JPN-91-049, Forwards Response to NRC 910123 Request for Addl Info & 910117 Telcon W/Nrc & NRC Contractors Re Station Blackout
| ML20082T691 | |
| Person / Time | |
|---|---|
| Site: | FitzPatrick  |
| Issue date: | 09/13/1991 |
| From: | Ralph Beedle POWER AUTHORITY OF THE STATE OF NEW YORK (NEW YORK |
| To: | NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM) |
| References | |
| JPN-91-049, JPN-91-49, NUDOCS 9109190108 | |
| Download: ML20082T691 (130) | |
Text
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- September 13,1991 JPN 91049 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Mall Station P1 137 Washington, D.C. 20555
SUBJECT:
James A. FitzPatrick Nucloar Power Plant Docket No. 50-333
- Response to Roquest ior Additional Information Regarding L'tation Blackout
REFERENCE:
NRC letter, D. E. LaBargo to J. C. Brons, dated January 23,1991 regarding request for additional station blackout information.
Dear Sir:
Attached are the Authority's answers to the fourtoon NRC staff questions concerning 1 station blackout at the FitzPatrick Plant included with the reference lettor.
The five attachments _ confirm and clarify the information provided to the NRC staff and it's contractors during a January 17,1991 conference call with the Authority.
Attachment I answers the fourtoon questions. Attachments 11 through V are calculations referred to in the answers, if you have any further questions rogarding this issue, please contact Mr. J. A. Gray, Jr, Very truly.yours,
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Ralph E. Boodle Exocutive Vice President Nuclear Generation cc: Noxt page 1
100042 D) 9109190109 910913 l
PDR-9 DOCK 05000333 P
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cc:
U. S. Nuclear Regulatory Commieslon 475 Allendale Road King of Prussia, PA 19406 -
Office of the Resident inspector U.S. Nuclear Regulatory Commission P.O. Box 136 Lys ling, NY 13093 Mr. Brian C. McCabe Project Directorate 11 Division of Reactor Projects l/11 U.S. Nuclear Regulatory Commission Mail Stop 14 B2 Washington, DC 20555 Attachments:
1.
Response to NRC January 23,1991 Request for Additional information regarding Station Blackout.
l-II.
" Control Room Heatup Analysis," Devonruo calculation 89-JAF-04 dated Juno 25, 1989.
Ill.
" Room Heatup Analysis " Devonrue calculation 89-JAF-0G dated October 24, 1989.
IV.
" Relay Room Heatup Analysis," calculation 89-JAF-05 dated June 23,1989.
- V.
" Plant Coping Capabilities Under Station Blackout Conditions per NUMARC 87-00," miscellaneous calculation [[::JAF-89-048|JAF-89-048]] dated September 20,1989.
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L Attachment I to JPN.91049 New York Pm ithority James A. FitzPatric.Joar Power Plant Response to NRC Request for Additional Information Regarding Station Blackout Question 1 i
Justify the EAC classification of "A". EAC classification is based on the required LOOP loads not SBO loads por NUMARC 87-00 Supplomontal Ouostions and Answors.
Response 1 Requirod LOOP (loss-of-offsito power) cloctrical loads are within tho capacity of a singlo EDG (omorgoney diosol generator), Using Table 3.7 of NUMARC 87-00, FitzPatrick has an EAC "A" classification, i.e.four EDGs are provided by design and only one is required for shutdown.
Table 8.6-2 of the FitzPatrick FSAR (Reference 5,
- Equipment Supplied By Each Emergency AC Powcr Source For Orderly Shutdown Without Offsite Power") lists the electrical load on each pair of EDGs for a LOOP. Four Icads on this tablo are not required to achlove and maintain safo shutdown in the event of an SBO: one RHR (Rosidual Heat Removal) pump (846 KW); one RPR Servico Water Pump (280 KW); one Standby Uquid Control System (SLCS) Pump (80 KW); are the SLCS Heators (80 KW), Subtracting the loads for those components reduces the required load to 2,501 KW.
During a LOOP, the second pair of RHR and RHMSW (Residual Heat Removal Servico Wator) pumps are not required. Electrical intorlocks provent the second RHR and RHRSW pumps from loading on to the 4kV busses when the bus is poworod by a single diosol.- Thorofore no oporator action is required to prevent the loading (or to shed) those pumps.
The SLC system need not operato during a LOOP. The SLCS pumps do not start cutomatically, so no operator action is necessary to provent their oporation or load shed.
Heat tracing on the SLCS pump suction piping is powered during a LOOP. A manual operator action would be required to shed this load.- Adding the heater load (80 KW) to the required equipment load (2,501 KW) results in a total LOOP EDG load of 2,581 KW. This is still loss than l
the continuous 2600 KW rating of one EDG.
The FitzPatrick EAC class is documented in Section 2.2 of Calculation [[::JAF-89-012|JAF-89-012]], Revision 0, (Reference 3).
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Attichment I to JPN 91049 Table 1 SBO Emergency Diosol Genorator Loads Based on FSAR Tablo 8.6-2 L
_KW Equipment 846 RHR Pump 280 RHR Snrvice Water Pump Y
200 Control Rod Drive Pump 200 Emergency Service Water Pump 75 Motor Operated Valves 75 DieselGenerator Auxiliaries
- 60 Battery Charger 25 Reactor Protection System (RPS) MG Set 25 Turbine Turning Gear Drivo 30 Turbine Gear Oil Pump 585 Emergency Plar.t HVAC 100 Emergency and Plant information Computer System 80 Standby Uquid Control Heaters *
-2581 KW Total Electrical Load
- Not required to achieve and maintain safe shutdown. Manual operator action required to shed electricalload.
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Attachment I to JPN 91049 Ouestion 2 Provide the details of what loads are stripped and when they are stripped so that 'he Class 1E batteries have sufficient capacity to meet SBO loads for four hours.
Response 2 The load shedding scheme for each battery is described in Tables 2 and S. Tables 3 and 4 are load profiles for each station battery during an SBO.
The Authority has completed calculations that demonstrate that either the A or B station battery is capable of powering SBO loads for more than six hours. These calculations used the methodology outlined in IEEE-485 (Reference 20) and applied penalties for initial low electrolyte temperature (10%) and battary end-of life condition (25%). In accordance with NUMARC 87-00, no credit was taken for load shedding until thirty minutes into the SBO.
