ML20099C055
| ML20099C055 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 02/28/1985 |
| From: | MISSISSIPPI POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML20099C044 | List: |
| References | |
| RTR-NUREG-0737, RTR-NUREG-737, RTR-REGGD-01.097, RTR-REGGD-1.097 TAC-51094, NUDOCS 8503110202 | |
| Download: ML20099C055 (55) | |
Text
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REGULATORY GUIDE 1.97 (REVISION 2)
POSITION REPORT FOR GRAND GULF NUCLEAR STATION UNIT 1 MISSISSIPPI POWER & LIGHT FEBRUARY 1985 A
16 F
PDR J0P12RPT85021801 - 1
4 s
GGNS REGULATORY GUIDE 1.97 (REV. 2) POSITION REPORT
1.0 INTRODUCTION
NUREG-0737 Supplement 1, Item 6, " Regulatory Guide (RG) 1.97 - Application to Emergency Response Facilities," states that each operating license holder provide data to assist control room operators in preventing and mitigating the consequences of reactor accidents. RG 1.97 provides guidance to ensure that instrumentation necessary to measure certain pre-scribed variables during and after an accident is available to the appro-priate personnel. As required by NUREG-0737 Supplement 1, this document has been developed to provide the GGNS position on Regulatory Guide 1.97, Revision 2, " Instrumentation for Light Water Cooled Nuclear Power Plants to Assess Plant and Environs Conditions During and Following an Accident" (referred to in this document as RG 1.97). identifies the existing GGNS instrumentation for compliance to the variables provided in Table 1 of RG 1.97 and table contains the specific information requested by Section 6.2 of NUREG-0737 Supplement 1.
The information presented in this attachment represents the existing GGNS design, except for the columns labeled " Reg Guide Compliance, Schedule, and GGNS Position." Attachment 2 contains the notes referenced in the Position Report Tabulation. Attachment 3 provides the MP&L position statements with justification for the RG 1.97 positions on GGNS for those variables which deviate from the requirements of RG 1.97.
2.0 MP&L POSITION ON RG 1.97 DESIGN AND QUALIFICATION CRITERIA FOR GCNS MP&L concurs with the intent of RG 1.97, which is to ensure that necessary and sufficient instrumentation exists in a nuclear power station for assessing plant and environmental conditions during and following an accident as required by 10CFR Part 50, Appendix A and General Design Criteria 13, 19 and 64.
In general, MP&L also concurs with the positions and criteria referenced under RG 1.97 item C. " Regulatory Position" with the following clarifications:
2.1 Seismic Qualification of Category 2 Instrumentation (RG 1.97 para.
1.3.2.a) - Category 2 instruments which perform a safety-related function will meet the requirements of Regulatory Guide 1.100.
i I
Category 2 instruments which are part of a safety-related system for maintaining a pressure boundary will be seismically qualified to insure pressure boundary integrity during accident conditions if the loss of integrity could jeopardize the operation of the fluid system.
The electrical components and control room indication for these variables will not be ceismically qualified. Category 2 instruments that are not included in the clarifications discussed above, will not be designed to meet the seismic requirements of Regulatory Guide 1.100.
2.2 Environmental Qualification of Category 2 Instrumentation (RG 1.97 para. 1.3.2.a) - Instruments for Category 2 variables will be speci-fied and designed to remain functional in a postulated accident environment. The qualification of these instruments will depend on J0P12RPT85021801 - 2
s the instrument usage. Category 2 instruments which are functionally safety-related (i.e., Class IE) and are located in harsh environments will be qualified in accordance with 10 CFR 50.49.
Category 2 instruments which actively form part of the pressure boundary of a safety related system or whose failure could otherwise affect a safety-related system will be qualified to the extent necessary to ensure that such failures do not occur. No additional environmental qualification will be required for the remainder of the Category 2 instruments.
2.3 Quality Assurance (QA) Requirements (RG 1.97 para. 1.3.1.e and 1.3.2.d) - Previously installed Category 1 and 2 instruments as identified in the attachments were installed under the existing QA programs in effect at that time, which met the requirements of 10 CFR 50, Appendix B.
Instrumentation being implemented for RG 1.97 which is required to meet 10 CFR 50 Appendix B, will be installed under the existing QA program at the time of installation. MP&L's OA program is contained in the MP&L QA topical report; MPL-TOP-1A " Operational Quality Assurance Manual."
MP&L will evaluate Category 2 instrumentation for inclusion in the GGNS Q-List for both safety-related and nonsafety-related application. The GGNS operating QA program will then be applied to the appropriate portions of the Category 2 instrumentation as delineated in the Q-List.
2.4 Instrument Identification (RG 1.97 para 1.4b) - The identification of instruments for post-accident monitoring must take into consideration other NUREG-0737 Supplement 1 activities such as detailed control room design review and emergency operating procedures upgrade. By incorporating these activities and RG 1.97 into an integrated project (NUREG 0737 Supplement 1), the NRC has ensured that human factors engineering and RG 1.97 integration is achieved. CGNS will develop a philosophy regarding instrument channel identification as part of the overall Emergency Response Capability program, and it will be imple-mented as part of the GGNS Detailed Control Room Design Review (DCRDR).
2.5 Servicing, Testing and Calibration (RG 1.97 para. 1.5.a) - Se rvicing, testing and calibration programs of instruments are not provided herein, but will be established and implemented on a frequency necessary to maintain instrumentation operability.
3.0 COMPLIANCE TO NUREG-0737 SUPPLEMENT 1 This report fulfills the requirements of NUREG-0737 Supplement I section l
6.2.
As provided in Attachment 1, the Type A,B,C,D and E variables have been addressed showing instrument range, environmental qualification, seismic qualification, quality assurance, redurdancy, power supply, control room display and schedule for implementation as discussed in the GGNS positions. Deviations, considered appropriate for GCNS, are dis-i cussed and supporting justification or alternatives are provided in l.
Where a variable was referenced as more than one type, only
[
the most limiting application for CGNS was evaltated and addressed.
l l'
J0P12RPT85021801 - 3
P The measurement and indication of RG 1.97 variables per NUREG-0737 Supplement 1 section 6.1.b fer display in the control room are discussed in the attachments to this report.
As required by NUREG-0737 Supplement 1 Sections 6.1.c, 6.1.d 8.2.1.h, and 8.4.1.g, Types A, B, C, D, and E variables necessary for TSC and EOF functions will be provided primarily by the use of the GGNS Emergency Response Facility Information System / Safety Parameter Display System (ERFIS/SPDS) as identified in our letter from J. P. McGaughy to H. R.
Denton dated April 15, 1983, in response to NUREG-0737 Supplement 1.
A specific review of these variables for display in the EOF and TSC has not been performed. However, the GCNS ERFIS/SPDS computer based system which will contain both the SPDS safety parameters and the offsite dose assess-ment model for monitoring post accident status will be provided in the TSC and EOF. The SPDS displays and parameter set are still under development, but they will be identified in the GGNS SPDS Safety Analysis.
Human factors considerations of Section 5.1.d to NUREG-0737 Supplement 1 for existing RG 1.97 instrumentation will be evaluated during the GGNS DCRDR review phase and future modifications will be evaluated against the results established by the DCRDR summary results.
4.0 GGNS TYPE A VARIABLES RG 1.97 defines Type A variables as "those variables to be monitored that provide the primary information required to permit the control room operator to take specific manually controlled actions for which no auto-matic control is provided and that are required for safety systems to accomplish their safety functions for deeign basis accident events."
Primary information is defined by RG 1.97 as "information that is essen-tial for the direct accomplishment of the specified safety functions."
(Variables associated with contingency actions that may be identified in written procedures are excluded from this definition of primary informa-tion.) The Type A variables were determined from a review of the control guidelines of the existing CGNS Emergency Procedures and the BWR Emergency Procedure Guidelines. Uninterruptible power supplies (UPS) for these variables were evaluated where momentary interruption is not tolerable.
The type A variables have been or will be provided at GGNS are Category 1.
The following RG 1.97 variablen have been determined to be the Type A variables at CGNS as further identified in Attachment 1:
RPV Level RPV Pressure Drywell Pressure Drywell Atmosphere Temperature Primary Containment Pressure Primary Containment Temperature Suppression Pool Water Temperature Suppression Pool Water Level Containment Hydrogen Concentration Drywell Hydrogen Concentration Group 1 (MSIV) Isolation J0P12RPT85021801 - 4
e o
P23e 1 of 16 a
GGNS POSITION REPORT TABULATION REGUIATORY GUIDE 1.97 (REVISION 2)
REG ITEM NO.
GUIDE GGNS QUALIFICATION GGNS POWER CONTROL VARIABII CAT TYPE / CAT ENVINON SEISMIC REG GUIDE RANGE RANGE SUPPLY REDUNDANCY ROOM DISPLAT TYPE A VARIABLES 1A RPV Level Bottom of core support plate (-316.7) to centerline of main steam line (+118")
Wide Range 1
A/1 Note 4 Note 5
+60 to -160 IE 2 divs.
Recorded in. w.c.
Feel Zone 1
A/l Note 6 Note 21
-117.0 to Non-1E 2 divs.
Recorded
-317.0 in.
RPS w.c.
Shutdown Range 1
B/2 Note 6 Note 21 0 to 180 in.
Non-1E None Recorded w.c.
A/l Note 4 Note 5 15 psia to 1500 psig 0-1500 psis IE 2 divs.
Recorded 3A Drywell 1
A/1 Note 4 Note 5 0-110% design pressure
-10 to +40 IE 2 divs.
Recorded Pressure (0-33 psig) psig UPS 4A Drywell 1
A/l Note 4 Note 5 40 to 440 F 0-400 F IE 2 diva.
Recorded Atmosphere Temperature 5A Primary Ctat 1
A/l Note 4 Note 5 to psia - 3x design
-5/0/+5 psig IE 2 divs.
Recorded Pressure pressure 3x (15 psig) 0-50 psig UPS 6A Primary Ctat 1
A/l Note 4 Note 5 N/A 0-400 F 1E 2 divs.
Recorded Temperature 7A Suppression A/I Note 4 Note 5 30 to 230 F 30-230 F Non-1E 2 divs.
Recorded Pool Wtr RPS Temp SA Suppression 1
A/1 Note 4 Note 5 Bottom of ECCS suction 0-180 in.
IE 2 divs.
Recorded Pool Wtr (103'0") to 5 ft above w.c.
UPS Level normal level (116'7")
103*6"-
188'6" plant elevation
- =.--.. ~ ~
o P ge 2 ef 16 t
ITEM NO.
SPDS QA REG GUIDE GGNS VARIABM (NUTE 1)
(NOTE 2)
INSTRtBENT Col 9ENTS COMPLIANCE SCHEDULE POSITION
/
4 TYPE A VARIAB11S IA RPV Level Yes NA NA Wide Rasse Yes Yes B21-LT-N091 B21-UR-R623 Fuel Zooe No Yes B21-LT-N044 Note 7 Yes Second refuel Position I B21-LR-R615 outage Shutdows No Yes 321-LT-N027 Note 7 Yes Second refuel Position 1 l
Range B21-LT-R605 Note 3 outage 1
1 2A RPV Pressure Yes Yes B21-PT-N062 Note 8 Yes First refuel Position 2 B21-11R-R623 outage 4
3A Drywell Yes Yes M71-PDT-N001 Yes NA NA Pressure M71 *9R-R601 4
4A Drywell Yes Yes M71-TE-N013 Note 10 Yes First refuel Position 3 Atmosphere Note 9 M71-TE-N008 Note 3 outage j
Temperature M71-TR-R602 l
M71-TR-R603 5A Primary Ctat Yes Yes M71-PDT-N002 Yes NA NA Pressure M71-PDT-N027 M71-PDR-R601
)
6A Primary Ctat Yes Yes M71-TE-N007 Note 11 Yes NA NA i
Temperature Note 9 M71-TR-R602 j
M71-TR-R603 7A Suppression Yes Yes M71-TE-N012, Note 12 Yes First refuel Position 4
]
Pool Wtr Note 9 N022 N023, outage l
Temp N024, N025, t
NO26 M71-TR-R605 8A Suppression Yes Yes E30-LT-N003 Note 13 Yes First refuel Position 5 Pool Wtr E30-LR-R600 Note 3 outage I
J s
i 1
I i
1 i
o P:ge 3 ef 16 REG ITEN NO.
GUIDE GGIS QUALIFICATION GGNS POWER CONTROL VARIABEK CAT TYPE / CAT ENVIRON SEISMIC REG GUIDE RANGE RANGE SUPPLY REDUNDANCY ROOM DISPIAY 9A Ctet Bydrogen 1
A/1 Note 14 Note 5 0-30% N2 0-10% Na IE 2 diva.
