706, NUDOCS 8603250169 | |
| Download: ML17299B110 (38) | |
Text
ELECTRICAL POWER SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)
ACTION (Continued) c.
With one offsite circuit and one diesel generator inoperable, demon-strate the OPERABILITY of the remaining A.C. sources by performing Surveillance Requirement
- 4. 8. 1. l. 1. a within one hour and at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter; and if the EDG became inoperable due to any cause other than preplanned preventative maintenance or
- testing, demonstrate the OPERABILITY of the remaining OPERABLE EDG by performing Surveillance Requirement 4.8. l. 1. 2. a. f within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />";
restore one of the inoperable sources to OPERABLE s'ta us w>
1n 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
Restore the other A.C.
power source (offsite circuit or diesel generator) to OPERABLE status in accordance with the provisions of Section 3.8. 1. 1 Action State-ment "a" or "b", as appropriate with the time requirement of that Action Statement based on the time of initial loss of the remaining inoperable A.C. power source.
A successful test of diesel OPERABILITY per Surveillance Requirement
- 4. 8. 1. l. 2. a. 4 performed under this Action Statement for an OPERABLE diesel or a restored to OPERABLE diesel satisfies the EDG test requirement o'f Action Statement "a"
or llbll I
NR'glAA mug 80
~ID ISO 0%
rtg bQ NC O0" NQ RQ.IL d.
With two of the required offsite A.C. circuits inoperable, demon-strate the OPERABILITY of two diesel generators by sequentially performing Surveillance Requirement
- 4. 8. 1. 1. 2. a. 4 on both diesels within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, unless the diesel generators.
are already operating; restore one of the inoperable offsite sources to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least HOT STANDBY within the next 6
hours.
Following restoration of one offsite source, follow Action Statement "a" with the time requirement of that Action Statement based on the time of initial loss of the remaining inoperable offsite A.C.
circuit.
A successful test(s) of diesel OPERABILITY per Surveillance Requirement 4.8. 1. 1.2.a.4 performed under this Action Statement for the OPERABLE diesels satisfies the EDG test requirement of Action Statement "a".
With two of the above required diesel generators inoperable, demon-strate the OPERABILITY of two offsite A.C. circuits by performing Surveillance Requirement
- 4. 8. 1. l.l. a within one hour and at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter; restore one of the inoperable diesel generators to OPERABLE status within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
Following restoration of one diesel generator unit, follow Action Statement "b" with the time requirement of that Action Statement based on the time of initial loss of the remaining inoperable diesel generator.
A successful test of diesel OPERABILITY per Surveillance Requirement 4.8. 1. 1.2.a.4 performed under this Action Statement for a restored to OPERABLE diesel satisfies the EDG test requirement of Action Statement "b".
"This test is required to be completed regardless of when the inoperable EDG is restored to OPERABILITY.
PALO VERDE - UNIT 2 3/4 8-2
NO SIGNIFICANT HAZARDS DOCUMENTATION Unit 2 Technical S ecification 6.4 The proposed amendment request does not involve a
Significant, Hazards Consideration because:
(A)
The operation of PVNGS Unit 2 in accordance with this change would not:
1)
Involve a
significant increase in the probability or consequences of an accident previously evaluated; or 2)
Create the possibility of a new or different kind of accident from any accident previously analyzed; or 3)
Involve a significant reduction in a margin of safety; and (B)
This change reflects the changes in the organization described in Specification,6.2.1.
The Training Manager will report to the Assistant Vice President, Nuclear Production, instead of the PVNGS Plant Manager.
This change was discussed with Mr. Manny Licitra in your offices on February 21, 1986 and found to be acceptable.
l V
1 E
U h
F
ADMINISTRATIVE CONTROLS 6 4 TRAINING ass i.
v P. 4<<<<4<
P<oo dcVad 6.4.1 A trainin program for the unit staff shall be maintained under the direction of th or his designee and shall meet or exceed the requirements and recommendations of Section 5.0 of ANS 3. 1-1978 and Appendix A of 10 CFR Part 55 and the supplemental requirements specified in Sections A and C of Enclosure 1 of the March 28, 1980 NRC letter to all licensees, and shall include familiarization with relevant industry operational experience.