The actual load shedding instructions are in stop C.7 of F-AOP-49 (Reference 7).
The ability of the station batteries to power SBO loads for four hours is documented in Catectation [[::JAF-89-013|JAF-89-013]], Revision 2 (Reference 8).
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Attachmont I to JPN 91049 T
Tablo 2 Load Shodding Scheme for Station Battery 71SB 1 At T= 30 minutes, the f ollowing electrical loads are shed from station battery 71SB 1:
The emergoney DC lubo oil pumps for the main foodwater pump turbino, The omorgency DC lubo oil pumps for tho main turbino, and Non-vital DC lighting.
At T= 60 minutes, the following cloctrical loads are shed from station battery 71SB 1:
The UPS (Uninterruptablo Power Supply) MG (Motor Generator) set.
Shodding the UPS MG sot will ensure that the A battery can power its SBO loads for four hours.
Onco the UPS is shed, the primary sourco o' plant information for the operators would be the 09-95 and 09-96 panels in the relay room.
To provide control room operators with botter instrumentation in the event of an SBO, the Authority proposed a modification F189-158 to supply the 27 MAP panel with omergency electrical power during a SBO After this modification is installed, each half of this panol will bo poworod from a different LPCI battery during an SBO. No operator action will be nocessary to effect the power transfer. The batteries can handlo the additional load imposed by thoso panols.
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Attachmont I to JPN 91049 4 -
Table 3 Station Battery Load Profilo During SBO
- A" Battery (71S8-1)
This load profile conservatively assumes that the A train section of the 27 MAP panel is poworod from the battories two minutos after the start of the event.
Time after start of SBO, Total Battery Load 01 minutes 1008 Amps 12 minutes 803 Amps 2 30 minutes 678 Amps 30-60 minutos 499 Amps 60120 minutes 194 Amps 120 240 minutes 194 Amps Table 4 Station Battery Load Profile During SBO
- B' Battery (71SB 2)
This load profile conservatively assumos that the B train section of the 27 MAP panel is powered from the batterics two minutos after the start of the event.
' Time after start of SBO Total Battery Load G-1 minutes 1017 Amps 12 minutes 932 Amps 2-30 minutes 507 Amps 3060 minutes 210 Amps- 60-120 minutes 210 Amps 120-240 minutes 210 Amps 5
Attachment I to JPN 91049 4
Table 5 Load Shedding Scheme for Station Battery /1S8 2 At T=30 minutes, the following electrical loads are shed from station battery 71SB-2:
The omorgency DC lubo oil pumps for the main foodwater pump turbine, The omorgency DC lubo oil pumps for the main turbino, and Non-vital DC lighting.
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Attachmont I to JPN 91049 4
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- Question 3 Provide information rogarding the EDG roliability program which moots the requirements sot forth in NUMARC 87 00. Provido the continuous and 2000-hr. tatings of the EDGs.
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Response 3 Emergoney Diosol Rollability Program The Authority will preparo and implomont a formal EDG roliability program when NRC Gonoric Issuo B 56 *Emorgoney Diosol Gonorator Roliability* has boon resolved. This Authority commitment has boon stated in two lotters to the NRC (References 11 and 22).
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s As stated in Referenco 11, the Authority has established an EDG tar 001 rollability of 0.95 for i
FitzPatrick, This targot is consistent with FitzPatrick's four hour coping duration category.
FitzPatrick's EDGs have consistently surpassed, by a significant margin, the reliability goals outlined in Appondix F to NUMARC 87-00. Table 6 providos FitzPatrick's EDG naliability for the past F % and 100 domands.
Emergoney Diesel Gonorator Ratings The FitzPatrick EDGs ratings ato listed in Tablo 7.
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Attachment I to JPS91-049 Tablo6 James A. FitzPatrick Nuclear Power Plant Emergency Diosol Generator Rollability as of September 4,1991*
Last 20 Last 50 Last 100 Diosol Domands
_Domands Demandst A
1.00 1.00 1.00 B
1.00 1.00 1.00 C
1.00 1.00 1.00 D
1.00 1.00 1.00
- The last Emergoney Diosol Gonorator damand pri-"'
.amittal of this report was on September 4,1991, th 1100 demands covers the timo period from the 4 quarter of 1986 through the presont.
Tablo7 FitzPatrick EDG Ratings Rating Period Rating (KW)_
Continuous (8,720 hrs.)
2,600 2000 hrs.
2,B50 160 hrs 2.950 30 minutos 3,050
l Attachmsnt I to JPN 91-049 l
Ouestion 4.a Loss of HVAC (detailed answer is required):
The licensoo's April 17,1989 SBO submittal (lotter JPN 89-018) stated that the calculated control room temperature excooded 120 degroos F and would be recalculatod. The subsequont SBO submittal of March 29,1990 did not provido any information on control room temperaturo for en SBO. Provido the calculated maximum SBO temperature for the control room for the four hour i
coping porlod and the assumod initial control room temperature. Identify the methodology used in this calculation, and, if different from the NUMARC 87-00 methodology, provide a copy of the calculation.
f Response 4.a l
The original control room temperaturo calculation erroneously assumed the existence of an acoustic tilo drop colling in the FitzPatrick Control Room. An open-grato drop ceiling has always existed in the FitzPatrick Control Room. This type of ceiling permits air to flow frooly from one side to the other and has no insulating value. Since a drop-tilo ceiling reduces the volume of air in
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the control room and acts as a layor of insulation, the original calculation overestimated the maximum control room temperature.
The Authority has completed two revised control room heatup calcuMtions. The calculations were performed using the NUMARC 87 00 methodology (Section 7.2.4) and assume an inside wall temperature of 75 degrees F and an outside wall temperature of 104 degroos F. Accordingly, an initia! temperature of 89.5 degrees F was used.
The first caso assumed that fifty percent of the battery-powered electricalloads are in the control room and fifty percent are in the relay room. The second caso assumod that ninety porcent of tho DC-poworod loads are in the control room.
l Calcula*.lons for the first caso predict a maximum control room temperature of 92 degrees F.
l Maximum control room temperature for the second case is 109 degrees F.
A copy of those calculations is included in Attachment 2.
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Attachment I to JPN 91049 Ouestion 4.b The licensee has not provided SBO temperatures in the drywell, suppression pool, and main steam tunnel which are usually Dominant Areas of Concern (DACs) in BWRs such as FitzPatrick.