Recorded Concentration ICA Drywell Ny-1 A/1 Note 14 Note 5 0-30% N2 0-10% H2 1E 2 divs.
Recorded drogen Coe-centrstion 11A Group 1 1
A/1 Note 4 Note 5 Closed, open
- Closed, Non-1E None Indicated Isolation Note 19 open RPS TYPE B VARIABIIS IB Neutroe Flam 1
3/1 Note 16 Note 16 10-s to 100% power 10 "-125%
Non-1E None Note 17 power RPS 2B Control Rod 3
B/3 Nome None Full in or Note 20 Non-1E NA Note 20 Position Not full in 3B RCS Soluble 3
E/3 See Item 20E 0-1000 ppe See Item 20E Beroe Conces-tration Sample l
4B RPV Level 1
A/1 See Itco 1A
-316.7 to +118" See Item 1A 53 ShR Core 1
NA NA NA 200 to 2300 F NA NA NA NA l
Thermo-couples 6B RPV Pressure I
A/1 See Item 2A 15 psia to design See Item 2A pressure (1025 psig) 73 Drywell 1
A/1 See Item 3A 0 to design pressure See Item 3a Pressure (30 psig) 83 Drywell Sump I
3/3 Nome Note 21 Bottom to top (0-30")
0-M ' H O 1E None Recorded 2
Isvel 95 Primary Coe-1 A/1 See Item 5A 10 psia to design See Item 5A tainment pressure (15 pais)
Pressure
P;ge 4 cf 16 IYEM NO.
SPDS QA IIEG GUIDE GGIIS VARIABLE (IN N E 1)
(IIDTE 2)
IIBSYRIBENY C019ElffS C0ffLIANCE SCNEDULE POSITICII 9A Ctat Rydroges Yes Yes E61-AlYS-E002 Ilote 15 Yes NA Position 6 Concestration E61-AR-R602 Note 3 ICA Drywell Ny-Yes Yes E61-AlYS-E001 Note 15 Yes MA Position 6 drogee Coe-E61-AR-R602 Note 3 centration 11A Group i No Yes Note 18 Note 19 Yes First refuel Position 8 Isolation Note 3 outage YYPE B VARIABIIS 13 Neetros Fles Yes Note 16 C51-NE-N001 Note 16 No Second refuel Position 7 N002, 5011, outage N012, N013, h014 Note 17 2R Control Rod No Nome Cll-ZS-N124 Yes NA NA Position C11-ZS-M125 Note 3 38 BCS Solable Boroe Conces-tration Sample 48 RPV Level
$3 Eh4 Core NA NA NA NA NA NA Position 9 Yherne-couples
. 6B RPV Pressere 7R Drywell Pressure St Drywell Semy No Note 22 E31-LY-N093 Yes NA Position 10 level E31-LR-R618 Note 3 98 Primsry Coe-tainment Pressure
o Pcae 5 af 16 REG ITDt NO.
CUI.
GCNS
_ QUALIFICATION _
CGNS POWER CONTROL VARIABLE CAT TYPE / CAT ENVIRON SEISMIC REG CUIDE RANCE RANCE SUPPLY REDUNDANCY ROOM DISPIM 10B Primary Coe-1 B/l Note 4 Note 5 Closed-Not closed Closed /open IE No Indicated tainment Iso-Except lation Valve Group 1 Position TYPE C VARIABII.S IC Radiation 1
E/3 None None
( to 100) x tech spec 10-2 pCi/ml Non-1E None None Coac. in Cir-limit (52 pCi/sm x I-131 to any range culating Pri-and $100/EpC1/ge) by dilution mary Coolant 2C Analysis of 3
E/3 See item 19E 10 pCi/gm to 10 Ci/gm See Ites 19E Primary Coolant Camma Spectrum 3C BWR Core I
NA See Item 5B 200 to 2300 F See Item 5B Thermocouples 4C RPV Pressure 1
A/I See Item 2A 15 psia to 1500 psig See Item 2A SC Primary Ctat 3
C/l Note 4 Note 5 1 R/hr to los R/hr 1-10 R/hr IE 2 divs.
- Monitor, 7
Area Radiation UPS recorded 6C Drywell Draio 1
B/3 See Item 8B Bottom to top (0-30")
See Item 8B Sump Isvel 7C Sappression 1
A/l See Item 8A Bottom of ECCS suction See Item 8A Pool Water to 5 feet above normal Level water level 8C Drywell 1
A/l See Item 3A 0 to design pressure See Item 3A Pressure (0-30 psig) 9C RPV Pressure 1
A/l See Item 2A 15 psia to 1500 psig See Item 2A 10C Containment &
I A/l See Items 9A 0-30% Hz 12 psia to See Items 9A Drywell Rydro-
& 10A design press. environ
& 10A gem IIC Costainment &
1 NA NA NA 0-101 03 NA NA NA NA Drywell Oxyges 12C Containment 3
E/2 See Item 4E 10'* to 10'2 pCi/cc See Item 4E Effloent Radioactivity Noble Cas
o P:ge 6 ef 16 ITElf NO.
SPDS QA REG GUIDE GGNS VARIABLE (NOTE 1)
(NUTE 2)
INSTRtMNT COISENTS COWLIANCE SCIEDULE POSITION 108 Primary Cee-No Yes Note 23 Note 19 Yes First refuel Position 11 tainment Iso-Note 3 outage lation Valve Position TYPE C VARIARLES Yes NA Position 12 IC Radiation No No P.A.S.S.
Invel in Cir-Note 3 culating Pri-mary Coolmat 2C Analysis of Primary Coolant Casma Spectre 3C BhR Core Thermocouples 4C RPV Pressure SC Primary Ctat Yes Yes D21-RE-N048 Yes NA NA Area Radiation D21-RR-R601 6C Drywell Drain 7C SepPression Pool W ter Level SC Drpsell Pressure 9C RPV Pressure IIC Containment &
Drywell Nydro-See 11C Containment &
NA NA NA Does not NA NA Ctat is not inert; Drywell Oxyges apply to does not apply GGNS 12C Containment Effluent Radioactivity Noble Gas
Pcse 7 af 16 REC 17D8 NO.
GUIDE GGNS QUALIFICATION GGNS POWR CONTROL VARIABLE CAY TYPE / CAT ENVIRON SEISftIC REC GUIDE RANGE RANGE SUPPLY REDUNDANCY ROOM DISPLAY 13C Radiation 2
.NA NA NA 10~1 to 10* R/br NA NA NA NA Exposure Rate 8
14C Effluent Radio-2 E/2 See Item 7E 10-6 to 10 pCi/cc See Item 7E activity Noble Gases TYPE D VARIABIES ID Main Feedwater 3
D/3 None None 0-110% design flow 0-14 alb/hr Non-1E 2 channels Indication Flow (0-22.6 alb/hr) per line UPS l
2D CST Level 3
D/3 None None Bottom to top l'1" to 41'1" Non-1E None Indication (0-31'0")
level UPS 3D Ctat Spray 2
D/2 Note 4 Note 5 0-110% design flow 0-10 kape IE None Indication I
Flow (0-8195 spe) l 4D Drywell 2
A/l See Item 3A 12 psia to 3 psig See Item 3A Pressure l
SD Suppression 2
A/1 See Ites SA Top of vent to top of See Item 8A l
Pool Water weir wall Level 6D Suppression 2
A/1 See item 7A 30 to 230 F See Item 7A Pool Water Temp 7D Drywell 2
A/1 See Item 4A 40 to 440 F See Item 4A Atmosphere Temp 8D Drywell Spray 2
NA NA NA 0 to 110% design flow NA NA NA NA Flow 9D MSIV Leakage 2
D/2 Note 4 Note 5 0-15" w.c.
0-50 psia IE 2 divs.
Recorded Control Sys 0-5 psid 0-100 psig Press.
10D SRV Position 2
D/2 Note 4 Note 5 0-50 psig 0-100 psig IE None Indiration Pressure in UPS Valve Line 11D Isol Coed Sys 2
NA NA NA
'op to bottos NA NA NA NA Shell-Side Wtr Lvl l
e P;ge 8 af 16 e
ITEM NO.
SPDS QA REG GUIDE GGNS VARIABIX (NOTE I)
(NOTE 2)
INSTRLDENT COPBENTS COMPLIANCE SCHEDULE POSITION 13C Radiation NA
- NA NA NA NA NA Position 13 Exposure Rate 14C Effluent Radio-activity Noble Gases TYPE D VARIABLES ID Nain Feedwater Yes No N21-FT-N087 Yes NA NA Flow Note 9 N21-FI-R686 2D CST Level Yes No Pil-LT-N003 Yes NA Position 14 P11-LI-R601 Note 3 Yes NA Position 15 3D Ctat Spray Yes Yes E12-FT-N015 Flow E12-FI-R603 Note 3 4D Drywell Pressure SD Suppression Pool Water Level 6D Suppression Pool Water Temp 7D Drywell Atmosphere Temp 8D Drywell Spray NA NA NA Does not NA NA NA Flow apply to GGNS 9D MSIV Leakage No Yes E32-PT-N051 Yes NA NA Control Sys E32-PT-N061 Press.
E32-PIS-N651 E32-PIS-N661 10D SRV Position No Yes B21-PS-N150 Yes NA NA Pressure in B21-XA-L634 Valve Line 11D Iso Cond Sys NA NA NA Does not NA NA NA Shell-Side apply to Wtr Lvl GGNS l
P ge 9 ef 16 REG ITEM NO.
CUIDE GCNS QUALIFICATION GGNS POWER
' CONTROL VARIABLE CAT TYPE / CAT ENVIRON SEISMIC REG GUIDE RANGE RANGE SUPPLY REDUNDANCY R00tf DISPLAY 12D Isol Cond Sys 2
NA NA NA Open or Closed NA NA NA NA Viv Position 13D RCIC Flow 2
D/2 Note 4 Note 5 0-110% design flow 0-1000 gpa IE None Indication (0-880 gne)
D/2 Note 4 Note 5 0-110% design flow 0-10,000 gpm IE None Indication (0-7826 gpm)
D/2 Note 24 Note 5 0-110% design flow 0-10,000 gpa IE None Indication (0-7826 gpm) 16D LPCI Flow 2
D/2 Note 4 Note 5 0-110% design flow 0-10,000 spe IE None Indication (0-8195 spm) 17D SLCS Flow 2
NA NA NA 0-110% design flow NA NA NA NA 18D SLCS Storage 2
D/3 None None Bottom to top 0'6 1/8" -
IE None Indication Tank Level (0-12'1")
11' O 1/8" 19D RHR System 2
D/2 Note 4 Note 5 0-110% design flow 0-10,000 gpa IE None Indication Flow (0-8195 spm) 20D RHR Heat 2
D/2 Note 24 Note 5 32 to 350 F 0-750*F Non-1E None Recorded Exchanger UPS (0-600*F)
Outlet Temp 21D Cig Wtr Temp 2
D/2 Note 24 Note 5 32 to 200 F 0-750'F Non-1E None Recorded to ESF Sys UPS (0-600'F)
Components 4
I
{
22D C1g Wtr Flow 2
D/2 Note 24 Note 5 0-110% design flow 0-15,000 spa IE UPS None Available to ESF Sys (0-14,700 gpm SSW)
SSW SSW for call-up Components (0-850 spe HPCS) 0-1000 gpa IE on computer HPCS HPCS 23D High Radio-3 D/3 None None Top to bottom (0-16'5")
10 5/8" to Non-1E 2 channels None activity Liquid (0-16'7")
overflow Note 25 Tank Level 24D Emergency 2
D/2 Note 4 Note 5 Open, closed Open/close IE None Indicated Ventilation Damper Position 1
P;se 10 af 16 ITEM NO.
REG GUIDE GCNS VARIABLE (NOTE 1)
(NOTE 2)
INSTRUMENT COMMENTS COMPLIANCE SCHEDULE POSITION 12D Isol Cond Sys NA NA NA Does not NA NA NA Vlv Position apply to GGNS 13D RCIC Flow Yes Yes E51-FT-N003 Yes NA NA E51-FI-R606 14D HPCS Flow Yes Yes E22-FT-N005 Yes NA NA E22-FI-R603 15D LPCS Flow Yes Yes E21-FT-N003 Yes NA NA E21-FI-R600 16D LPCI Flow Yes Yes E12-IT-N015 Yes NA Position 15 E12-FI-R603 17D SLCS Flow NA NA NA Yes NA Position 16 Note 3 18D SLCS Storage No None C41-LT-N001 Yes First Refuel Position 17 Tank Level C41-LI-R601 Note 3 Outage 19D RHR System No Yes E12-FT-N015 Yes NA NA Flow E12-FI-R603 20D RHR Heat Yes Yes E12-TE-N027A&B Yes First Refuel Position 18 Exchanger E12-TJRS-R601 Outage Outlet Temp 21D Clg Wtr Temp No Yes P41-TE-N011 Yes NA Position 19 to ESF Sys E12-TJRS-R601 Components 22D C1g Wtr Flow No Yes P41-FT-N016A&B.