6: 5 REVIEW AND AUDIT 6.5.1 PLANT REVIEW BOARD (PRB FUNCTION 6.5. 1. 1 The Plant Review Board shall function to advise the PVNGS Plant Manager on all matters related to nuclear safety.
COMPOSITION
- 6. 5. l. 2 The Member:
I 1ember:
Member:
Member:
Member:
Member:
Member:
Member:
Member:
Member:
PRB shall be composed of the following personnel:
'I Technical Support Manager Operations Manager Maintenance Manager Plant Services Manager Engineering Manager Operations Superintendents for Unit 1, Unit 2, Unit 3 STA Supervisor IKC Superintendent Radiation Protection and Chemistry Manager equality Systems/Engineering Manager The PVNGS Plant Manager shall designate the Chairman and Vice-Chairmen in writing.
The Chairman and Vice-Chairmen may be from outside the members listed above provided that they meet ANSI Standard
- 3. 1, 1978.
ALTERNATES
- 6. 5. 1. 3 All alternate members shall be appointed in writing by the PRB Chairman to serve on a temporary basis;
- however, no more than two alternates shall participate as voting member's in PRB activities at any one ti'me.
~EETIN I
E I I
6.5. 1.4 The PRB shall meet at least once per calendar month and as convened by the PRB Chairman, Vice-Chairmen, or his designated alternate.
PALO VERDE - UNIT 2 6-7
E
NO SIGNIFICANT HAZARDS DOCUMENTATION Unit 2 Technical S ecification 3/4.3.3.9 Tables 3.3-13 and 4.3-8 The proposed amendment request does not involve a
Significant Hazards Consideration because:
(A)
The operation of PVNGS Unit 2 in accordance with this change would not:
1)
Involve a
significant increase in the probability or consequences of an accident previously evaluated; or 2)
Create the possibility of a new or different kind of accident from any accident previously analyzed; or 3)
Involve a significant reduction in a margin of safety; and (B)
The proposed change does not result from a change in plant design, but it reflects that, at certain times during plant operation in MODES 3 and 4, condenser vacuum may not be established or sealing steam applied to turbine glands from the steam generators.
If neither of these conditions exists, there is no possibility of a release from this pathway.
The monitors would not need to be operable at this time.
This change was discussed with Mr. Jared Wermiel in your offices on February 20, 1986 and found to be acceptable.
V
TABLE 3.3-13 (Continued)
RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION
~ p INSTRUMENT 3.
CONDENSER EVACUATION SYSTEM MINIMUM CHANNELS-OPERABLE APPLICABILITY ACTION B.
Low Range Monitors a.
Noble Gas Activity Monitor 0RU-141 b.
Iodine Sampler c.
Particulate Sampler Flow Rate Monitor e.
Sampler Flow Rate Measuring Device High Range Monitors 1
1 4k 1, 2, 3, 4
1 2
3 1
2, 3
1 2
3 1
2 3
37 40 40 36 36 a.
Noble Gas Activity Monitor 8RU-l42 b.
Iodine Sampler c.
Particulate Sampler d.
Sampler Flow Rate Measuring Device 4.
PLANT VENT SYSTEM A.
Low Range Monitors a.
Noble Gas Activity Monitor 8RU-143 b.
- Iodine Sampler
" 'c.
Particulate Sampler d.
Flow Rate Monitor e.
Sampler Flow Rate Measuring Device
)'
1 2
3 1
2 3
1 2
3 1, 2, 3
42 42 42 42 37 40'0 36 36
TABLE 3. 3-13 (Continued)
TABLE NOTATION At al 1 times.
- During GASEOUS RADWASTE SYSTEM operation.
During waste gas release.
¹¹ In MODES 1, 2, 3, and 4 or when irradiated fuel is in the fuel storage pool.