Provide results of ambient air SBO temperature calculations for these rooms (including assumed initial temperature and methodology) or provide a detailed justification to why these rooms are not DACs for an SCO event. The licensee should note that the drywell ambient air temperature must assume an RCS leakage of 61 gpm which is made up of 18 gpm from each recirculation pump and 25 gpm technical specification leakage. The suppression pool temperature calculation is also
- required to ensure that pool temperature limits are not exceeded during an SBO event.
Response 4.b 4
No equipment in the drywell, torus, or main steam tunnel is required to mitigate the effects of an SBO The paragraphs below further justify why each of these areas are not Dominant Areas of Concern (DACs) using the critiera outlined in NUMARC 87-00.
Drywell i
No equipment in the FitzPatrick drywell is required to function to mitigate the effects of a design basis SBO.
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NUMARC 67-00 assumed that the peak drywell temperature during a SBO would be bounded by l
the peak post-LOCA temperature. The Authority confirmed this assumption with three plant-specific calculations performed for the FitzPatrick IPE (Individual Plant Evaluation). All three l
calculations predict a maximum SBO drywell temperature of approximately 200 *F after four hours. This is considerably less than the peak post LOCA temperature inside the drywell of 4
approximately 300 *F (FSAR Figure 14.6-6) and the drywell design temperature of 309 *F (FSAR Figure 5.2-1).
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Two calculations assumed a 36 gpm seal leak; one calculation assumed a 65 gpm leak. The first 36 gpm leakage calculation assumed that the SRVs and HPCI are used to depressurize the RPV.
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. The second 36 gpm calculation assumed HPCI alone is used to depressurize the RPV. The third calculation assumed a 65 gpm RPV to-drywell leak rate.-
The only equipment in the drywell which might be helpful (but not required) to mitigate the effects of a design basis SBO are the SRV (Safety / Relief Valve) pilot solenoids. Operable SRV solenoids would allow automatic or manual pressure reductions. However, their failure does not preclude achieving and maintaining safe shutdown. IPE calculations show that during an SBO, reactor pressure and torus water temperature do not reach conditions requiring manual depressurization.
Operation of either HPCI (High Pressure Coolant injection) or RCIC (Reactor Coolant isolation Cooling) systems provides adequate RPV (Reactor Pressure Vessel) pressure control.
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While the SRV pilot solenoids are not required to mitigate an SBO, they are environmentally qualified to post LOCA temperature and pressure conditions and would in fact be operable, 4
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Attachment I to JPN 91049 4
i Torus (Suppression Pool) l Elevated torus temperature and pressure could, in thoory, affoct FitzPatrick's ability to mitigato tho effects of an SBO in two ways. Because the HPCI and RCIC pumps use a small portion of water from the pump to cool the pump and its lubricating oil, hot water frorn tho torus would not l
adequately cool the HPCI (or RCIC) turbino lubo oil. Secondly, torus air pressure at or above tho l
HPCI (or RCIC) turbine high backpressure sotpoint would cause the turbine to trip.
t To assure that the HPCI and RCIC turbine lobe oil receives ndoquato cooling during an SBO, the FitzPatrick station blackout procedure (Referenco 7) instructs tho operator to dofoat the automatic transfer of HPCI suction from the CSTs (condonsate storage tanks) to the torus on high torus f
pressure. This assures a cool supply of water from the CSTs and adoquate turbino oil cooling.
Sinco no similar transfer logic is present in the RCIC system, the station blackout procedure instructs the operator to maintain RCIC suction from the CSTs.
l The HPCI and RCIC high backpressure setpoints of approximately 150 psig and 50 psig respectively are well above the maximum torus pressure predicted for a four hour SBO cvent.
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r Main Steam Tunnel i
No equipment in the main steam tunnel is required to mitigato the effects of an SBO. Accordingly, l
the main steam tunnelis not a DAC.
l Calculations performed using NUMARC 87-00 methodology predict that during a four har SBO, ambient temperatures near the drywell entrance and suppression pool room areas could roach 184 degrees F and exceed HPlC and RCIC high ambient temperature isolation setpoints. To i
prevent HPCI or RCIC from inadvertently isolating in the event of ari SBO, proceduro F-AOP-49 directs the operator to place the main steam break detection circuits in the test mode. This effectively prevent HPCI or RCIC isolation due to elevated temperature in the drywell entranco
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Temperatures ir a the suppression pool room waro not calculated because temperatures near the drywell entrance are known to I:s higher.
Because the 090 procedure includes steps to preclude inadvertent HPCI or RCIC isolation due to high ambient temperatures, the suppression pool and drywell entrance areas are not DACs at I
FitzPatrick.
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Attachmont I to JPN 91049
,Ouestion 4.c The licensoe's stated SBO temperature of 130 degroos F in the HPCI and RCIC rooms appears to be low compared to calculation results provided by other similar BWRs. Provide the assumed heat load, initial temperature, room sizo and total wall surfaco area for those rooms.
f Response 4.c At the FitzPatrick plant, the HPCI and RCIC pumps, turbinos and auxiliary equipment are contained within ventilated onclosures. The HPCI onclosure has five sidos with no roof or ceiling.
RCIC equipment is onclosed on six sides but is ventilated by oxhaust fans. Both onclosures are located inside the crescent area which is a relatively largo and opon volume. The crescent area is below grado lovol. The low maximum temperature predicted for FitzPatrick's HPCI and RCIC areas during an SBO ovent may be attributable to this unique layout. The Authority does not have calculations for other BWRs and cannot comment on them. At other BWRs, the HPCI and RCIC systems are gonorally contained in smallor
- corner" rooms with little or no air circulation.
The Authority performod SBO HPCI and RCIC room heat load calculations using the methodology described in NUMARC 87 00. Peak area temperaturo calculations assumed the use of HPCI (not RCIC) for Reactor Pressuro Vossolinjection. The higher heat load associated with HPCI operation bounds RCIC operation.
Tho Authority has proposed a plant modification (F189-159) to provido an alternato source of electrical power to the two RCIC enclosure vont farm. Soo response to Question 6.
A copy of the FitzPatrick crescent area heat up calculation is included as Attachmont 3, 12-
Attachment I to JPN 91-049 Question 4.d The licensoo has not specifically identified whether any SBO related procedures will adviso the operators to open the instrumentation and control cabinets in the control room within 30 minutos of an SBO event. This is a requiremont which was addressed in the NUMARC 87-00 Supplomental Questions and Answers of December 27,1989.