Yes NA NA to ESF Sys SSW Components P41-FT-N016C HPCS 23D High Radio-No No SG17-LT-N280 Note 25 Yes NA NA activity Liquid SG17-LT-N283 Tank Level 24D Emergency No Yes Note 26 Yes NA NA Ventilation Damper Position
P;ge 11 ef 16 REG ITEM NO.
GUIDE GGNS QUALIFICATION GGNS POWER CONTROL VARIABLE CAT TYPE / CAT ENVIRON SEISMIC REG GUIDE RANGE RANGE SUPPLY REDUNDANCY ROOM DISPLAY Status of Standby Power & Other Energy Sources Important to Safety 25D AC Power 2
D/3 Note 27 Note 27 Volts, amps Note 27 Note 27 "None Indicated 26D DC Power 2-D/2 Note 27 Note 27 Volts, amps Note 27 Note 27 None Indicated 27D Hydraulic /
2 D/3 Note 27 Note 27 Pressure Note 27 Note 27 None Indicated Pneumatic TYPE E VARIABLES 7
lE Primary Ctat 1
C/1 See Item SC 1-10 R/hr See Item SC Area Radiation 7
2E Reactor 1
C/l NA NA 1-10 R/hr NA NA NA NA Building or Secondary Containment Area Radiation 3E Radiation 2
E/3 None None 10 104 R/hr Note 28 Non-lE None Note 28 Exposure Rate UPS Noble Cases & Vent Flow Rate 4E Drywell Purge, 2
E/2 Note 6 Note 29 10-8 to 105 pCi/cc Note 30 Note 30 None Note 31 SGTS & Ctat 0-110% vent design Purge flow rate SE Secondary Ctat 2
E/2 See Item 4E 10-s to 104 pCi/cc See Item 4E Purge 0-110% vent design flow rate 6E Secondary Ctat 2
NA NA NA 10-s to 104 pCi/cc NA NA NA NA (Shield 0-110% vent design Building flow rate Annulus) 7E Auxiliary 2
E/3 Note 6 Note 29 10-s to 108 pCi/cc Note 33 Note 33 None Note 31 Building 0-110% vent design flow rate 8E Co m a Plant 2
NA NA NA 10-s to jos pCi/cc NA NA NA NA Vent or Multi-0-110% vent design put90se Vent flow rate Disc.grging
P ge 12 ef 16 ITEM NO.
SPDS QA REG GUIDE GGNS VARIABLE (NOTE 1)
(NOTE 2)
INSTRLMENT C0f9fENTS COMPLIANCE SCHEDULE POSITION Status of Standby Power & Other Energy Sources Important to Safety 25D AC Power No Note 27 Note 27 Note 27 Yes NA Position 20 Note 3 26D DC Power No Note 27 Note 27 Note 27 Yes NA Position 20 Note 3 27D Hydraulic /
No Note 27 Note 27 Yes NA Position 20 Pneumatic Note 3 TYPE E VARIABLES lE Primary Ctat Area Radiation 2E Reactor Build-NA NA NA Does not NA NA NA ing or Secondary apply to Containment GGNS Area Radiation 3E Radiation No No Note 28 Yes NA Position 21 Exposure Rate Note 3 Noble Cases & Vent Flow Rate 4E Drywell Purge, No No Note 30 Note 32 Yes First Refuel Position 22 SGTS & Ctat Note 3 Outage Purge SE Secondary Ctat NA NA NA Purge 6E Secondary Ctat NA NA NA
[bes not NA NA NA (Shield Build-apply to ing Annulus)
GCNS 7E Auxiliary Bldg No No Note 33 Note 34 Yes NA Position 23 Note 3 8E Common Plant Vent NA NA NA Does not NA NA NA or Multipurpose apply to Vent Discharging GGNS
P;ge 13 cf 16 REG ITEM NO.
GUIDE GGNS
_ QUALIFICATION GGNS POWER CONTROL VARIABLE CAT TYPE / CAT ENVIRON SEISMIC REG GUIDE RANGE RANGE SUPPLY REDUNDANCY ROOM DISPLAY 9E All Identified 2
NA NA NA 10-s to 102 pCi/cc NA NA NA NA Plant Release 0-110% design flow Points; Sampling w/On-site Analysis Capability Particulates and Halogens 10E All Identified 3
E/3 None None 10'8 - 102 pCi/cc Note 35 None None Note 31 Plant Release 0-110% design flow Points; Samp-ling w/Onsite Analysis Capa-bility 11E Radiation NA NA None None NA None None None None Exposure Meters 12E Airborne Rad-3 E/3 None None 10 10-8 pCi/cc 10-e to 10~8 NA NA No iohalegens &
pCi/cc Particulates (Portable) c R/hr photons 10-8 to 2 x NA NA No 13E Plant & Envi-3 E/3 None None 10-8-104 rons Radiation 10-8-104 4
R/hr beta &
10 R/hr (Portable) low energy photons photons &
beta 14E Plant & Environs 3 E/3 None None Multichannel Multichannel NA NA No Radioactivity spectrometer analyzer 15E Wind Direction 3
E/3 None None 0-540', starting speed Note 39 Non-1E Note 40 Note 40
.7 mph, dampening.4 at 10' distance con-stant 1.1 meters, accu-racy 13*
16E Wind Speed 3
E/3 None None 0-90 mph, accuracy 11%,
Note 41 Non-1E Note 40 Note 40 distance constant 5 ft, starting threshold 0.63 aph 17E Estimation 3
E/3 None None
-10*F to 20*F delta Note 42 Non-1E Note 40 Note 40 of Atmospheric 10.I'F or 1% of AT Stability
Pzge 14 af 16 ITEM NO.
SPDS QA REG CUIDE GGNS VARIABLE (NOTE 1)
(NOTE 2)
INSTRUMENT CofffENTS COMPLIANCE SCNEDULE POSITION j
9E All Identified NA NA NA.
No other NA NA NA Plant Release release Points; Samp-points ling w/Onsite identified Analysis Capa-bility Particulates and Halogens 10E All Identified NA No Note 35 Yes NA NA Plant Release Points; Samp-ling w/Onsite Analysis Capa-bility llE Radiation No No No NA Position 24 Exposure Meters 12E Airborne Rad-NA No Note 36 Yes NA NA iohalogens &
Particulates (Portable) 13E Plant & Envi-NA No Note 37 No NA NA rons Radiation (Portable) 14E Plant & Environs NA No Note 38 Yes NA NA Radioactivity ISE Wind Direction Yes No C84-ST-N018 &
Yes NA NA N022 16E Wind Speed Yes No C84-ZT-N018 &
Yes NA NA NO21 17E Estimation Yes No C84-TT-N023 &
Yes NA NA of Atmos-N020 pheric Stability I
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P;se 15 of 15 REG ITEN NO.
GUIDE CGNS QUALIFICATION GGNS POWER CONTROL VARIABLE CAT TYPE / CAT ENVIRON SEISMIC REG GUIDE RANGE RANGE SUPPLY REDUNDANCY ROOM DISPIM Accident Sampling I.
Primary Coolant and Sump 1 R Gross Activ-3 E/3 None None 10 pCi/ml to 10 Ci/ml 10-2 pCi/ml Non-1E None None ity to any range by dilution 19E Camusa Spec-3 E/3 None None Isotopic Analysis Isotopic Non-1E None None trum Analysis 20E Boron Content 3
E/3 None None 0-1000 ppm 250-10,000 Non-1E None None PPe 21E Chloride Content 3 E/3 None None 0-20 ppa 100 ppb-1 ppe Non-1E None None 1-20 ppm 22E Dissclved 3
E/3 None None 0-2000 cc/kg (STP)
.5-50% H Non-1E None None N2 or Total Gas 23E Dissolved 02 3
E/3 None None 0-20 ppe 500 ppb-19 ppe Non-1E None None 24E pH 3
E/3 None None 1-13 ppe 0-14 i.2 Non-1E None None II. Containment Air 25E Hydrogen 3
E/3 None None 0-10%
Note 44 Non-1E None None 26E Oxygen 3
E/3 None None 0-30%
Note 44 Non-1E None None 27E Causa Spectrum 3
E/3 None None Isotopic Analysis Isotopic Non-1E None None Analysis
P ge 16 af 15 ITEM NO.
SPDS QA REG GUIDE GGNS VARIABLE (NOTE 1)
(NOTE 2)
INSTRUMENT COMMENTS COMPLIANCE SCHEDULE POSITION Accident Sampling Note 43 Note 43 Yes NA Position 25 Note 3 I.
Primary Coolant and Sump 18E Gross Activ-NA NA Yes NA ity 19E Camma Spec-NA NA Yes NA trum 20E Boron Content NA NA No NA 21E Chloride NA NA No NA Content 22E Dissolved H 2 NA NA No NA or Total Gas 23E Dissolved 03 NA NA No NA 24E pH NA NA Yes NA II. Containment Air 25E Hydrogen NA NA Note 44 Note 44 Yes NA 26E Oxygen NA NA Note 44 Note 44 Yes NA 27E Gasuna Spectrum NA NA Yes NA
-~ ~ '~
Attachnent 2 Page 1 of 18 NOTES FOR GCNS POSITION REPORT TABULATION REGULATORY CUIDE 1.97 (REVISION 2)
Note 1 Items noted as "Yes" are presently input into the Emergency Response Facility Information System (ERFIS) which will be available for on-demand callup from the control room TSC and EOF. The ERFIS inputs will be evaluated further based on this document and the revised SPDS parameter set developed from the GGNS upgraded emergency operating procedures.
Note 2 Items indicated as "Yes" were installed under the existing QA programs in effect at that time which met the requirements of 10 CFR 50, Appendix B.
Note 3 Based on the modifications being proposed by MP&L and/or the existing GGNS design which is considered by MP&L to meet the " intent" of Regulatory Guide 1.97, CGNS is con-sidered to be in compliance with Regulatory Guide 1.97, Rev. 2, for this variable.
Note 4 Instrumentation complies with 10 CFR 50.49.
Note 5 Instrument seismic qualification meets the requirements of IEEE 344-1975.
Note 6 Instrumentation is located in a harsh environment; however, it is not presently required to meet the 10 CFR 50.49 requirements.
Note 7 Only the existing wide range RPV level instruments meet the requirements for Category 1.
-Note 8 These instruments are used as a primary indication which provides key information for assessing the extent of certain accidents, as required by the BWR EPGS.
Note 9 The same variable is input to ERFIS as to the control room, but the signals are derived from different instruments.
The qualification and QA sections in the table are for control room input only. This will be evaluated further during the SPDS parameter set development.
Note 10 The existing GGNS design does not presently comply with Reg. Guide 1.97 in that instrumentation does not monitor a range of 40 to 440 F and is not on IE UPS power.
Note 11 Based on the energy transfer rate between drywell and containment atmospheres (Reference FSAR Chapter 6.2),
containment temperature will remain relatively constant
if Page 2 of 18 over the time period standby power would be unavailable (210.sec). Therefore, uninterruptible power is not required.
Note 12
-The present GGNS normal power supply is RPS with manual switching to standby power through non-Class IE control circuits.
Note 13 The existing GGNS instrumentation monitors a range from 103'-6" (centerline of ECCS suction) to 118'-6".
The centerline of ECCS suction is the lowest available level for use of the suppression pool as a source for ECCS water (i.e., at or above.this. point the RHR pumps would begin to lose suction). Therefore, the remaining pool volume (below 103'-6") is not available for RPV injection.
Note 14 Post-LOCA gas analysis systems E61-J001A/B and J002A/B (of which E61-AITS - K001A/B and K002A/B are a part) are covered by 10 CFR 50.49 Qualification Program.
Note.15 Containment and Drywell Hydrogen Concentration The discussion and models used for hydrogen control issues have shown that the hydrogen recombiners " trip" on over-temperature at approximately 4% hydrogen levels. The 1/20th scale test performed for the hydrogen control issue has also shown that hydrogen burn (caused by the hydrogen igniters) occurs at 6% hydrogen concentration.