ACTION 35
With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, the contents of the tank(s) may be released to the environment provided that prior to initiating the release:
a.
At least two independent samples of the tank's contents are analyzed, and b.
At least two technically qualified members of the facility staff independently verify the release rate calculations and discharge valve lineup; Otherwise, suspend release of radioactive effluents via this pathway.
ACTION 36 -
With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via this pathway may continue provided the flow rate is estimated at least once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
ACTION 37 -
With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via this pathway may continue provided the actions of (a) or (b) are performed:
a.
Initiate the Preplanned Alternate Sampling Program of Specification
- 6. 16 t'o monitor the appropriate parameter(s).
b.
Place moveable air monitors in-line or take grab samples at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
ACTION 38 -
With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, immediately suspend PURGING of radioactive effluents via this pathway.
ACTION 39-With the number of channnels OPERABLE one less than required by the Minimum Channels OPERABL'E requirement, operation of the GASEOUS RADWASTE SYSTEM may continue provided grab samples are taken and analyzed daily.
With both channels inoperable operation may continue provided grab samples are taken and analyzed (1) every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> during degassing operations, and (2) daily during other operations.
glHFWEVC,Q 7HC C.oADCHtdg big.
AA AovHC-5 YStgq g s
/A OP/ ch Trow Q HSAICvCQ J
7 v RQ 6
G OLIOS ll8 ~
OEIAC
>> I ~~ +0 W /TH S 7+4<
I ICOP1 Sd<rRO<g
, 07444.
Th'y4 1'8r.
A afXI a. ia AY Qo i'd a(Sg, PALO VERDE - UNIT 2 3/4 3-75.
0 l
Jt I IA 1'
TABLE 4.3-8 (Continued)
RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE RE UIREMENTS INSTRUMENT 3.
CONDENSER EVACUATION SYSTEM (RU-141 and RU-142) a.
Noble Gas Activity Monitor D(6)
R(3)
CHANNEL SOURCE CHANNEL CHECK CHECK CALIBRATION CHANNEL MODES IN WHICH FUNCTIONAL SURVEILLANCE TEST IS EEIT IIIEE C(2)
- b. Iodine Sampler
- c. Particulate Sampler d.
Flow Rate Monitor e.
Sampler Flow Rate Measur ing Device N. A.
N.A.
D(7)
D(7)
N.A.
N. A.
N.A.
N. A.
N.A.
1 2
3 1
2 3,
1, 2, 3, 1, 2, 3, 4.
PLANT VENT SYSTEM (RU-143 and RU-144) a.
Noble Gas Activity Monitor
- b. Iodine Sampler
- c. Particulate Sampler d.
Flow Rate Monitor e.
Sampler Flow Rate Measuring Device D(6)
N. A.
N.A.
D(7)
D(7)
M R(3)
N. A.
N.A.
N.A.
N.A.
N.A.
R u(2)
TABLE 4.3-8 (Continued)
TABLE NOTATIONS
¹
¹¹
¹¹¹
'-(j )
(2)
(3)
At al 1 times.
During GASEOUS RADWASTE SYSTEM operation.
During waste gas release.
During MODES 1, 2, 3 or 4 or with irradiated fuel in the fuel storage pool.
Functional test should consist of, but not be limited to, a verification of system isolation capability by the insertion of a'imulated alarm condition.
The CHANNEL FUNCTIONAL TEST shall also demonstrate that automatic isolation of this pathway occurs if the instrument indicates measured levels above the alarm/trip setpoint.
The CHANNEL FUNCTIONAL TEST shall also demonstrate that control room alarm annunciation occurs if any of the following conditions exists:
1.
Instrument indicates measured levels above the alarm setpoint.
2.
Circuit failure.
3.
Instrument indicates a downscale failure.
4.
Instrument controls not set in operate mode.
The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards (NBS) or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS.
These -standards shall permit calibrating the system over its intended range of energy and measurement range.
For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.
(4)
(6)
The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:
1.
One volume percent
- hydrogen, balance
- nitrogen, and 2.
Four. volume percent
The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:
1.