Response 4.d Although it is not necessary, Stop C.6.a of the FitzPatrick SBO proceduto F AOP-49 (Reference 7) directs oporators to "opan all panol doors in the Control and Relay Rooms."
Opening the panol doors is not necessary because calculations predict that the peak temperature insido control and relay room cabinets will not exceed 109 degrees F (worst case) in the control room. See Attachment 11.
The Authority's response to Question 8 addresses instrumentation cabinets in the rolay room.
f Attachment I to JPN 91049 Ouestion 5 Section 7.3 and Table 7.31 of the FitzPatrick Updated FSAR does not provide sufficient information to perform a containment isolation valvo review in accordance with the critoria of NUMAnC 87-00 and Regulatory Guido 1.155. Provido a complete list of ali primary containment penetration valvos which includes the following information for each isolation valve: valvo size, valvo type (e.g. check va!ve), status upon loss of all AC power, valves which are normally locked closed, number of valves on the same penetration, and valvos with acceptable means of position indication (NUMARC 87 00, Section 7.2.5).
Response 5 The Authority rild not use the methodology outlined in Section 7.2.5 cf NUMARC 87-00 to ensure that "appropriato containment integrity can be provided during a station blackout event for the required duration." NUMARC 87-00 assessed containment integrity on a valvo-by-valvo basis, without considering any redundancy in isolation capability for a given ponctration.
The Authority took a different appicach, performirr a containment ocnotration-by-penetration review. For each containment ponotration, the A. ithority ensured that each lino that is required to be isolated in the event of an SBO is isolated by at least one of the fo! lowing:
A fail cim:ed valve, A locked closed valve, An automatic check valvo, A valvo interlocked with another valvo, (e.g., two valves on a single line with control circuits that prevent both valves from being open at the same tinyt or, A DC powered motor operated valve.
This alternate approach fulfills the intent of Section 7.2.5 and is consistent with NUMARC 87-00's assumption that non mechanistic failures need not be postulated.
Panel 27 MAP includes primary containment isolation valvo position indicators that satisfy the guidance of Regulatory Guide 1.97 for variable B10. As the Authority described in Reference 22, these indicators aro QA Category 1, environmentally and seismically qualified, and redundant. As a Regulatory Guide 1.97 Category 1 instrumentation, power is supplied from a 1E qualified source.
However, the set of containment isolation valves selected by the Authority to isolato primary containment in the event of an SBO is not the same set of valves used following a design basis accident.
There is no reason to isolate the RHR and core spray suction lines (penetrations 225A,2258,227A and 227B; 20 inch and 16 inch diameter lines) from the suppression pool during an SBO. During an SBO, these lines are effectively an extension of the primary containment pressure boundary and are isolated by the water seal created by the normal water lovel in the suppression pool above the pump suction strainers. _
AttachmentI to JPN 91419 d
l l tion Tho Atr.hority described its approach to the NRC staff in Reforenco 22.
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is includod in Attachment 5 and summarized in Tablo 8.
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TABLE 8 A'
James A. FitzPatrick Nuclear Power Plant Containment isolation Provisions Dering an SBO TMU PENETRxTION NOMINAL VALVE SYSTEM NUMBER OFISOLATION SBO EVALUATION VALVES PER NUMBER SIZE (IN.)
PENETRATION OR PER UNE"OM'l Bo'h MOVs are ru many c!cse-1 The rnboard va*ve is AC 52 20 RHR Shutdowa 2 MOVs powered and the outixard valve is DC powered. Posi+Jon Cooling indication is availat%e via the 27 MAP panet
. The check valve and the inboard injection MOV a e 13A,B 2;
RHR (LPCI) 2 MOVs injection 1 check valve normany closed and the cuttoard MOV is normany cpen.
The AC/s are powered from the LOCI Incependent Pour Suppfies. Interlocks are prov:ced to prevent both MOVs fr om being open when reacior pressure is above approximately 350 psig.
. Position Indication is availat9e fa the 27 MAP paM.
. Both MOVs are normaHy open T'se outboard valve and its 14 6
RWCU Suction 2 MOVs cssociated bypass line MOV are DC powered and would automatica!!y close on a Group I isolation. The ich d valve is AC powered. Posidon indcraon is availabio via the 27 MAP panel.
. The two LO/s are AC powerec wth the inboard MCN 1SA, B to CS Injection 2 MOVs 1 check valve be:ng normaDy esosed and the outboard va've normany open. Interlocks are prcW to prevent both MOVs from being open when reactor pressure is greater than appresT.ately 425 psig. Position ir6.at. Mis available via the 27 mar' panel
. Both MOVs are normal?y closed. The irboard vafve is AC V7 4
RHR Head Spray 2 MOVs powered and the cutboard va've is DC pcesied. Pos?Jon indicahon is via the 27 MAP paM.
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Attachment i18JPN.91049 t
Table 9 1
Unos Pentrating Primary Containment and Excludod Using the Criioria of NtINT#iB 87 00, Section 7.25 i
Exclusion Critorion 1 Penetration No, DNJiption of Uno Functbn (line C'rc) l 228 Condonsate to Supptossion Pool (10 In.)
Excluslon Critorion 3 t
9A,90 Main Foodwator (18 in.)
i 212 Roactor Core Isolation Cooling Turbino Exhaust (8 in.)
214 HPCI Turbine Exhuast (20 in.)
Exclusion Critonon,,5 31Ac,31Bc RWR Soa! Purgo (1 in.)
35 Traversing incore Probe (1 in.)
37,38 Control Rod Drive Supply and Return (1 in.)
210A,210B Residual Heat Removal Koop-full (1 in.)
210A,2108 Core Spray Koop full (1 in.)
Exclusion Critorion 3 and 5 42 Standby Uquid Controf System (1.5 in.)
57 -
Containment Air Dilution suppl / to Drywell (1 in.)
221 RCIC Vacuum Pump Discharga (2 in.)
222 HPCI Turbino Drain Trap to Supprossion Pool (2 in.)
i i
1 i
c 27-
Attachment I to JPN 91040 Question 6 Provide infortnation regarding the quality assuranco aspects and SBO equipmont which will be relied upon to cope with a postulated SBO ovent as tequirod by Rogulatory Guido 1.155, Appendices A and B.