Note 16 There are two areas in which the present instrumentation does not meet Category I requirements:
the first is qualification;- the second is that present power supplies-are either non-Class IE or not uninterruptible. The present status of both is shown in Table 1.
The detectors and amplifiers were installed under the construction QA program.
Table 1 PRESENT STATUS OF NEUTRON MONITORING SYSTEM Equipment SRMs IRMs LPRMs/APRMs Drive-Non-1E power, Non-1E power, Not applicable
- Mechanisms
'No qualification-No gaalification Detectors &
RPS power RPS power, IEEE RPS power, Amplifiers 323-1971 & IEEE IEEE 323-1971 344-1975 Recorders &
Non-1E UPS power Non-1E UPS power Non-1E UPS power.
Indicators No qualification Ne qualification No qualification
Page 3 of 18 Note 17 Recorders C51-NR-R602A SRM Recorder A C51-NR-R602B SRM Recorder B C51-NR-R603A IRM/APRM Recorder A C51-NR-R603B IRM/APRM Recorder B C51-NR-R603C IRM/APRM Recorder C C51-NR-R603D IRM/APRM Recorder D Note 18 This table provides the instrument numbers for those valves used as Group 1 Isolation.
Position Indicated on Isolation Valve Status Valve Instrument Panel B21-F022A B21-ZS-N101A Yes B21-F022B B21-ZS-N101B Yes B21-F022C B21-ZS-N101C Yes B21-F022D B21-ZS-N101D Yes B21-F028A B21-ZS-N102A Yes B21-F028B B21-ZS-N102B Yes B21-F028C B21-ZS-N102C Yes B21-F028D B21-ZS-N102D Yes Note 19 Primary containment isolation valve position indication is the key variable for determining the status of primary containment isolation. The present instrumentation meets the requirements of Regulatory Guide 1.97 with the following exceptions:
1.
The position switches for the Group 1 isolation valves (B21-F022A, B, C, and D, and B21-F028A, B, C, and D) do not have a Class 1E power supply.
2.
Redundant valve position indication is not provided for each valve. Therefore, valve position indication does not meet the single failure criterion of Section 1.3.1.b of Regulatory Guide 1.97.
3.
The control room indicating lamps are not seismically qualified per IEEE 344-1975.
Page 4 of 18 Group 1 Isolation Group 1 isolation does not meet the specific criteria of a Type A variable, since no specific operator action is required from monitoring this variable. However, MP&L considers its importance for RPV isolation under accident conditions and its recognition as an entry condition into the RPV control guideline of the BWR EPGs, to be equivalent to a Type A variable.
Note 20 The Control Rod Position System consists of two independent channels in monitoring control rod position. Both channels have separate signals and perform exactly the same function.
There are 49 control rod positions per rod, including fully inserted (position 00) per channel. The control rooc4 operator may select Channel A, Channel B, or both for display on a 2-character, seven segment L.E.D. display device for each rod. Additionally, there is a single indicating lamp for all rods fully inserted.
Note 21 This device was installed seismically, but is not qualified to function after a seismic event.
Note 22 This instrument was installed under the construction QA Program, but no QA Program was used for purchasing, manu-facturing, shipping, receiving, or storing of this device.
Note 23 The following table provides the existing instrument numbers for the primary containment isolation valve position indication.
(Group 1 isolation indication is provided in Note 18.)
Position Indication on the Isolation Valve Status Valve Inst rument Panel P71-F148 P71-ZS-N020 Yes P71-F149 P71-ZS-N021 Yes PS2-F105 PS2-ZS-N012 Yes P53-F001 P53-ZS-N011 Yes P45-F067 P45-ZS-N079 Yes P45-F061 P45-ZS-N071 Yes P45-F068 P43-ZS-N080 Yes P45-F062 P45-Zu-N072 Yes P45-F273 P45-ZS-N506 Yes P45-F274 P45-ZS-N507 Yes P45-F098 P45-ZS-N027 Yes l
P45-F099 P45-ZS-N028 Yes l
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Page 5 of 18 Position Indication on the Isolation Valve Status Valve Instrument Panel Pll-F075 P11-ZS-F005 No P11-F130 P11-ZS-N070 Yes P11-F131 P11-ZS-N071 Yes P21-F017 P21-ZS-N017 No P21-F018 P21-ZS-N003 Yes P53-F003 P53-ZS-N012 Yes P60-F009 P60-ZS-N009 Yes P60-F010 P60-ZS-N010 Yes P44-F053 P44-ZS-N009 No P44-F069 P44-ZS-N032 No P44-F070 P44-ZS-N029 No P71-F150 P71-ZS-N022 No E61-F009 E61-ZS-N019 Yes E61-F010 E61-ZS-N020 Yes E61-F056 E61-ZS-N027 Yes E61-F057 E61-ZS-N028 Yes E12-F011A E12-ZS-N131A Yes E12-F011B E12-ZS-N131B Yes E12-F024A E12-ZS-N122A No E12-F024B E12-ZS-N122B No E12-F028A E12-ZS-N110A No E12-F028B E12-ZS-N110B No E12-F037A E12-ZS-N119A No E12-F037B E12-ZS-N119B No G33-F053 G33-ZS-N121B Yes G33-F054A G33-ZS-N121A Yes G33-F252A G33-ZS-N128 Yes G36-F101 G33-ZS-M138 No G36-F106 G33-ZS-N136 Yes M41-F011 M41-ZS-N026 Yes M41-F012 M41-ZS-N027 Yes M41-F034 M41-ZS-N018 Yes M41-F035 M41-ZS-N019 Yes G41-F028 G41-ZS-N103 Yes G41-F029 G41-ZS-N102 Yes G41-F044 G41-ZS-N101 Yes B21-F019 B21-ZW-N117 Yes B21-F016 B21-ZS-N116 Yes B21-F067A B21-ZS-N104A Yes B21-F067B B21-ZS-N104B Yes B21-F067C B21-ZS-N104C Yes B21-F067D B21-ZS-N104D Yes E12-7321 E12-ZS-N122C Yes
Page 6 of 18 Position Indication on the Isolation Valve Status Valve Instrument Panel E12-F008 E12-ZS-N104 Yes E12-F009 E12-ZS-N103 Yes E21-F012 E21-ZS-N106 No E12-F023 E12-ZS-N132 Yes E22-F023 E22-ZS-N106 Yes E51-F078 E51-ZS-N133 Yes E51-F031A E51-ZS-N100 No E51-F077 E51-ZS-N133 Yes E51-F063 E51-ZS-N109 Yes E51-F064 E51-ZS-N110 Yes E51-F076 E51-ZS-N120 Yes G33-F028 G33-ZS-N113 Yes G33-F034 G33-ZS-N114 Yes G33-F001 G33-ZS-N104 Yes G33-F004A G33-ZS-N105 Yes G33-F039 G33-ZS-N110 Yes G33-F040 G33-ZS-N109 Yes Relief valves E12 -F017A/B/C, E12-F025C, E12-F055A/B, E12-F036. E12-F005, E22-F014, E21-F018 and manual valves G41-F053 and G41-F201 are containment isolation valves that do not have position indication. In addition, the fuel transfer tube.in the G41 system also does not have position indication. The two manual valves and the fuel transfer tube can be locked closed and kept under administrative control. The 10 relief valves are not capable of being fitted with position switches.
Note 24 Instrument is presently exempt from the existing NUREG-0588' l
requirements; therefore, qualification to 10 CFR 50.49 is not required.
Note 25 All sumps that could collect highly radioactive fluids after an accident pump to either the equipment drain collector tank or to the floor drain collector tank. Each tank has its level indicated and recorded on the radwaste I
console. The present instrumentation monitors a range from 10-5/8 inches to greater than tank overflow. This range covers the total usable volume of the tank. Monitoring the tank level below 10-5/8 inches is not considered necessary because this is below the pump shutoff level of 1 foot 2 inches.
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1 Page 7 of 18 i
Note 26 Primary containment penetrations for vents and purges are covered in containment isolation valve position section (Item 10B).
The secondary containment dampers are as follows:
Valve Position Indicated on Isolation Valve Status Valve (Damper)
Instrument Panel Q1T41F006 T41-ZS-N025 No Q1T41F007 T41-ZS-N026 Yes Q1T42F003 T42-ZS-N013 No Q1T42F004 T42-ZS-N016 No Q1T42F011 T42-ZS-N002 No Q1T42F012 T42-ZS-N001 No Q1T42F019
.T42-ZS-N022 No Q1T42F020 T42-ZS-N021 No Q1M41F007 M41-ZS-N023 Yes Q1M41F008 M41-ZS-N022 Yes Q1M41F036 M41-ZS-N020 Yes Q1M41F037 M41-ZS-N021 Yes -
Note 27 The variables in this category for GGNS are-as follows:
- 1) ADS Air Receiver and Accumulator Pressure
- 2) Starting Air Pressure for Standby Diesel Generators
-3) Starting Air Pressure for HPCS Diesel Generators
- 4) HPCS Standby Power, Voltage and Current (Division III)
- 5) Division I and II AC Power, Voltage and Current
- 6) Class IE DC Power, Voltage and. Current STATUS OF STANDBY POWER INDICATORS Function Instrument Tyge Range LCC 15 BA4 INCH FDR 52-15401 R20-II-R627A 185 0-1200A ac 480 V LCC 15 BA4 R20-EI-R628A 185 0-600 V ac
'LCC 15 BA2 INCM FDR 52-15201 R20-II-R629A 185 0-1200A ac 480 V LCC 15 BA2 R20-EI-R630A 185 0-600 V ac Bus 15AA INCM FDR 152-1511 R21-II-R613A 185 0-1500A ac 4.16 kV Bus 15AA R21-EI-R615A 185 0-5.25 kV ac LCC 15 BA6 INCM FDR 52-15601 R20-II-R648A 185-0-1200A ac 480 V LCC 15 BA6 R20-EI-R647A 185 0-600 V ac Bus 15AA INCM FDR 152-1501 R21-II-R616A 185 0-1500A ac Bus 15AA INCM FDR 152-1514 R21-II-R617A
- 185 0-1500A ac LCC 15 BAS INCM FDR 52-15501 R20-II-R631A 185 0-1200A ac 480 V LCC 15 BAS R20-EI-R632A 185 0-600 V ac LCC 15 BA1 INCM FDR 52-15101 R20-II-R633A 185 0-1200A ac
Page 8 of 18 Function Instrument Tyge Range 480 V LCC 15 BA1 R20-EI-R634A J85 0-600 V ac LCC 15 BA3 INCM FDR 52-15301 R20-II-R635A 195 0-1200A ac 480 V LCC 15 BA3 R20-EI-R636A 1(5 0-600 V ac DIESEL GENERATOR 11 (DIV. 1)
Volts P75-EI-R600A 180 0-5.25 kV ac Frequency P75-SI-R601A 180 55-65 Hz Amps P75-II-R604A 180 0-1500A ac Field Volt P75-EI-R605A 180 0-300 V de Field Amp P75-II-R606A 180 0-400 A de Watts P75-JI-R602A 180 0-10 MW Vars P75-JI-R603A 180
-10/0/+10 MVAR 125 V de Bus 11DA L21-EI-R603A 180 0-150 V de LCC 16 BB4 INCM FDR 52-16401 R20-II-R627B 185 0-1200A ac 480 V LCC 16 BB4 R20-EI-R628B 185 0-600 V ac LCC 16 BB2 INCM FDR 52-16201 R20-II-R629B 185 0-1200A ac 480 V LCC 16 BB2 R20-EI-R630B 185 0-600 V ac LCC 16 BB6 INCM FDR 52-16601 R20-II-R648B 185 0-1200A ac 480 V LCC 16 BB6 R20-EI-R647B 185 0-600 V ac LCC 16 BBS INCM FDR 52-16501 R20-II-R631B 185 0-1200A ac 480 V LCC 16 BB5 R20-EI-R632B 185 0-600 V ac LCC 16 BB1 INCM FDR 52-16101 R20-II-R633B 185 0-1200A ac 480 V LCC 16 BB1 R20-EI-R634B 185 0-600 V ac LCC 16 BB3 INCM FDR 52-16301 R20-II-R635B 185 0-1200A ac 480 V LCC 16 BB3 R20-EI-R636B 185 0-600 V ac Bus 16 AB INCM FDR 152-1611 R21-II-R613B 185 0-1500A ac 4.16 kV Bus 16 AB R21-EI-R615B 185 0-5.25 kV ac Bus 16 AB INCM FDR 152-1614 R21-II-R617B 185 0-1500A ac Bus 16 AB INCM FDR 152-1601 R21-II-R616B 185 0-1500A ac DIESEL GENERATOR 12 (DIV. 2)
Volts P75-EI-R600B 180 0-5.15 kV ac Frequency P75-SI-R601B 180 55-65 Hz Amps P75-II-R604B 180 0-1500A ac Field Volts P75-EI-R605B 180 0-300 V de Field Amp P75-II-R606B-180 0-400 A de Watts P75-JI-R602B 180 0-10 MW Vars P75-JI-R603B 180
-10/0/+10 MVAR 125 V de Bus 11DB L21-EI-R603B 180 0-150 V de Bus 17AC INCM FDR 152-1704 E22 R622 180 0-1500A ac Bus 17AC INCM FDR 152-1705 E22 R615 180 0-1500A ac Bus 17AC INCM FDR 152-1706 E22 R620 180 0-1500A ac MCC 17B01 INCM FDR 152-1703 E22 R621 180 0-300A ac DIESEL CENERATOR 13 (HPCS, DIV. 3)
Amps E22 R607 180 0-800A ac Vars E22 R608 180
-4/0/+4 MVAR Watts E22 R609 180 0-6000KW ac Bus Voltage E22 R610 180 0-5.25 kV ac 480 V MCC 17B01 Voltage E22 R617 180 0-600 V ac DC Bus Voltage 125 V de E22 R618 180 0-150 V de Bus 11 de t
Page 9 of 18 The indicators listed are either GE Model 180 or Model 185.