One volume percent
- oxygen, balance
- nitrogen, and 2.
Four volume percent
The channel check for channels in standby 'status shall consist of verification that the channel is "on-line and reachable."
(7)
Daily channel check not required for. flow monitors in standby status.
T<"-
<uA~ '-~sr g 0 iC ~r ~~q~
~~sr'<
i s i~
MHCd r'BA.
T'0 g Q /Al' C.AADp
+4 r; 3 r: /Ac s 0 PPctwo m st/
5c uce<qpgQg PALO VERDE - UNIT 2 3/4 3-80
NO SIGNIFICANT HAZARDS DOCUMENTATION Unit 2 Technical S ecification 3/4.4.3.2 The proposed amendment request does not involve a
Significant Hazards Consideration because:
(A)
The operation of PVNGS Unit 2 in accordance with this change would not:
1)
Involve a
significant increase in the probability or consequences of an accident previously evaluated; or 2)
Create the possibility of a new or different kind of accident from any accident previously analyzed; or 3)
Involve a significant reduction in a margin of safety; and (B)
This change reflects requirements stated in NUREG-0857, Supplement No. 9, issued with Facility Operating License NPF-46.
Locking the valves in the open position helps to ensure the operability of the auxiliary spray system when it may be needed.
This change was reviewed by Mr.
Chu-Yu Liang in your offices on February 20, 1986 and found to be acceptable.
~
4 I'I
REACTOR COOLANT SYSTEM AUXILIARYSPRAY LIMITING CONDITION FOR OPERATION 3.4.3.2 Both auxiliary spray valves shall be OPERABLE.
+-
APPLICA6TLITY:
MODES 1, 2, 3, and 4.
ACTION:
a
~
With only one of the above required auxiliary spray valves
- OPERABLE, restore both valves to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
With none of the above required auxiliary spray valves
- OPERABLE, restore at least one valve to OPERABLE status within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
SURVEILLANCE RE UIREMENTS 4.4.3.2.1 The auxiliary spray valves shall be verified to have power available to each valve every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
4.4.3.2.$ 3The auxiliary spray valves shall be cycled at least once per 18 months.
g.Q. 3.g. Q Lg - Hv ggf
~we, od-Hv-5'3p sn'4c~
dr= via>r i~a
<oceano OPCA +r ~r=~sr oa~~
r r=Z al DAYS PALO VERDE - UNIT 2 3/4 4"'LO
NO SIGNIFICANT HAZARDS DOCUMENTATION Unit 2 Technical S ecification 3/4.5.1 The proposed amendment request does not involve a
Significant Hazards Consideration because:
(A)
The operation of PVNGS Unit 2 in accordance with this change would not:
1)
Involve a
significant increase in the probability or consequences of an accident previously evaluated; or 2)
Create the possibility of a new or different kind of accident from any accident previously analyzed; or 3)
Involve a significant reduction in a margin of safety; and (B)
This change will make the surveillance requirement more conservative than the present specification.
This will make the referenced pressure agree with the pressure stated in the footnote on Page 3/4 5-1 and will eliminate confusion between the two items.
The change was reviewed by Mr.
Chu-Yu Liang in your offices on February 21, 1986 and found to be acceptable.
EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE RE UIREMENTS (Continued) b.
C.,
2.
Verifying that each safety injection tank isolation-valv'e is open and the nitrogen vent valves are closed.
At least once per 31 days and within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after each solution level increase of greater than or equal to 7%%u'f tank narrow range level by verifying the boron concentration of the safety injection tank solution is between 2000 and 4400 ppm.
P g6ssuni z c R, 93o &sic At least once per 31 days when the~ pressure is above Whig, by verifying that power to the isolation valve operator is removed.
At least once per 18 months by verifying that each safety injection tank isolation valve opens automatically under each of the following conditions:
1.
Mhen an actual or simulated RCS pressure signal exceeds 515 psia, and 2.
Upon receipt of a safety injection actuation (SIAS) test signal.
e.
g.