Response 6 With the exception of the RCIC enclosuro vontilation fans, all equiprnent tollod upon to cope with a postulated FBO event is covered by the Authority's Quality Assurance Prograrn for safety related equipment. The RCIC onclosure ventilation fans (13FN 1 and 13FN.2) are currently powerod from a non-OA Category 1 power supply.
The Authority proposed a modification (F189159, Reference 10) to power to those fans during an SBO. After this modification is installod,6ach fan will be powerod from a difforont LPCI battery using the associated LPCl invertor during an SBO. The LPCI battorios and invortera have adoquate capa0lty to power those fans and other required equipment during a SBO. No operator
- action will be necessary to effect the power transfor.
If this modification is inr,talled, the fans themsolves will be roclassified as OA Category M. Soo responso to Question 12.
r F
r 28-I-
1
-~.
Attachment I to JPN 91049 Question 7 The licensco has not addressed the positive or negative offects,if any, of the closo juxtaposition (1,0. 3000 foot) to RtzPatrick of the Nino Milo Point Unit 1 and 2 nuclear power plants. Fiovido an ovaluation of the potentialinfluence of thMo nearby plants on Fit?. Patrick within the context of an SBO event.
Response 7 No studios have boon dono by the Authority to quantify the influence of the two adjacont nuclear power plants on a the probability or offects of an SBO. The Authority's SBO coping studios conservatively assumed that RtzPatrick was a single-unit site and did not take credit for either >'
the two adjacent Nine Milo Point (NMP) Nuclear Power Plants. FitzPatrick SBO procoduro F.
AOP 49 (Referonce 7) directs the Shift Supervisor to contact the NMP control room and the NYPA Enorgy Control Contor at Marcy in the event of a SBO.
i 29-
Attachment I to JPN 91-CM9 i
W Ouostion 8 Has the rolay Ioom boon ovaluatod as a Dominant Arca of Colecorn? Provide calculation.
Rosponso 8 FitzPatrick's Rolay Room has boon ovaluated as a Dominant Arca of Concern (DAC). The maximum rotay room air temperature have boon calculated using the mothodology outlinod in NUMARC 87-00. Those calculation prodict a maximum temperaturo of 106 dogroos F during a four hour SBO, A copy of this calculation is includod as Attachmont 5.
30-
Attachmont I to JPN 91449 s
Question 9 Once Modificabon F189158 concorr.ing the Unintorruptablo Power Supply (UPS) to Control Room Panel 27 MAP is completod, describo the instruments which will be available when the UPS is load shed. Describo the instruments which will be lost, what instrumonts will bocomo availablo, and the not offect on the Control Room hoat load following a load shoo for SBO.
Ryoonso 9 SBO Instrumentation in the event of an SBO, panel 27 MAP and Analog Transmittor Trip System (ATTS) indicators will be available to the operator. The combination of instruments provided by thoso panols is adoquato to monitor coro cooling and containment intogrity during a four hour SBO ovent.
Panol 27 MAP will provido the following indicators: (1) wido rango drywell pressuro; (2) wido range supprossion pool lovol; and, (3) primary containmont isolation valvo position, excluding chock valvosc These indicators woro designod and installod to moot the guidanco of Regulatory Guido 1.97 for post accident instrumentation. Soo Reference 22.
Five ATTS indicators will be available to the operator: (1) wido and narrow range reactor vossol water level; (2) narrew range drywell prossuro; (3) main stoam isolation valvo position; (4) scram dischargo instrument volume level; and, (5) HPCI and RCIC steam broak protoction system status (high ambient temperature, high stoarn flow and low steam pressuro).
Loss of UPS FitzPatrick Abnormal Operating Proceduro F AOP 21 (Reference 15) summarizos the plant's response to a loss of UPS. Table 10 outlinos some of the symptoms associated with a complete loss-of UPS.
The FitzPatrick SBO proceduro Instructs the oporator to shod the UPS approximately sixty minutos into a SBO ovent.
!I 31-I
Attachmont I to JPN 91049 i
Table 10 Some of the Symptoms Associated with a Complete Loss of UPS at FitzPatrick 1.
Control rod drive display lights de energized 2.
Primary Containment graphic display lights de-energized 3-Recirculation neotor generator sets runback to minimum speed 4.
Feedwater control system locks up f
5.
Five Control Room meters are lost:
a.) Reactor Pressure b.) Reactor Level c.) Reactor Steam Flow d.) Reactor Feed Flow 6.
Six 'ecorders " lock up" a.) Average Power Range Monitors b.) Source Range Monitors,7 45 CPS c.) Core Plate Differential Pressure d.) Feedwater Flow e.) Reactor Level and Pressure f.) Reactor Prossure/ Turbine Steam Flow 7.
SRV ocoustic monitor annunciator illuminated 3
32 s
Attachment i to JPN 01049 Question 10 Provide the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> load profilo for each battery.
Rosponso 10 Tho 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> load profilo for each battory is includod as part of the Authority's responto to question 2, tables 3 and 4.
33-
Attachment I to JPN 91049 QAstion 11 Provide the assumptions usod for the High Prossure Coolant Injoction System doptossurization of the reactor and the assumptions used for drywell temporature tolated to SBO. Ensure that the assumptions ata consistont, Responso 11 The Authority conservatively assumod that the HPCI systorn was oporated continuously and that any flow not required to maintain reactor water levol was returned to the condonsato sintago tanks. Stoam flow to the HPCI turbine was assumod to be 150,000 pounds por hour at 1000 psig reactor pressuro.
The drywell is not a l'e.C at FitzPatrick. Soo respon50 to question 4.b.
The assumptions used in those analysos aro consistent with thoso prodictod for a four SBO ovont.
34
.n--c
s Attachment i13JPt191049 i
. i r
f Question 12 t
in relation to the modification to convert the Reactor Core Isolation Cooling enclosure ventilation fans to DC, has the load been considered in the battery capacity calculation and the fans capacity check for adequacy?
l e
Response 12 j
i The modification proposed by the Authority does not convert these fans to DC. The Authority l
proposed to power these f ans from RizFatrick's Low Pressure Coolant injection (l. CPI) independent pw supply busses, an independent source of AC power. Each fan would be powered from a different LPCI electrical bus. Since these fans would not draw power from the station batteries, the operation of these fans doA not affect tlw ability of the station batteries to i
cope with an SBO.