The Model 180 indicators were evaluated in accordance with IEEE 323-1974 and IEEE 344-1975 and are qualified to function at least 100 days after, but not during, a safe shutdown earthquake.
The Model 185 indicators were not qualified or required to function after a' safe shutdown earthquake. However, they are qualified not to interrupt the operation of any Class IE device by remaining structurally intact. The power supply for each device is the bus /LCC which that device monitors.
Both Model 180 and 185 indicators were installed under the existing QA program.
ADS Air Receiver Pressure Transmitter Indicator Type Range B21-PT-N201A&B B21-PI-R702 180 0-200 psig The devices are to be implemented by an existing design change package. The devices for measuring and indicating ADS air. receiver pressure will be qualified to 10 CFR 50.49 and IEEE 344-1975, and will be installed under the existing QA program.
There are no individual control room indicators for the standby diesel starting air storage tanks.
Note 28 Instruments for the Detection of Radiation Exposure Rate Low range area monitors are provided at the following locations throughout the plant where radiation could be present.
Instrument Function Range Recorder D21-RE-N001 Radn Det 100t Room A 1-100,000 mR/hr D21-RJR-R600A D21-RE-N002 Rada Det RHR Room B 1-100,000 mR/hr D21-RJR-R600A D21-RE-N003 Rada Det RCIC Room 1-100,000 mR/hr D21-RJR-R600A D21-RE-N004 Rada Det Comp Clg Wtr HX 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N005 Rada Det Tip Mechanism Area 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N006 Rada Det Drwl Equip Hatch 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N007 Rada Det Drwl Pers Airlock 1-100,000 mR/hr D21-RJR-R600A D21-RE-N008 Rada Det Ctat Pers Airlock 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N009 Rada Det Crd Hyd Units North 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N010 Radn Det Crd Hyd Units South 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N011 Rada Det RHR HX A Hatch 1-100,000 mR/hr D21-RJR-R600A D21-RE-N012 Radn Det RHR HX B Hatch 1-100,000 mR/hr D21-RJR-R600A D21-RE-N013 Rada Det SGTS F1tr Train 0.01-1000 mR/hr D21-RJR-R600A
Page 10 of 18 Instrument Function Range Recorder D21-RE-N014 Rada Det CRD Repair Room 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N015 Radn Det Outside CRD Rpr Rm 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N016 Rada Det Aux Bldg Sample Sta 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N017 Rada Det Ctmt Vent Equip Rm 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N018 Radn Det H2 Sample Panel A 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N019 Rada Det H2 Sample Panel B 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N020 Radn Det Ctmt Vent Fltr Tn 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N021 Radn Det Ctmt Sample Sta 0.1-10,000 mR/hr D21-RJR-R600A D21-RE-N022 Radn Det Fuel Handling Area 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N023 Rada Det Fuel Handling Area 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N024 Rada Det Fuel Handling Area 0.01-1000 mR/hr D21-RJR-R600A D21-RE-N025 Radn Det Fuel Handling Area 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N026 Rada Det Dryer Storage Area 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N027 Rada Det Sep Storage Area 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N028 Rada Det Ctmt Fuel Area N 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N029 Rada Det Ctmt Fuel Area S 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N030 Radn Det Ctmt Pers Airlock 0.01-1000 mR/hr D21-RJR-R600B D21-RE-NO31 Rada Det Turb Bldg Filtr Tn 0.1-10,000 mR/hr D21-RJR-R600B D21-RE-NO32 Rada Det Turb Bldg Smpl Sta 0.1-10,000 mR/hr D21-RJR-R600B D21-RE-N033 Rada Det Mech Vac Pump Area 0.1-10,000 mR/hr D21-RJR-R600B D21-RE-N034 Rada Det Turb Bldg Inst Rack 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N035 Rada Det RX Feed Pump Area 1-100,000 mR/hr D21-RJR-R600B D21-RE-N036 Rada Det Turb Bldg Oper F1 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N037 Rada Det Turb Bldg Oper F1 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N038 Rada Det Turb Bldg Oper F1 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N039 Rada Det Turb Bldg Oper F1 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N040 Radn Det Rmt Shutdown Area 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N041 Rada Det Hot Machine Shop 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N042 Rada Det Rad Bldg Inst Rack 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N043 Rada Det Rad Bldg Sample Sta 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N044 Rada Det Rad Bldg Contr Sta 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N045 Rada Det Dist1t Smpl Tk Rm 0.01-1000 mR/hr D21-RJR-R600B D21-RE-N046 Rada Det Rad Bldg HVAC Room 0.1-10,000 mR/hr D21-RJR-R600B D21-RE-N047 Rada Det Solid Radwaste Area 1-100,000 mR/hr D21-RJR-R600B D21-RE-N049 Radn Det Tech Support Center 0.01-1000 mR/hr D21-RJR-R600C D21-RE-N050 Rada Det Post ACC Smpl Area 1-100,000 mR/hr D21-RJR-R600C D21-RE-N600 Rada Det Control Room 0.01-1000 mR/hr D21-RJR-R600B Note 29 This device does not constitute a part of a safety system.
Therefore seismic qualification is not required since it is Category 2.
Page 11 of 18 Note 30 Noble Gases and Vent Flow Rate Power Supply Racge All non-UPS Location and Function Instrument pCi/cc (unless noted)
I.
FUEL HANDLING AREA A.
Eberline SPING 1.
Low Range Noble D17-RE-N130 10-7-6x10-2 Non-1E Gas (NG) 2.
Mid-Range NG D17-RE-N131 2x10-2_4xio2 Non-1E B.
GE Sample Panel Log Ccunt Rate D17-RITS-K619 1.92x10-6 Non-1E Meter (LCRM) to 7.69x10-2 UPS C.
Eberline AXM.
1.
Mid-Range D17-RE-N132 10-4-101 Non-1E Accident NG 10 -105 Non-1E 1
2.
High Range D17-RE-N133 Accident NG II. ~ STANDBY GAS TREATMENT B A.
Eberline SPING 1.
Low Range NG D17-RE-N142 10-7-6x10-2 1E (15B41) 2.
Mid-Range NG D17-RE-N143 2x10-2-4x102 IE (15B41)
B.
Eberline AXM.
1.
Mid-Range D17-RE-N144 10-4-101 1E (15B41)
Accident NG 10 -105 IE (15B41) 1 2.
High Range D17-RE-N145 Accident NG III. STANDPY GAS TREATMENT A A.
Eberline SPING 1.
Low Range NG D17-RE-N148 10-7-6x10-2 1E (15B41) 2.
Mid-Range NG D17-RE-N149 2x10-2-4x102 1E (15B41)
B.
Eberline AXM.
1.
Mid-Range D17-RE-N150 10-4-101 1E (15B41)
Accident NG 10 -105 1E (15B41) 1 2.
High Range D17-RE-N151 Accident NG J
r Page 12 of 18 IV.
CONTAINMENT AREA A.
Eberline SPING 1.
Low Range NG D17-RE-N124 10-7-6x10-2 Non-1E 2.
Mid-Range NG D17-RE-N125 2x10-2-4x102 Non-1E B.
GE Sample Panel LCRM D17-RITS-K603 1.92 x 10-8 Non-1E 7.69 x 10-2 C.
Eberline AXM.
1.
Mid-Range D17-RE-N126 10~4-101 Non-1E Accident NG 1
5 2.
High Range D17-RE-N127 10 -10 Non-1E Accident NG V.
STACK FLOW INSTRUMENTS Fuel Handling Area D17-FT-N200C 0-35360 cfm Non-1E Standby Gas Treatment B D17-FT-N200F 0-4300 cfm 1E (15B41)
Standby Gas Treatment A D17-FT-N200E 0-4300 cfm 1E (15B41)
Containment Vent D17-FT-N200B 0-6000 cfm Non-1E Note 31 The Eberline microprocessor-controlled noble gas,. particulate, and iodine monitors will give an alarm and print out the parameters for the alarming station continuously. Post accident or any station information may be " called up" on the control room terminal at any time. The General Electric noble gas monitor channels are continuously recorded in the control room on the following recorders:
Containment, Off Gas and Radwaste Building Vents - D17-RR-R600 Turbine Building, Fuel Handling Area Vents - D17-RR-R607 These indicators / recorders will only be used to determine the noble gas activities released. To determine the iodine and particulate release activities, personnel will be required to remove the iodine / particulate filters from either the Eberline SPING, GE Sample Panel, Eberline AXM grab sample pallet or, for the standby gas treatment systems, from the alternate sample station on auxiliary building 139' elevation.
Note 32 The containment purge, fuel handling area ventilation, and standby gas treatment systems can be monitored by either a non-1E microprocessor-based system with on-demand callup and recording available in the control room, or a General
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Page 13 of 18 Electric-supplied sample panel with recording available (except SGTS A and B).
The present system uses two separate sections to monitor the full range required by the Regulatory Guide. The AMC FM&IS panel controls sample flow to the Eberline SPING 4 detection system (for a range 10-7 to 4 x 102 pCi/cc), or the GE Sample Panel, which has an installed sample pump and manual sample flow rate control (for a range 1.97 x 10-6 to 10-2 pCi/cc, except SGTS A and B).
The Eberline AXM Panel, with its installed vacuum pump, draws and analyzes a sample from the ventilation duct.
(Note that this sample method meets the requirements of ANSI N13.1 at one ventilation flow rate only.) The sample results (vent flow rates for determining concentrations are provided by the AMC FM&IS panel via the SPING 4 microprocessor) are transmitted to the control room via the data acquisition module (range 10-4 to 105 pCi/cc).
It has been determined (Reference Mechanical Calc. 5.6.9.-N) that for post-LOCA
. conditions the release rate through the standby gas treatment system will be 21 x 10-3 pCi/cc and release rate through the containment and fuel handling area vent systems will be 21 x 10-2 pCi/cc prior to system isolation.
Based on these release rates, it is not necessary to place Category 2 requirements on any low range instruments.
The present power supplies to the accident range monitors are as reliable as the power supplies for the ventilation systems which they monitor.
Note 33 Noble Gases and Vent Flow Rate Power Supply Range All non-UPS Location and Function Instrument pCi/cc (unless noted)
I.
OFFGAS AND RADWASTE VENT A.
Eberline SPING 1.
Low Range Noble D17-RE-N118 10-7 -6 x 10-2 Non-1E Gas (NG) 2.
Mid-Range NG D17-RE-N119 2 x 10-2 -4 x 102 Non-1E B.
GE Sample Panel LCRM D17-RITS-K602 1.92 x 10-6 Non-1E 7.69 x 10-2 UPS
Page 14 of 18 C.
Eberline AXM.
1.
Mid-Range D17-RE-N120 10-4 -101 Non-1E Accident 2.
High Range D17-RE-N121 101 -105 Non-1E Accident II.
TURBINE BUILDING VENT A.
Eberline SPING 1
Low Range NG D17-RE-N136 10-7-6x10-2 Non-1E Mid-Range NG D17-RE-N137 2x10-2-4x102 Non-1E B.
GE Sample Panel LCRM D17-RITS-K620 1.92 x 10-8 Non-1E 7.69 x 10-2 pp3 C.
Eberline AXM.
1.