At least once per 18 months by verifying OPERABILITY of RCS-SIT differential pressure alarm by simulating RCS pressure
> 715 psia with SIT pressure
( 600 psig.
At least once per 18 months, when SITs are,'isolated, by verifying the SIT nitrogen vent valves can be opened.
At least once per 31 days, by verifying that power is removed from the nitrogen vent valves.
Q PALO VERDE " UNIT 2 3/4 5-2
NO SIGNIFICANT HAZARDS DOCUMENTATION Unit 2 Technical S ecification 6.8.4f The proposed amendment request does not involve a
Significant Hazards Consideration because:
(A)
The operation of PVNGS Unit 2 in accordance with this change would not:
1)
Involve a
significant increase in the probability or consequences of an accident previously evaluated; or 2)
Create the possibility of a new or different kind of accident from any accident previously analyzed; or 3)
Involve a significant reduction in a margin of safety; and (B)
Deletion of the procedure number would allow the flexibility to change the procedure number without changing the Technical Specifications.
It is also common practice not to include plant procedure numbers in the Technical Specifications.
This change was discussed with Mr. Jared Wermiel in your offices on February 21, 1986 and found to be acceptable.
E' F
F J
ADMINISTRATIVE CONTROLS PROCEDURES AND PROGRAMS (Continued)
(1)
Training of personnel, and (2)
Procedures for monitoring.
e.
Post-Accident Sam lin A program which will ensure the capability to obtain and analyze reactor coolant, radioactive iodines and particulates in plant gaseous effluents, and containment atmosphere samples under accident conditions.
The program shall include the following:
(1)
Training of personnel, (2)
Procedures for sampl i ng and analysis, (3)
Provisions for maintenance of sampling and analysis equipment.
f.
S ra Pond Monitorin A program which will identify and describe the parameters and activities used to control and monitor the Essential Spray Pond and Piping.
The program shall be conducted in accordance with 6.9 REPORTING RE UIREMENT ROUTINE REPORTS 6.9. 1 In addition to the applicable reporting requirements of Title 10, Code of Federal Regulations, the following reports shall be submitted to the Regional Administrator of the Regional Office of the NRC unless otherwise noted.
STARTUP REPORT 6.9. 1. 1 A summary report of plant startup and power escalation testing shall be submitted following (1) receipt of an operating license, (2) amendment to the license involving a planned increase in power level, (3) installation of fuel that has a different design or has been manufactured by a different fuel
- supplier, and (4) modifications that may have significantly altered the nuclear, thermal, or hydraulic performance of the plant.
6.9. 1.2 The Startup Report shall address each of the tests identified in the FSAR and shall include a description of the measured values of the operating conditions or characteristics obtained during the test program and a comparison of these values with design predictions and specifications.
Any corrective actions that were required to obtain satisfactory operation shall also be described.
Any additional specific details required in license conditions based on other commitments shall be included in this report.
- PALO VERDE - UNIT 2 6-16
A 4
The staff requested that additional information be supplied concerning the change to Technical Specification 6.2.1.
The major change is depicted on Figure 6.2-1.
The Assistant Vice President, Nuclear Production, is shown separated from the Vice President, Nuclear Production, and is assigned direct responsibility for four support functions:
Emergency
- Planning, Administrative Services,
- Training, and Water Reclamation Facility Operations.
%his change was made to allow those managers who have direct responsibilities for plant operation and safety to concentrate resources on those areas and to provide effective management for necessary support functions.
An additional change can be seen on Figure 6.2-1.
The Compliance Department reporting to the PVNGS Plant Hanager will now be headed by a manager with one or more supervisors reporting to him.
This change is intended to increase the effectiveness of this group in responding to Licensee Event Reports and other interfaces with regulatory matters.
"af" bl a
e A'
CEO EXECUTIVE V.P.
V.P.
NUCLEAR PRODUCTION ASST.
V.P. NUCLEAR PRODUCTION PVNGS PLANT MANAGER MGR.
NUCLEAR SAFETY ISEG/NSG
'DIR.