~
The fans are adequate to cool the enclosure.
The Authority has tentatively scheduled installation of this modification for the 1992 refuel outage.
[
The Authority will install this modification after the NRC lasues its Safety Evaluution Report on RtzPatrick's compilance with 10 CFR 50.63.
t i
i i-s i-.
f i
4-4-
I 35-
Attachment i t)JPN 91049
,/
i I
Ouor. tion 13 Provido a revisod calculation for the total condensato needed for SBO which includos roactor vessel leakage, depressurization, and decay heat removal.
R_osponse 13
[
Reactor Vessel Leakago Assuming the maximum reactor coolant system leakrate permitted by Tochnical Specifications (25 gpm) plus 18 gpm (per pump) recirculation pump seal leakage, a total of 14,640 gallons of condensato are requited to makeup roactor vossel leakago during the four hour coping period.
Vossel Depressurization The FitzPatrick reactor vessel nood not bo depressurized during the four hour coping porlod. As a resuit, no inventory is assumed to be lost. Soo rosponse to question 4.b.
The volume of water in the reactor vessel bolow the bottom of the stoam dryor is approximatoly 5.600 cu. ft. (or 42,000 gallons).
Decay Heat Romoval Calculations using the mothodology outlined in NUMARC 87 00 predict a minimum condonsato inveratory requirement of 53,884 gallons over the four hour coping period.
Therefore, the total condensate requi'od to mitigato tuo offects of an SBO is 68,524 gallons.
14,640 gallons lost due to system leakago pluu 53,884 required for docay heat removal.
Assuming that the total volume of water below the steam dryer must also be made-up, the volumo required (approx.110,000 gallons) is still significantly loss than the minimum CST volumo (200,000 gallons) permitted by Technical Spocifications, t
r t
38
Attachmont I to JPN 91 CM9 Oooction 14 Provido Control Room heatup calculations for SBO.
Rosponto14 Control Room boatup calculations are includod as Attachmont 2.
37-i
Attachmont I to JPN 91049 f'
s References 1.
Nuclear Managomo1 and Resourcos Council Roport 87-00, "Guidolinos and Technical Basos for NUMARC Initiativos AddrostJng Station Blackout at Ught Wator Reactors
- dated November 1987.
2.
NUMARC 87 00, *Supplomontal Ouostions and Answors' dated Docomber 27, 1989.
3.
NYPA Calculation Set No. [[::JAF-89-012|JAF-89-012]], Revision 0, 'Dotormination of Roquirod (SBO) Coping Duration Por NUMARC 87 00* dated March 14,1989.
4.
NYPA Calculation Set. No. JAF-89448,
- Plant Coping Capability Under Station Blackout Conditions Por NUMARC 87 00* dated September 20,1989.
S.
James A. FitzPatrick Updated Final Safety Analysis Report (FSAR) Soction 8.6,
- Emorgoney AC Power System,' Tablo 8.6.2
- Equipment Supplied by Each Fmorgency AC Power Sourco For Orderly Shutdown Without Offsite Power James A. FitzPatrick Nuclear Power Plant.'
6.
James A. FitzPatrick Updated Final Safety Analysis Report (FSAR) Section 7.3
- Primary Containment and Reactor Vessel isolation Control Systom*; Tablo 7.31
'Rimary Containment isolation Valvos' 7.
- Station Blackout.'
8.
NYPA Calculation Set. No. JAF 89413, Rovision 2,
- Station Battery Capacity Under Station SBO Conditions
- dated Novomber 14,1989.
9.
NYPA Modification F189-158, Conceptual Design Package, dated Octobor 10, 1990, " Power 27 MAP From LPCI invertors' 10.
NYPA Modification F189-159, Conceptual Design Package, dated September 27, 1990,
- 11.
NYPA lettor, J. C. Brons to NRC (JPN 89-018) dated April 17,1989 regarding Response to 10 CFR Part 50.63, Loss of All Alternating Current Power Station Blackout.
12.
NRC Generic Safety issue (GSI B 56) Emorgoney Diosol Generator Rollability.
13.
Devooruo lettor, A. Faramazi to K. Vohstodt (DLNYPA 8048-01/AF) datod August 1,1989, regarding station blackout room boatup analysis.
14.
Devonrue Report
- Evaluation of Drywell Heatup During Station Blackout in Support of Applicability of NUMARC 87 00 Assumptions
- dated March 1990, 15.
NYPA Abnormal Oparating Proceduro F AOP 21,
- Loss of UPS,* Rovision 8 dated June 12,1990.
38
Attachment i to JPN 91049 jo 16.
Devonroe lettar, A. Faramarz! to K. Vehstedt (DLNYPA 891043/AF) dated October 30,1989 regarding revised crescent heatup analysis.
17.
- Station Blackout,' datod June 1988.
18.
10 CFR 50.63, ' Loss of All Altornating Curtont Power,"
19.
Devonruo Calcutation 89-JAF44
- Control Room Heatup Analysis' dated June 25, 1989.
20.
Devonrue Calculation 89-JAF-05 'Rolay Room Hoatup Analysis' dated Juno 23,
- 1989, 21.
Devonrue Calculation 89-JAF 08 ' Room Heatup Analysis' dated October 27,1989, 22.
NYPA letter, C. A. McNeill,Jr. to D. B. Vassallo dated November 30,1964 (JPN 84-077) rogarding Supplomont 1 to NUREG0737 (Gonoric Letter 82 33), Rogulatory Guide 1.97, Revision 2, implemontation Report.
39-
,r*
r Attachmont ll to JPN 91049
' Control Room Hoatup Analysis' 1
I Devonrue Calculation 89 JAF 04 Dated June 25,1989 1
T b
New York Power Authority James A. FitzPatrick Nuclear Power Plant
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'A 5.o Re FeRENCES
[G N U MARC 8 7 -co, " G wd hes a,rd' TFch<wa/ Bs s MtMARC IniliaWies Acidroniu gMib, 3 lac w+ o +
l @ hf daf(r Reac hirs d fd' tlovemby 119,2
[G Devondute Calcalolibn No.
g q. 3A p. p.z chjej lfril l 6, f 9 6 9, jevisibn 95
[G LeIhr Tb:
iLvol FAfarvn47 i C Oc vcer.,r> Fdoivl Ven t
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NEW YORK POWER AUTHORITY -
[
g JAMES A. FITZP ATRICK NUCLEAA POWER PLANT
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4# Authority S9M -ON l
MAY 30, 1989-
[
KJV-89-25 t
i Mr. Ahmad Faramarzi
,Devonrue, LTD.