Mid-Range D17-RE-N138 10-4-101 Non-1E Accident NG 10 -10s Non-1E 1
2.
High Range D17-RE-N139 Accident NG III. STACK FLOW INSTRUMENTS Offgas and Radwaste D17-FT-N200A 0-53,600 cfm Non-1E Turbine Bldg D17-FT-N200D 0-11,550 cfm Non-1E Note.34 The Turbine Building and Radwaste Building ventilation systems are presently monitored by a non-1E microprocessor-based system with on-demand callup and recording available in the control room, or a General Electric-supplied Sample Panel with recording available. The present system uses two separate sections to monitor the full range required by the Regulatory Guide. The AMC FM&IS panel controls sample flow to the Eberline SPING 4 detection system, which transmits its information to the control room (for a range 10-7 to 4 x 102 pCi/cc), or the GE Sample Panel, which has aninstalledsamplepumpandmanualsamgleflowrate control (for a range 1.97 x 10-8 to 10-pCi/cc).
l The Eberline AXM Panel, with its installed vacuum pump, draws and analyzes a sample from the ventilation duct.
l (Note that this sample method meets the requirements of ANSI N13.1 at one ventilation flow rate only.) The sample results (vent flow rates for determining concentrations are l
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O Page 15 of 18 provided by the AMC FM&IS panel via the SPING 4 microprocessor) are transmitted to the control room via the data acquisition module (range 10-4 to 105 pCi/cc).
For the Turbine Building and Radwaste Building, there are no postulated events which will cause a harsh environment.
Therefore, no changes to these monitors are required.
Note 35 Iodine and Particulate Power Supply Range All non-UPS Location and Function
-Instrument pCi/cc (unless noted)
I.
FUEL HANDLING AREA A.
Eberline SPING Particulate D17-RE-N128 8.43 x 10-5 Non-1E*
to 8.43 Iodine D17-RE-N129 1.89 x 10-4 Non-1E*
to 18.9 B.
AMC FM&IS Stack Flow D17-RE-N200C 0-35360 cfm Non-1E II.
STANDBY GAS TREATMENT B A.
Eberline SPING Particulate D17-RE-N140 8.43 x 10~5 IE (15B41)*
to 8.43 Iodine D17-RE-N141 1.89 x 10-4 IE (15B41)*
to 18.9 B.
AMC FM&IS Stack Flow D17-FT-N200F 0-4300 cfm 1E (15B41)
III. STANDBY GAS TREATMENT A A.
Eberline SPING Particulate D17-RE-N146 8.43 x 10-5 IE (lab 41)*
to 8.43 Iodine D17-RE-N147 1.89 x 10-4 IE (15B41)*
to 18.9
Page 16 of 18 B.
AMC FM&IS Stack Flow D17-FT-N200E 0-4300 cfm 1E (15B41)
IV.
CONTAINMENT AREA A.
Eberline SPING Particulate D17-RE-N122 8.43 x 10-5 Non-1E*
to 8.43 Iodine D17-RE-N123 1.89 x 10-4 Non-1E*
to 18.9 B.
AMC FM&IS Stack Flow D17-FT-N200B 0-6000 cfm Non-1E V.
OFFGAS AND RADWASTE VENT A.
Eberline SPING Particulate D17-RE-N116 8.43 x 10-5 Non-1E*
to 8.43 Iodine D17-RE-N117 1.89 x 10-4 Non-1E*
to 18.9 B.
AMC FM&IS Stack Flow D17-FT-N200A 0-53600 cfm Non-1E VI. TURBINE BUILDING VENT A.
Eberline SPING Particulate D17-RE-N174 8.43 x 10-5 Non-1E*
to 8.43 Iodine D17-RE-N135 1.89 x 10-4 Non-1E*
to 18.9 B.
AMC FM&IS Stack Flow D17-FT-N200D 0-11,550 cfm Non-1E
- These installed monitoring instruments will be used for problem detection. Actual release rates will be determined by removing the collection filter, from either the GE, SPING sampler, or AXM and counting these filters in the onsite High Purity Intrinsic Germanium SpectroscogySystem(multichannelanalyzer)whichhasarangeof 10-3 to 10 pCi/cc.
Page 17 of 18 Note 36 Four Radeco Model H809C air samplers are provided for field sampling with charcoal filters. The onsite analysis capability includes three multi-channel analyzers, two in cold lab and one in hot lab, (Nuclear Data #66 and Ortec
- 7054).
Note 37 Four Eberline R0-7 dose rate meters (ImR/hr - 20,000 R/hr) and three Ludlum Model 125 micro ratemeters are provided for environmental monitoring.
Note 38 1 Nuclear #256D portable multi-channel analyzer is available to the field monitor teams.
Note 39 Instrumentation exists to measure wind direction from 0 to 540* at 33 feet and 162 feet.
Accuracy is 13* with a starting threshold of 0.7 mph, distance constant of 1.1 meters, and a dampening ratio of 0.4 at 10*.
Note 40 Meteorological information is available in the control room either from the B0P computer or the met tower console.
Both primary and backup instruments are available for meteorological parameters.
Note 41 Instrumentation exists to measure wind speed from 0 to 90 mph at 33 feet and 162 feet. Accuracy is 1.0% and the starting threshold is 0.63 mph.
Note 42 Instrumentation exists to measure vertical temperature difference from -10 F to +20 F.
Accuracy is 1.0 percent of delta temperature, or 0.1*F.
Note 43 The post-accident sampling station is installed on the 93-foot elevation of the turbine building and allows for performing the following grab samples:
Containment atmosphere Drywell atmosphere Reactor recirc loop B Jet pump flow line D RHR loop A and B Suppression pool
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Page 18 of 18 The post-accident sampling system allows the following on-line analysis for the above samples:
Cloride Conductivity pH Liquid samples Dissolved 02 H2 Gross activity Gamma spectrum All samples Isotopic analysis Note 44 This analysis will be performed using a gas chromatograph and will have an effective range of 0-100 percent volume for hydrogen, oxygen, nitrogen, and trace gases. The sample for this analysis is drawn from the post-accident sample system discussed in Note 43.
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Page 1 of 16 GGNS REGULATORY GUIDE 1.97 (REVISION 2)
POSITION STATEMENTS Position 1 Reactor Pressure Vessel Level Table 1 of Regulatory Guide 1.97 requires a range extending from the bottom of the core support plate to the centerline of the main steam line. To comply with this requirement, MP&L will use two Fuel Zone, two normal Wide Range, and two Shutdown Range instruments.
Because of the range of monitoring required for the operator to take action in accordance with the Emergency Procedures and the fact that only the wide range RPV level instruments meet the requirements of Category 1, the following changes will be provided for indication over the full RPV level range required by Regulatory Guide 1.97.
1)
Replace the fuel zone and shutdown range level instruments with instruments which are qualified to 10 CFR 50.49 and IEEE 344-1975.
2)
Replace the fuel zone and shutdown range signal and power cables with Class IE cables and upgrade the power supplies to Class 1E, e
UPS.
3)
Replace the present fuel zone and shutdown range recorders with Class 1E two-pen recorders that are redundant and electrically separated.
4)
All above items will be provided with two divisions.
This will provide two divisions of fully qualified and redundant level indication over the full range required by Regulatory Guide 1.97, except for the Shutdown Range instruments.
The two divisions of Shutdown Range instruments will share a reference leg, drywell sensing lines and drywell penetrations. This reference leg utilizes the top head vent as an RPV penetration.
In order to fully meet the single failure criterion of Section 1.3.1.b of Regulatory Guide 1.97, an additional head penetration would be needed to provide a redundant reference column for the second Shutdown Range instrument. However, because of the following considerations, shutdown range will be designed to meet Type B with full Category 2 requirements excluding the addition of a redundant reference column.
1)
Of the total range required by Regulatory Guide 1.97 (434.7") the Shutdown Range instruments are only used for the upper 58".
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Page 2 of 16 2)
The only operator action (as identified by the BWR EPG) associated with the Shutdown Range is increasing RPV level to the main steam line outlet for alternate shutdown cooling.
3)
Only a break of the reference leg or sensing line would prevent at least one division of the Shutdown Range instruments from being available.
In this case, RPV pressure and SRV pressure or tempera-ture indication could be used to determine if RPV level is at or above the main steam outlet.
4)
The addition of another RPV and drywell penetration would be ex-tremely difficult and costly for the marginal improvement in plant safety that would be realized.
Therefore, it is MP&L's position that implementation of the proposed water level instrumentation (without the addition of a redundant Shutdown Range reference leg) will meet the intent of Regulatory Guide 1.97, Category I requirements for this variable.
Position-2 Reactor Pressure Vessel Pressure MP&L will provide Class IE uninterruptible power to the reactor pressure vessel pressure instruments. This will ensure that a record of any pressure changes is available for accident evaluation. After this change is implemented, these instruments will meet the requirements of Reg.
Guide 1.97.
Position 3 Drywell Atmosphere Temperature The FSAR analysis of the main steam line break accident shows that drywell atmospheric temperature peaks between 1 and 2 seconds after the accident. Therefore, to ensure that the capability to monitor this variable is maintained (i.e., recorded) for accident evaluation, the power supplies for these devices will be upgraded to Class lE, UPS. The present GGNS drywell atmospheric temperature monitored range is 0 to 400 F.
The maximum calculated post LOCA drywell temperature is 330 F.
All automatic and manual actions occur at less than or equal to 85 percent of full scale for the present instrument range. No additional margin in the monitored range is considered necessary.
It is MP&L's position that the present instrument range adequately moni-tors drywell atmospheric temperature and will meet the intent of Regulatory Guide 1.97.
Position 4 Suppression Pool Water Temperature The power supply for Category 1 devices is required by Regulatory Guide 1.32 to be, " Station Standby Power and should be backed up by batteries where momentary interruption is not tolerable." The present GGNS normal power supply is RPS with manual switching to standby power through non-Class IE
m--
e Page 3 of 16 control circuits. Because this power supply does not meet the requirements of Regulatory Guide 1.97 Category 1, upgrading the power supply to Class 1E power is required. Because suppression pool temperature is relatively constant (Reference FSAR Figures 6.2-3 and 6.2-11, for wetwell temperature) over the time' period that Class IE standby power would not be available (~10 sec), uninterruptible pcwer is not necessary. MP&L will-change the power supply to the suppression pool water temperature monitoring devices from RPS to Class 1E standby power. With the implemen-
'tation of Class IE standby power, this variable will meet the requirements of Reg. Guide 1.97.
Position 5 Suppression Pool Water Level The present range of the suppression pool level measurement is in compli-ance with Regulatory Guide 1.97 except at the lower end, which measures only to the centerline of the ECCS suction line rather than the bottom as required by the regulatory guide. However, lack of capability to monitor level to the bottom of the suction line does not preclude any safety system from perfonning its intended function.
In addition, indication of level at the lower end of the scale is not required for any further manual safety action by the operator. The suppression pool level instru-mentation therefore meets the intent of Regulatory Guide 1.97.
-Position 6 Drywell and Containment Hydrogen Concentration Emergency procedure guidelines are being' developed for containment hydrogen control. GGNS procedures developed from these guidelines will not require operator action for hydrogen control at hydrogen levels in
~..
excess of 10%. This.is based on the development'of the hydrogen deflagration overpressure limit, the maximum hydrogen concentratior. in which operator action will be required by the hydrogen control procedure.
~
MP&L has installed a hydrogen ignition system for containment hydrogen control. The 1/20th scale test performed for the hydrogen control issue has shown that the hydrogen burn (caused by hydrogen igniters) will occur at hydrogen levels of 6%. Since the hydrogen igniter system is redundant,
-Class IE, and turned on prior to hydrogen generation, homogeneous hydrogen levels greater'than 6% should not occur. Therefore, the existing. range for hydrogen monitoring (0-10%) meets the intent of the' Reg. Guide 1.97.
Position 7 Neutron Flux
..The only GGNS Emergency Procedure that requires operator action for
-neutron flux level is based on an ATWS event. The post ATWS drywell environment is very similar to the normal operating drywell environment and the drive mechanisms are designed to withstand normal. environments.
Additionally, the critical safety function of reactivity control for design basis accidents is performed by redundant, Class 1E automatic 3 -
devices - no operator 1 action is required. Although for unpostulated events such as ATWS, operator action may be required, the equipment operating environment is very similar to the normal operating environment.
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Page 4 of 16 Equipment used for mitigation of ATWS events function as a backup to safety devices used for design basis accident mitigation.
The ATWS Final Rule does not require Class IE power for ATWS equipment; however, it does require a power supply independent from the Reactor Trip System that is uninterruptible and available following a loss of offsite power.