TECHHICAL SERVICES DIR.
CORPORATE QA MGR.
EMERGENCY PLAN MGR.
OPERATIONS MGR.
TRANSITION MGR.
NUCLEAR EHGIHEERIHG
'SST.
MGR.
CORPORATE QA MGR.
+
ADMINISTRATIVE SERVICES MGR.
MAINTENANCE MGR.
NUCLEAR CONSTRUCTION MGR.
QUALITYSYSTEMS/
ENGINEERING MGR.
TRAINING MGR.
OUTAGE MANAGEMEHT MGR.
NUCLEAR FUELS'.
MGR.
'ROCUREMENT QUALITY WRF SUPERINTENDENT MGR.
PLANT SERVICES MGR. RECORDS MGR.
QUALITY AUDITS/
MONITORING MGR.
TECHNICAL SUPPORT MGR. LICEHSIHG MGR.
QUALITY CONTROL
+ LOCATED OHSITE MANAGER COMPLIANCE FIGURE 6.2-1 OFFSITE ORGANIZATION
PVHGS PLAHT MAHAGER OUTAGE.
MANAGEMENT.
MANAGER TECHNICAL SUPPORT MANAGER OPERATIONS MANAGER MAINTEHAHCE MAHAGER PLANT SERVICES MANAGER MANAGER COMPLIAHCE MANAGER OPS ENGINEERING SUPERIHTEHOEHT UNIT I SUPERIHTEHDENT ICC MAINTENANCE MANAGER OPERATIONS SECURITY SUPERVISOR STA SUPERINTEHOEHT UNIT 2 SUPERINTEHDENT MCC SUPERVISOR FIRE PROTECTIOH MANAGER RAD. PROT. 4 CHEM.
SUPERINTEHDENT UNIT 3 SUPERINTENDENT ELEC. MAINTENANCE SUPERINTEHDEHT OPS COMPUTER SYSTEM SUPERVISOR OPERATIONS SUPPORT SUPERINTEHOEHT STATION SERVICES SUPERIHTEHOEHT MECHANICAL MAIHTEHANCE FIGURE 6.2-2 OHSITE UHIT ORGAHIZATIOH
Rl m
t
~ ChI OIR.
DIR. PROJECT SERVICES I
EMPLOYEE RELATIONS I
I G/4 PROJECT COHTROL
)
NGL AONIH. SERVICES NGR COHTRACTS 4 PURCHASOIO NGR. AHPP COMMUNICATIONS PVHOS PLANT MANAGER MGR OPERATIONS Vi'.
NUCLEAR PROOUCTION ASST, V.Pr NUCLEAR PROOUCTION MGR.
TRAttSITIOH NGR.
HUCLEAR SAFETY ISEO/HSO I
I I
OIR.
J TECHNICAL SERVICES OIR.
PROCURENEHT QUAL I
ASST. MGR.
CORPORATE QA I
I I
NGR.
QUALITY SYSTElt EHGIHEERIHG NGL PARTICIPANT SERVICES ltGR. MAINTENAHCE MGR. OUTAGE NAHAGENENT MGR. PLANT SERVICES ltGR.
TECHNICAL SUPPORT I
I I
I I
I I
(
I I
I I
NGR.
NUCLEAR COHSTRUCTIOH MGL ENERGEKCY PLAHNlttO NGR. HUCLEAR FUELS MGR. RECOROS MGL QUALITYAUOITS NOHITORIHO ONSITE MGR.