180 Lincoln Street Boston, Massachusetts 02111
Dear Mr. Faramar:
- i:
l
SUBJECT:
JAMES A-FITZPATRICK NUCLEAR POWER PLANT STATION BLACKOUT ROOM HEATUP ANALYSES t
The Authority has-_ reviewed your transmittal 8904-01/AF dated April 18, 1989, concerning predictions of maximum steady state i
temperatures in selected plant areas under station blackout conditions.
Due to the predicted temperatures being significantly higher than expected in the control room and relay room, NYPA has concentrated on the assumptions and methodology employed for those rooms.
Our detailed comments and observations O
are attached to this leteer.
t If you have any questions or comments, please contact me at
[
-(914) 681-6314
{
Very truly-yours, K. J. VEHSTEDT OPERATIONS & MAINTENANCE-BWR KJV mac cc:
R. H. Lauman, Jr.
J. A. Gray, Jr.
-P. W. Brozenich i
RMS-WPO-11
[.
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1 -
ATTACHMENT "A" TO KJV-89-25 w7
@.. M r-Off RELAY ROOM ANALYSIS-
_ VOLUME Per_ drawing FA-16A, Rev.'16, the principle dimensions of the H
= relay room are 76 feet (from mark 9 to mark 12 less two foot thickness of the north'well) and 66 feet (from mark G to mark-C) for a floor area of 5,016 sq. ft.
Per_ drawing FA-18B, the height of the room is from floor elevatien 284'8" to-the control room floor 300'0" less the 6 inch thickness of the-floor for a height of 14.83 ft.
3 The resultant. uncorrected volume is 74,402 FT.
For calculational purposes assume a 10% volume reduction to account for structures and equipment, or a net free volume of 66,962 cu
-ft.
HEAT INPUTS The referenced SWEC. calculation, No. 70-25, assumed normally operating (heat) loads from lighting and equipment only, no transmission gains being considered.
That calculation is not applicable to these. station blackout analyses.
.O.
Per SWEC calculation-No 70-6, the following data and eesumptions were used in determinins trenemiseton saine into the relay room-for sizing the HVAC system:
Rcom. Temperature:
75'F Outdoor Temperature 93*F
" Indoor" Temperature: 105'F*
AREg)
WALL (FT u
T Btu /hr WEST 1155 0.305 30 10.550 NORTH 1047 0.305 30 9.560 SOUTH 1047 0.305 50 15.960 EAST 1155 0.350 22 7.750 FLOOR 5030 0.360 30 34.700 98.020 = 28.7 kw
=
- For non-air conditioned areas The-SWEC estimate of the transmission gain, 28.7 KW, should be compared-with the initial gain predicted using the NUMARC 87-00-Model (i.e., when the room is at 75'F).
Per drawing FE-658, Rev.-10, emergency lighting in the relay room consists of one lamp fed from lighting panel EADCl O
(covered fro = the "^" etetton betterv) and rive "^PPeadix
-R battery-backed lamp pairs.
1-
. -. ~. _- - -.-
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' ATTACHMENT A" TO KJV-89-25 1-J h
RELAY ROOM ANALYSIS i
-Per SWEC Calculation No..'70-6'the normal (operating) i
-equipment heat load in the relay room is-14 kw.--
Assuming'an additional 10%-load for margin, the equi load considered was 52,600 Btu /hr (15.41 kw).pment sn Copies of the-'following drawings are attached for your review / records:
)
FA-16A,.-Rev.-16 FA-16B, Rev. 17-FA-16C, Rev. 6-FA-183, Rev. 4 I
FE-65B, Rev. - 10 I
.}
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_ y q /7 ATTACHMENTf"B" to KJV-89-25 M - 3 AF_o T n
1s)?
CONTROL ROOM ANALYSIS l
-VOLUME Per drawing FE-65A, Rev. 11, the principle dimensions of the
- control-room are 68 feet (from mark G to' mark C plus two feet) and 76. feet'(from mark 9 to mark 12 less two feet).
The. uncorrected floor area is thus 5,168 sq. ft, Utilizing the attached sketch (a modification of that telecopy. dated April 28, 1989), the following dimensional data was_ developed:
)
The area of node E is approximately 396 sq. ft.
assuming _an internal wall (wall E on the sketch)
't thickness of one foot.
'~
The-area of node D is approximately 465 sq. ft.
The area of node C is approximate 1.y 207.5 sq. ft.
The area of node B is approximately 76.67 sq. ft.
i
()
The net free volume of node A is 4,022 sq. ft.
_ Treating nodes B, C, D, and E as dead-ended; volumes, the free volume of-the control room.is approximately 80,447 cu.
ft.obased onLa ceiling height 1of twenty feet.
As there is no acoustic tile. dropped ceiling in node A, the entire height of the room has been considered.
~
t
- The' surface area.of wall A is approximately 1,373.4 sq.-ft.
(68.67 ft. by 20-ft.).
-i
- The surface area of_ wall section C is-approximately 440 sq.
- ft. (22fft'. by 20 ft.).
-Wall sections'D,.E, and F/are partial height structures the lower portions of which constitute. boundaries of the SS office and the.WCC.
As those volumes are considered 1
dead-ended, the lower _ portions of the north and east
.i exterior walls are not credited for heat renoval.
The height of interior wall sections D, E, and-F is 13.33 ft.-
_per1 drawing FA-21G, Rev. 2.
i The' surface area (upper portion)of the east wall, section-H, i
is approximately 360 sq. ft..(54 ft. by 6.67 ft.).
=l
([)
The surface area of the north wall, section G, is approximately 454 sq. ft. (68 ft. by 6.67 ft.).
k I
- L
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[pg ATTACHMENT "B to KJV-89-25 ggg CONTROL ROOM ANALYSIS Th'e surface area of the ce! ling is approximately 5,168 sq.
ft..(68 ft.-by-76 ft.).
The total surface area is:
AREA (SQ. FT.)