Even though MP&L considers neutron monitoring to be a Type B variable for operator action for an ATWS event, MP&L will pursue the implementation of Category 1 instrumentation. To date, MP&L believes that no neutron monitoring system has been fully qualified to meet the Category 1 require-ments. However, MP&L will continue to follow industry development in this area and will either implement a system in the future that will comply to the Category I requirements or MP&L will upgrade the present system to provide the necessary reliability based on the GGNS specific design requirements.
Position 8 Group 1 Isolation Redundant valve position indication is not provided for each valve.
However, the requirement is met by the valves themselves.
MP&L will provide Class IE power to the position switches for the Group 1 Isolation valves (B21-F022 and F028). When this change is implemented, this instrumentation will meet the intent of Reg. Guide 1.97.
Position 9 BWR Core Thermocouples Supplement 1 to NUREG-0737 states that "BWR incore thermocouples...are not required pending further development and consideration as require-ments." Additionally, in generic letter 84-23 the NRC has stated that water level instrumentation in a BWR is relied upon for providing the operators with information which is used as a basis for actions to ensure adequate core cooling. Based on these items and our previous responses to Generic Letter 84-23 (AECM 84/0521), it is MP&L's position that Grand Gulf's reactor vessel water level instrumentation, as discussed in
[
Position 1, provides reliable information to monitor core cooling.
Therefore, the addition of in-core thermocouples is neither justified nor I
required.
Position 10 Drywell Sump Level The GGNS BWR Nark III drywell has two drain sumps. These drain sumps are the equipment drain sump, which collect identified leakage, and the floor drain sump, which collects unidentified leakage.
These drywell sumps are low volume (~460 gals each) and their level l-instruments are designed to identify small leaks.
The drywell leakage monitoring system is designed in accordance with Regulatory Guide 1.45 i
(Ref. FSAR Section 7.6.2.4.2.1).
Sump level detection is only one of the l
Page[.iof16 methods used to determine leakage from the reactor coolant system. The following are other methods of monitoring to determine leakage:
A.
Fission product monitoring 2)
Air cooler condensate monitoring 3)
Drywell air temperature monitoring, Class 1E 4)
Drywell pressure monitoring, Class 1E B.
Identified Leakage 1)
Recirculation pump seal monitoring 2)
Reactor vessel head seal monitoring 3)
Safety relief valve exhaust temperature monitoring The Grand Gulf Emergency Operating Procedares do not require any operator action based on sump level. The level of the sumps can be a direct indication of a small breach of the reactor coolant system boundary, but it provides no safety function for containment cooling or pressure control. Regulatory Guide 1.97 requires that Category 1 instruments function after an accident and provide the most direct indication of the =
accomplishment of a safety function. However, the drywell sump systems are deliberately isolated at the primary-containment penetration upon receipt of a LOCA isolation signal to establish isolation and maintain containment integrity. Once the sumps are isolated and full, they can not provide any further information which could be useful for accident mitigation or long term surveillance. The existing sump level instru-mentation is capable of functioning up to the point of sump isolation' due to a LOCA signal.
Therefore,' it is MP&L's. position that the presently installed Category 3 instrumentation for the Equipment and Floor Drain sump levels is adequate
}
and meets the intent of Reg. Guide 1.97.
Position 11 Primary Containment Valve Position Indication The automatic primary containment isolation valves are redundant Class 1E and are actuated by redundant Class 1E signals.
Inboard and outboard isolation valve position switches are electrically separated and powered
-from.different divisions.
It is MP&L's position that redundant valve position indication is not required for these valves and that the in-strumentation, with the modifications implemented as described above and in Position 8, will meet the intent of Regulatory Guide 1.97.-
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Page 6 of 16 Position 12 Radiation Concentration in Circulating Primary Coolant The purpose for monitoring this variable is given as " detection of breach," referring, in this case, to breach of fuel cladding. Monitoring the active coolant (or a sample thereof) is the dominant consideration to deterwine fuel element failure.
Th-Post-Accident Sampling System (PASS) provides a representative sample of the circulating reactor coolant.
The subject of concern in the Regulatory Guide 1.97 requirement is assumed to be an isolated NSSS that is shutdown. This assumption is justified because current radiation monitors in the condenser off-gas and main steam lines provide reliable and accurate information on the status of fuel cladding when the plant is not isolated.
Further, PASS will provide an accurate status of coolant radioactivity, and hence cladding status, once it is activated.
In the interim between NSSS isolation and operation of the PASS, the drywell and containment radiation monitors, drywell containment hydrogen monitors, condenser off-gas radiation monitors and main steamline radiation monitors will provide information on the status of the fuel cladding.
The usefulness of the information obtained by monitoring the radioactivi-ty concentration or radiation level in the circulating primary coolant, in terms of helping the operator in his efforts to prevent and mitigate accidents, has not been substantiated. The critical actions that must be taken, per the GGNS EP's and the BWROG EPG's, to prevent and mitigate a gross breach of fuel cladding are (1) shut down the reactor and (2) maintain water level. Monitoring, as directed in Regulatory Guide 1.97, will have no influence on either of these actions. The purpose of this monitor falls in the category of "information that the barriers to release of radioactive material are being challenged" and " identification of degraded conditions and their magnitude, so the operator can take actions that are available to mitigate the consequences."
Because no planned operator actions are identified and no operator actions are anticipated based on this variable, MP&L will retain this variable as Category 3 using the present PASS.
It is our position that this meets the intent of Reg. Guide 1.97.
Position 13 Radiation exposure rate inside buildings or areas that are in direct contact with primary containment where penetrations and hatches are located The use of local radiation exposure rate monitors to detect breach or leakage through primary containment penetrations is not necessary.
In ger.eral, radiation exposure rate in the secondary containment will be a function of radioactivity in primary containment and in the fluids flow-ing in ECCS piping, which will cause direct radiation shine on the area monitors. Because of the amount of piping and the number of electrical penetrations and hatches and their widely scattered locations, local rad-iation exposure rate monitors could give ambiguous indications. A more
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Page 7 of 16 appropriate means to detect breach of containment is by using the plant noble gas effluent monitors as discussed in Item 7E.
I' Based on the foregoing, monitoring of this variable will not be implemented.
Position 14 Condensate Storage Tank Level The existing C.S.T. level instrumentation monitors levels from 6i inches below the ECCS suction transfer point to the top of the tank. The level below the ECCS suction transfer point is not usable as an ECCS water source post-accident. It is MP&L's position that the instrumentation for this variable measures the full post-accident usable water level and, therefore, meets the intent of Regulatory Guide 1.97.
Position '15 Containment Spray and Low Pressure Coolant Injection Flow Rate GGNS has existing instruments which monitor total RHR system flow and meet Category 2 requirements. The same instruments on each RHR loop monitor the following variables:
1)
Containment spray flow (RHR A&B) i
'2)
Low pressure coolant injection flow (RHR A&B) 3)
Residual heat removal loop flows (RHR A, B&C), for other operation-modes.
Simultaneous operation of the various modes is prevented either by design
'(in the automatic mode) or by plant operations procedures (in the manual mode). Valve position indications meeting the' requirements of Category 2 are used by the operator to determine the system operations mode. There
- are also indirect Category 1 indications that can be used to determine the proper operation of the system in the desired mode (i.e., containment pressure and temperature to evaluate containment spray, and RPV level and pressure to evaluate LPCI),
i It is MP&L's position that the existing instrumentation, which measures l
RHR system flow, provides adequate indication of containment spray flow and LPCI flow to meet the requirements of Regulatory Guide 1.97.
Position 16 Standby Liquid Control System Flow The GGNS Standby Liquid Control System (SLCS) consists of the following major components: a storage tank with an electric heating system and sparger, a test tank, two 100-percent-capacity injection pumps (43 gpm each), two 100-percent-capacity injection valves, and associated piping instruments and valves.
The SLCS is manually initiated from the main control room panel by two keylocked on/off switches. Operation of either switch will start one pump, open the squib and storage tank outlet valves, and close the reactor water cleanup isolation valves. The SLCS storage tank pumps,
i Page 8 of 16 squib valves, tank outlet valves, and hand switches are all Seismic Category 1.
GGNS = has the following existing indications of SLCS operation in the con-trol room.
1)
Squib valve position, Seismic Category 1
- 2).SLCS tank outlet valve position, Seismic Category 1 3)
' Storage tank level 4)
Pump running lights
.It is NP&L's position that this instrumentation, along with reactivity change indicated by monitoring neutron flux, provides an adequate alter-native to monitoring SLCS flow. Therefore, it is MP&L's position that the existing SLCS instrumentation described above meets the intent of Reg. Guide 1.97.
Position 17 Standby Liquid Control System Tank Level The SLCS storage tank level is monitored by a nonqualified level trans-mitter and an indicator. These instruments monitor a level between O' 6-1/8" to 11'-1/8" (0-5000 gals). The bottom of the tank is considered to be 2-1/2" above the centerline of the tank outlet. This corresponds to a tank level of O' 6-1/8".
5150 gallons (tank overflow volume) is considered to be the top of the tank. This corresponds to a tank level of 11' 4".
The current design basis for SLCS assumes a need for an alternative method of reactivity control without a concurrent loss of coolant acci-dent or high energy line break. This design basis also recognizes that SLCS performs as a backup system to the reactor protective system or
~
other engineered safety systems.
Additionally, the ATWS final rule (10 CFR 50.62) requires environmental r
qualification for anticipated ' operational occurrences only, not for accident scenarios, and it does not require seismic qualification. MP&L i
will recalibrate the existing level transmitter to monitor a range of 0 to 5150 gallons. MP&L will also evaluate the need to install an accumulator system as a backup source of instrument air for the SLCS tank level instrumentation.
It is MP&L's position that with these changes accomplished, the instru-mentation will meet the intent of Regulatory Guide 1.97.
l Position 18 RHR Heat Exchanger Outlet Temperature This device was previously exempted from the NUREG-0588 program because j -
it does not perform a safety function. However, due to the Reg. Guide 1.97 l
Category'2 requirements for post accident monitors, MP&L will either replace or provide qualification documentation for the RHR heat exchanger I
outlet temperature instrumentation. After this change is implemented, I
'this instrumentation will meet the Category 2 requirements of Reg.
l Guide'1.97.
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Page 9 of 16 Position 19 Cooling Water Temperature to ESF System Components MP&L interprets this variable as main system flow. The present system consists of dual element thermocouples which provide inputs to both the BOP computer and a recorder. Because this instrumentation does not perform any essential safety function, seismic qualification is not required. Also, all parts of the instrument loops are in mild environ-mental areas, and presently exempt from environmental qualification.
Therefore, it is MP&L's position that the presently installed instrumen-tation meets the Regulatory Guide 1.97, Category 2 requirements.
Position 20 Status of Standby Power and Other Energy Sources Important to Safety (hydraulic, pneumatic)
The variables for GGNS that provide status of standby power and other energy sources are separately addressed as follows:
ADS Air Receiver and Accumulator Pressure The capability to monitor this variable in the control room with instru-
=entation which meets Category 2 requirements is being implemented in accordance with Licensing Condition 2.C.(33)(g).
Starting Air Pressure for the Standby Diesel Generators The presently installed equipment does not provide control room indica-tion to monitor starting air pressure. However, local indication which meets the requirements of Category 3 is provided along with local alarm capability that inputs to a common trouble alarm in the control room.
Investigation by plant operations personnel is required when this common trouble alarm is actuated. The addition of a separate alarm or indica-tion could possibly confuse the control room operator with multiple diagnostic indications and would not preclude the required operational investigation.
Rather than being a key variable, it is a backup variable in accordance with Regulatory Guide 1.97, Section B; Type D and E backup variables are Category 3.
MP&L's position is that the present Category 3 instru-mentation provides adequate information to monitor system status.
Starting Air Pressure for the HPCS Diesel Generators Local indication and alarrs are provided with instrumentation which meets Category 3 requirements but no control room indication is provided.
Starting air storage tanks are monitored locally by redundant pressure indicators and switches. These pressure switches control the electric and diesel driven air compressors for the HPCS starting air. This provides sufficient assurance of starting air availability.
r Page 10 of 16 Rather than being a key variable, it is a backup variable in accordance with the Regulatory Guide 1.97, Section B; Type D and E backup variables are Category 3.
MP&L's position is that the present Category 3 instru-mentation provides adequate information to monitor system status.
HPCS Standby Power, Voltage, Current and Frequency The parameters requiring instrumentation to monitor the status of the HPCS Standby Power Supply are voltage and current at the 4.16 kV bus.