QUALITYCONTR ONITE FIGURE 6.2"1 OFFSITE ORGANIZATION NGL LICEHSIHG
PVHOS PLANT MANAGER OUTAGE MAHAGEMEHT MAHAGER TECHHICAL SUPPORT MAHAGFR OPERATIONS MANAGER MAINTEHAHCE MAHAGER PLANT SERVICES MANAGER MAHAGER OPS EHGINEERING HRF SUPERINTEHOENT SUPERVISOR, HRF MAINTEHANCE MANAGER TRAI SUPERVISOR STA SUP ERIHTEHOEHT UHIT 1 SUPERINTEHOEHT IXC MAINTEHAHCE MAHAGER OPERATIONS~
SECURITY %h/
MAHAGER RAD> PROT. 4 CHEM>
SUPERINTEHOENT UNIT 2 SUPERINTEHOENT MCC SUPERVISORC3 FIRE PROTECTION SUPERVISOR COMPLIANCE SUPERIHTEHOEHT UNIT 3 SUPERINTENDENT ELEC. MAINTEHANCE SUPERINTEHOEHT OPS COMPUTER SYSTEM SUPERVISOR OPFRATIONS SUPPORT SUPERIHTEHOEHT STATIOH SERVICES FIGURE 6.2-2 ONSITE UNIT ORGANIZATION SUPERIHTEHOEHT MECHANICAL MAINTEHAHCE
NO SIGNIFICANT HAZARDS DOCUMENTATION Unit 2 Technical S ecification Table 3.3-11 The proposed amendment request does not involve a Significant Hazards Consideration because:
(A)
The operation of PVNGS Unit 2 in accordance with this change would not:
- 1) Involve a significant increase in the probability or consequences of an accident previously evaluated; or
- 2) Create the possibility of a new or different kind of accident from any accident previously analyzed; or
- 3) Involve a significant reduction in a margin of safety.
(B)
The proposed amendment is purely an administrative change to the technical specifications:
the fire detection instruments listed have been added to Unit 2 ~
C I,
CINITRGILILED'BV 'P~ER TABLE 3. 3-11 (Continued)
FIRE DETECTION INSTRUMENTS FIRE ELEYATIQN INSTRUMENT LOCATION ZONE HEAT
'LAME
~xy)
~x]~y SMOKE 7x Jyy'OTAL NUMBER OF INSTRUMENTS*
9B lQA 10B h
llA 11B lg
~ l3 14 1OO'00'00'OO'20'2O!
LZ,O l
20'2O'attery Rm. - Train A (Channel A)
Battery Rm. - Train B (Channel B)
Remote Shutdown Rm. "
Train A Remote Shutdown Rm. "
Train B.
Cable Shaft - Train A Cable Shaft - Train B
(<~wove,ao %woeS A,~
T.~warr km~
Lower Cable Spreading Rm.
System 1
System 2
System 3
System 4
System 5
System 6
0/2 0/2 0/1 0/1 0/1 O/1 0/1 0/1 0/1 O/1 0/2 0/2 1/0 1/0 s/~
o/6 0/6 0/8 O/8 0/8 0/8 15A 140'LAG
&~4 17 140'8A 160 Cable Shaft - Train A Cable Shaft - Train A C ~~~O)Pc,a. ~4@4~ R~
~hh~h h~
Control Rm. - MCB's & Relay 2/0 Cabinets
\\ L'Q M&0 llo 18B 160 l
>9 ic o 20 '60'able Shaft - Train B
~~.~~4 s~~Q~ ~k Upper Cable Spreading Rm.
System 1
System 2
System 3
System 4 System 5
0/1 O/1 0/1 O/1 O/1 1/o
>Io O/12 o/8 0/8 o/8 0/8
l lll
TABLE 3. 3-11 (Continued)
FIRE DETECTION INSTRUMENTS FIRE ELEYATION ZONE INSTRUMENT LOCATION TOTAL NUMBER OF INSTRUMENTS" HEAT FLAME SMOKE
~xy)
~xfyy Yx>~y 21B 22A 22B 24A
'4B 2gA 100'00'00'00'15'15'31'UILDING
- DIESEL GENERATOR Diesel Generator - Train A Diesel Generator - Train B
Diesel Generator Control Rm.-
Train A.