Additional indication of the operability of the power supply is obtained from readings of the 4.16 kV bus frequency and the voltage on the Divi-sion III de system.
Should the normal control room indication of bus voltage be lost, the same voltage can be monitored in the control room using the synchronizing circuits.
The normal current monitoring in the control room is accomplished using the HPCS diesel generator ammeter. Since there are only two feeder breakers supplied by the HPCS power supply, each of which is equipped with local ammeters, the total current supplied by the diesel generator could be obtained by summing these two readings should the normal indica-tion fail.
Control room indication of diesel generator frequency is normally provid-ed by the HPCS diesel generator frequency meter. Should this instrument be unavailable, the reading is displayed on the bus frequency meter when the generator is supplying bus 17AC.
The voltage of the Division III de bus is displayed in the control room by the bus voltmeter and by an independent meter local to the bus.
Therefore, due to the backup capability to monitor system status, the presently installed Category 3 instrumentation meets the intent of Regulatory Guide 1.97.
DC Power Voltage and Current The existing Crand Gulf design provides instruments in the control room to monitor the Class IE de power systems and voltage which meet Category 2 requirements.
The following information describes the monitoring capability of the CGNS de power supply as discussed in SER, Section 8.3.2.
The de systems for each unit consist of two 125-volt, one 250-volt and two 24-volt non-Class IE battery systems, and three independent and redundant Class IE 125-volt battery systems. Each of the three Class IE 125-volt power subsystems provides the control power for
Page 11 of 16 its associated Class 1E ac power load group channel; 4.16 kV switch-gear, and 480-volt load centers. Also these de subsystems provide de power to the engineered safety feature valve actuation, plant alarm and indication circuits, and emergency lighting system, and the de cc.ntrol power for each diesel generator. Loss of any one of the de subsystems does not prevent the minimum safety function from being performed. Loss of de power to the diesel generator is indicated on annunciators in the main control room. Each system is located in an area separated physically and electrically from other systems to ensure that a single failure in one train does not cause failure in the redundant train. All the essential components of Class IE 125-volt de systems are housed in Seismic Category 1 structures. There is no sharing between redundant Class IE trains of equipment such as batteries, battery chargers, or distribution panels.
The specific requirements for de power systems monitoring derive from recommendations embodied in Section 5.3.2(4), 5.3.3(5) and 6.3.4(5) of IEEE Std. 308-1974, and guidelines in Regulatory Guide 1.47.
In summary, these general recommendations and guidelines simply state that the de system (batteries, distribution systems, and chargers) shall be monitored to the extent that it is shown to be ready to perform its intended function. According to the guide-lines used in the licensing review of the de power system designs, the following indications and alarms of the Class IE de power system status should be provided in the control room:
Battery current (ammeter-charge / discharge)
Battery charger output current (ammeter)
DC bus voltage (voltmeter)
Battery charger output voltage (voltmeter)
Battery high discharge rate alarm DC bus undervoltage and overvoltage alarm DC bus ground alarm (for ungrounded system)
Battery breaker (s) or fuse (s) open alarm Battery charger output breaker (s) or fuse (s) open alarm Battery charger trouble alarm (one alarm for a number of abnormal conditions which are usually indicated locally)
The monitoring instruments and alarms called for in the above-cited guideline have been provided in the Grand Gulf control room, except as justified below.
Battery Current (ammeter-charge / discharge)
Since the purpose of this " Battery Current" indication is to deter-mine the battery condition, the method of accomplishing this purpose should not be a minimum requirement. For the Class IE batteries, Grand Gulf has a battery monitoring device which is like an extreme-ly sensitive undervoltage relay. This device compares half of the
e Page 12 of 16 battery cells to the other half to determine if there is a voltage imbalance greater than 2%.
If differences are detected, the general trouble alarm is activated and an operator is dispatched to correct the situation.
Battery Charger Output Current (ammeter)
This ammeter is located on the front of the charger panel where it provides useful information to maintenance or service personnel.
Battery charger output current is not required in the main control room since any current deviations of significance would result in the charger undervoltage or overvoltage alarm which are in the control room.
Battery Charger Output Voltage (voltmeter)
Instead of a voltmeter on the charger output, a voltmeter is provid-ed for the de bus in addition to overvoltage and undervoltage alarms provided for the battery chargers.
Battery High Discharge Rate Alarm The high discharge rate can only occur if there is an undervoltage on the de bus or a ground fault between the bus and the battery.
Since both of these two conditions are alarmed, the addition of this high discharge rate alarm is not required.
Based on the NRC's previously documented review, evaluation, and imposed requirements, the Class 1E de power system has been determined to be acceptable. It is MP&L position that the existing CGNS instrumentation meets the intent of Reg. Guide 1.97 requirements.
Position 21 Radiation exposure rate inside buildings or areas where access is required to service equipment important to safety Regulatory Guide 1.97, Revision 2, requires monitoring of this variable for the following reasons:
1)
Detection of significant releases i
2)
Release assessment 3)
Long term surveillance In general, radiation exposure rate in the secondary containment will be largely a function of radioactivity in the primary containment and fluids flowing in ECCS piping. This will cause direct radiation shine on the area monitors. Because of the radiation shine, local exposure rate monitors could give ambiguous indication of release assessments.
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Page 13 of 16 To prevent false indications of radionuclide release, the GGNS release assessments will be based on the data accumulated by removing the sample filters installed in either the Eberline SPING, AXM Grab Sample Pallet, or GE Sample Panel. These filters will be transported to the chemistry lab where they will be " counted", after some decay period, using high purity intrinsic germanium spectrographic detectors. The Eberline Sping panel, particulate and iodine channels may be used to provide indication /
alarm of particulate or iodine buildup and signify a need for filter evaluation, because these measurements can be corrected for background levels. The area monitors do not contribute to the release assessment or detection of significant releases.
As for the Regulatory Guide requirement for long term surveillance, GGNS procedures require that any entry into a radiation area be evaluated and supervised by plant health physics personnel. This evaluation is to be based on local area radiation readings using portable survey instruments that meet Category 3 requirements. Therefore, the area monitors would only be used to give an idea of the radiation levels possible in the areas and would provide little benefit in meeting the Regulatory Guide requirements for long term surveillance.
Since these monitors are not used for release assessment or personnel entry requirements but only for order-of-magnitude indication, a range to 104 R/Hr is not required. Therefore, it is MP&L's position that the existing area radiation monitors meet the intent of Reg. Guide 1.97.
Position 22 Noble Gases and Vent Flow Rate for Containment Purge, Standby Gas Treatment System (SGTS), and Fuel Handling Area MP&L has supplemented the original GE-supplied effluent monitoring system with a state-of-the-art Eberline digital effluent monitoring system.
This system provides monitoring over a range of 10-7 to 10 pCi/cc, which 5
meets Regulatory Guide 1.97 requirements. This system comprises two sub-units:
1)
A low range unit, meeting Category 3 requirements, comprises an AMC Isokinetic Probe and Flow Control Rack and a Eberline SPING-4 unit, which transmits information to the control room terminal. Monitor-ing is from 10-7 to 102 pCi/cc.
2)
A high/ accident range unit, which presently meets Category 3 re-quirements, comprises a sample probe, an Eberline AXM unit, and the data aquisition module.
(Note: the vent flow rate for release analysis is provided by the FM&IS panel via the SPING-4 microproces-sor.) Monitoring is from 10-4 to 105 pCi/cc. The present power supplies for the accident range monitors are at 1 cast as reliable as the power supplies to the HVAC trains they monitor. The SGTS A and B power supplies are Class 1E.
r-e Page 14 of 16-MP&L will install or upgrade the containment area, SGTS, and fuel handling area vent monitoring systems to meet Category 2 requirements as follows:
1)
Install an environmentally qualified redundant vent flow rate monitoring network, separate from the AMC FM&IS panel, which pro-vides input directly into the data acquisition module.
2)
Environmentally qualify the Eberline AXMs and data acquisition
-modules.
With these changes implemented, this instrumentation will meet the intent of Regulatory Guide 1.97, with the exception of the range monitored by environmentally qualified devices.
Based on the analysis performed to determine site boundary, LPZ outer boundary and control room doses resulting from a postulated LOCA, and the analysis performed to determine airborne activity inside the auxiliary and enclosure buildings, the activity release rate from the SGTS system would be 210-3 pCi/cc for iodine and daughter products and 210-1 pCi/cc for noble gases. There-fore, the noble gas activity release rate would be on scale for post accident conditions os. the AXM panel.
Since containment area and fuel handling area vent effluent monitors are powered from the same power susrce as the ventilation system that they monitor, operability of the effluent monitor-is ensured whenever the power source to that ventilation system is available.
Providing more l
reliable power supplies or restoring these monitors to onsite power sources is not necessary. Therefore, the effluent monitoring system power supply modifications proposed for the first refueling outage, as discussed in letter from L. F. Dale to H. R. Denton (AECM-81/339), dated Septent.ar 4,1981, are not considered necessary and are being superseded by this submittal.
It is MP&L's position that implementation of the scheduled instrumenta-tion upgrades will meet the intent of Regulatory Guide 1.97 and that additional qualification for the equipment which monitors below the range of the qualified AXMs is not necessary.
Position 23 Noble Gases and Vent Flow Rate for Auxiliary Building l
(including any building containing primary system gases) l MP&L has supplemented the original GE-supplied effluent monitoring system with a state-of-the-art Eberline digital effluent monitoring system.
This system provides monitoring from a range of 10-7 to 105 pCi/ce, which meets Regulatory Guide 1.97 requirements. This system comprises two sub-units:
1)
A low range unit, meeting Category 3 requirements, comprises an AMC l
Isokinetic Probe and Flow Control Rack, and an Eberline SPING-4 l'
Monitoring is from 10'7 to 102 unit, which transmits information to the control room terminal.
pCi/cc.
l
o Page 15 of 16 2)
A high/ accident range unit, which presently meets Category 3 re-quirements, comprises a sample probe, an Eberline AXM unit, and the data acquisition module.
(Note:
the vent flow rate for relr.ase analysis is provided by the FM&IS panel via the SPING 4 mirco-processor.) Monitoring is from 10-4 to 105 pCi/cc.
Because these instruments do not constitute a part of a safety system, seismic qualification is not required. Also, since there is no postulat-ed event that could cause a harsh environment in these buildings, addi-tional qualification for the normal environmental parameters is not required.
Since turbine building and radwaste building vent effluent monitors are powered from the same power source as the ventilation system that they monitor, operability of the effluent monitor is ensured whenever the power source to that ventilation system is available.
Providing more reliable power supplies or restoring these monitors to onsite power sources is not necessary. Therefore, the effluent monitoring system power supply modifications proposed for the first refueling outage, as discussed in letter from L. F. Dale to H. R. Denton (AECM-81/339), dated September 4, 1981, are not considered necessary and are being superseded by this submittal.
It is MP&L's position that the presently installed Category 3 equipment meets the intert of Regulatory Guide 1.97.
Position 24 Radiation Exposure Meters Per item 6.1.c.i of NUREG-0737 Supplement 1, " Continuous offsite dose monitors are not required pending their further development and consider-ation as requirements." MP&L does not plan to implement monitoring for this variable.
Position 25 Accident Sampling Capability Primary Coolant and Sumps An April 1984, NRC internal memo from Victor Benaroya, Chief of Chemical Engineering Branch, to Faust Rosa, Chief, Instrument and Controls Systems Branch states, in part:
The intent for obtaining a sump grab sample is to determine the location of component leakage under accident conditions.
Instead of sump grab samples, sump high level alarms, liquid or airborne radioactivity monitoring of sump area, or temperature detectors in sump area, are acceptable methods in determining leakage into sumps, 7
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o t
Page 16 of 16 GCNS has leak detection monitoring capabilities consisting of tempera-ture, differential temperature, differential flow and/or sump level monitoring for the following areas:
1)
Reactor water cleanup equipment rooms. Class IE 2)
Reactor core isolation cooling equipment rooms, Class IE 3)
Drywell drain sumps, Non-Q 4)
Residual heat removal equipment areas, Class IE 5)
Containment drain sumps, Non-Q 6)
Drywell, Class IE 7)
Containment, Class IE 8)
Main steam pipe tunnel, Class IE 9) liigh pressure core spray equipment areas Non-Q GGNS also has the capability to sample the primary coolant system, suppression pool and the containment and drywell atmospheres for perform-ing the analysis specified by the Regulatory Guide. The existing post accident sampling system has been designed to meet the previous require-ments of TMI Action Item II.B.3.
Because of these considerations, it is MP&L's position that the presently installed leak detection and sampling instrumentation meets the intent of Regulatory Guide 1.97.