Diesel Generator Control Rm.-
Train B
Combustion Air Intake Rm.-
Train A Combustion Air Intake Rm.-
Train B
Fuel Oil Day Tank-Train A 0/3 0/3 0/1 0/4 0/4 1/0 1/0 1/0 1/0 23B
-.. 131'uel Oil Day Tank-Train B
0/1 25A 25B 2-7 28 131'31'OO100'xhaust Silencer Rm.-
Train A Exhaust Silencer Rm.-
Train B
BUILDING - FUEL QQ gg gy er VL6ffb(KOQVPhL45 Spent Fue&ooi Rolling and Cleanup Pump Areas KhctA Wrac te 4 ~+v~p~g~g eccl.~
h4.~ a~4 Sp~4 Funk Geerqa ~~
BUILDING - AUXILIARY 3/0 3/0 0/o 3/0 88A 51'-6" j~
West Corridors 6/0 SSB 51 -6" <
~a'h S<-v j4j 32A 51,'-6," <<o',
3W kl'-6"
'eo'h.
5A-4 si-v" (
sc,'ALO YERDE " UNIT East Corridors Eguip~4 arnis i~+
LPSJ Pump Rm. - Train A
<o waim~4 spc"g%~q goow-'Yc o.iwb
~oCuw~4 Sp~ ~wq QOo~
Sl Pump Rm. - Train B
+Pc'nQ W~p 4inng. - ~re.ciah CQMTRQIL3.Eb BY USIER 6/0
)o Z
Og o/z 9'z
I k 4, ha I
~ H TABLE 3.3-11 (Continued)
FIRE DETECTION INSTRUMENTS FIRE ELEVATION INSTRUMENT LOCATION ZONE TOTAL NUMBER OF INSTRUMENTS" HEAT
'LAME SMOKE
~xy)
~xi' xi'7A 50B 120'2O'205120'lect.
Penetration Rm.-
Tr.
A (Chan.
A)
Elect. Penetration Rm.-
Tr.
B (Chan.
D)
EN Surge Tanks Corridor "
Tr. A8B Valve Gallery 0/1 0/1 0/28 0/24, 3/o 1/0 51B 52A 52D 12O'2O'20'pray Chemical Storage Tk Rm.
Central Corridor - Mest
'/1 Central Corridor - East 0/1 1/0 5/17 7/18 64 A.
57I 57J 57N 12O'Aa 14O'o 140'40'40'eactor Trip Switchgear Rm.
~a,a~
R,ash~
Storage and Elect.
Equip.
pgq g Kka cAY+c-w% (oo~
o hing Issue and Men' Locker Rm.
Nomen's Locker, Clean Storage and Lunch Rms.
Corridor Area BUILDING " CONTAINMENT""
1/0 e/o
<lo e/o tt'.
7/o 4/0 66A&66B 100' 120 Southwes't and Southeast Perimeter 1/0 67A867B 100'6A 12O'6B 120'7A867B 120'orthwest and Northeast Perimeter Southwest Perimeter Southeast Perimeter Northwest and Northeast Perimeter I/O 1/0 1/O 1/O PALO VERDE - UNIT 2 '
3/4 3"66
"I wl
>C
TABLE 3.3-11 (Continued)
FIRE DETECTION INSTRUMENTS FIRE ELEVATION INSTRUMENT LOCATION ZONE TOTAL NUMBER OF INSTRUMENTS" HEAT FLAME SMOKE
'xy) 7xi~y
~xi'3A 63B 120'20'o.
2 RCPs and SG Area 6/0 6/0 66A866B 67A867B 140'outhwest, Southeast, Northwest and Northeast Perimeters 1/0 63A 63B 70 71A 71B 72 73
,74A 74B 83 140'40'40'40'40 80'0'00',120'(
140'00',120'(
140'o.
'efueling Pool and Canal Area North Preaccess Normal AFU Area South Preaccess Normal AFU Area HAIN STEAH SUPPORT STRUCTURE Turbine Driven Aux.
Feedpump Rm.
Motor Driven Aux.
Feedpump Rm.
Hain Steam Iael.
& Dump Valve e /<
Area North t
Main Steam Isol.
8 Dump Valve n +
Area South OUTSIDE AREAS Condensate Storage Tank Pump House 5/0 5/0 4/0 2/0 2/0 0/3 2/0 I il<<i
1