WALL (A) 1,373 WALL'(B) 1,360 SECTION-(C) 440-SECTION.(H) 360
- SECTION (G) 454 CEILING 5,168 9,155 HEAT INPUTS-The heat gain (62 kw)-extracted from SWEC Calculation No.
-Q 70-5 is not-consistent (and-less conservative) with the more detailed heat; input evaluation given in Calculation No.
70.4.
The total design heat load specified in the 70-4 calculation is-261',400-Btu /hr (76.5 kw).
Per Calculation 70-4,-transmission gains into the control room'were determined as follows:
- Room Temperature:
75'F Outdoor Temperature:
93*F
" Indoor" Temperature: 104*F
-AREg)
WALL-.
(FT
-u T
Btu /hr NORTH.
1350 0.305 30
. 12,330
. SOUTH 1350-0.305 50 20,600 WEST.
1490 0.305 30 13,600 EAST 1490 0,350
-22
- 11,470 CEILING 5030 0.130 45 29,400
- For non-air conditioned areas 87,370 - 25.5 kw
=
It should be noted the above heat inputs consider gains into
-both the WCC and SS office, areas previously designated as dead ended.
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00 00
/#
I ATTACHMENT
'B" to KJV-89-25
?di'?
0'
$~]/[0Q CONTROL ROOM ANALYSIS Per drawing FE-1AH, Rev.
in the control room is 4.6 KW (i5,700 Btu /hr).7, the emergency DC light Per SWEC Calculation No.
equipment heat load is 19.5 KW (66,500 Btu /1r).70-4, the normal o)era A
a SB0 event is approximately 17.5 KW corresponding to a amp draw (at 125 VDC) from each of the two station batteries.
This load is shared between the control room and the relay room.
For purposes of thic calculation, it is conservative to assume fifty percent (50%) of the DC powered load is in the control room.
O O -
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we..., .~. ~,oeo, O /#dow,d i To W Ca b. 96-0 A F-og M NewYorkPower Memorandum n 1p$ August 1989f Authonty U .J KJV 89 38 Mr. Ahmad Faramani Devoarve, Ud. 180 Lincoln Stteet Bouon. Massachusetts 02111 Deat Mr. Paramani, Attached please find the additional information requested in your letter no. 8904)l/AF regarding inputs into the crescent area and main steam tunnel /drywell entrance heatup analpes under SBO conditions, if you have any questions or comments, please contact me at 914 68. 6314. K. J. Vehstedt (_) Nuclear Operations & Maintenance cc R. H. Lauman, Jr. P. W. Brorenich RMS.WPO.11 i O
o % led i +o $9-3hF.Ob ATTACllMENT TO KJV-89 38 O=* f fits 1 Piping and equipment lasulation in the dominant areas of concern is designed to ensure a madmum surface temperature of 140 F. Item 2 i SWEC calculation 67 2, copy artached, usumed an laitial tunnel temperature of 130 F and predicted an inner l . surface temperature of 108 F behind the three inch insulation. Dimension of the drymell entrance area are t given la drawings FP.278.Rev.*1 and FP.27A.Rev.14, copies attached. Steam tunnel data is found on drawings l FP.27C.Rev.10 and FC.2B.Rev.3, copies attached. - ( Items 3 and 4 L -SWEC calculation 64 gives the crescent area volume as 198,400 cu. ft. based on a floor area of 4,780 sq. ft. and 1 a height of 41.5 ft. No details of the floor area calculation ane provided by SWEC. Per drawing FM.1F.Rev.13, i the inner radius of the crescent is approximately 74.5 ft. to the centerline of the reactor. Approximating the ) outer radius to be 97 ft. (see attached sketch) and the torus to be 180 degrees, yields an outer wall area of l 12,633 sq. ft. and an inner wall area of 9,700 sq. ft. r Per SWEC calculation 664 the total heat input to the reactor building due to HPCI operation is 19.4 K Bru/hr, excluding piping. HPCI piping in the crescent area is shown on drawings FP47A.Rev.17, FP-67C.Rev.11, FP. 67D.Rev.12, and FP47E.Rev.12, copies attached. eM & ff,, el h>ig a j t t i h } T l 5 I i ? l L -l l I l I O i i F r r 5 .m
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$ NON-PERMANENT O g (3n me, i q; ir
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sma. sura, O' Bs%* %.u ke wun o,'lli rY,N,T? October 30,1989 DLNYPA 8910 03/AF Mr. Kenneth Vehstedt New York Power Authority 123 Main Stnet White Plains, New York 10601
REFERENCES:
i [a] Letter from A. Paramarzi (Devonrue) to K. Vehstedt (NYPA),
Subject:
" James A.-
FitzPatrick. Station Blackout Room lleatup Analysis", dated April 18,1989 [b] Letter from A. Paramarzi (Devonme) to K. Vehstedt (flYPA),
Subject:
" James A.
PitzPatrick. Station Blackout Room ileatup Analysis", dated August 1,1989 l O [c] Memorandum from K. Vehstedt (NYPA) to A. Faramarzi (Devonrue),
Subject:
" James A. FitzPatrick. Station blackout Room Heatup Analysis", dated August 28, 1989~
SUBJECT:
James A. FitzPatrick Station Blackout Revised Crescent IIcatup Analysis i
Dear Ms. Vehstedt:
We have completed the necessary soom heatup analysis in support of James A. FitzPatrick Plant station blackout (SBO) compliance. In April 1989 we performed room heat up analysis for the Crescent Ana, Steam Tunnel, Relay Room and the Control Roorn. The analysis results were transmitted in Reference [a); That Reference also included a brief l' description of the analysis methodology and assumptions made in performing the room heatup analysis as well as a list of additionalinformation required to reanalyze some of these rooms by considering a more realistic heat dissipation rate. O F l i
DLNYrA 8910 03/A DEvohuUE Subsequent to receipt of your input, Reference [b] prc vided the final analysis results for the d, Control and Relay rooms along with a copy of the conesponding Devonrue calculations. Reference [c] provided additional information and clarification for the crescent area. Specifically the wall surface area, maximum insulation surface temperature, and the llPCI pipe length were adjusted based on information provided in Reference [c] and plant drawings. Utilizing the guidelines of NUMARC 87-00, the revised Crescent area analysis predicts a maximum room air temperature of 123 P for a station blackout duration of four hours. As we discussed the steam tunnel is not a dominant area of concern. The only safe shutdown equipment of concem are a number temperature switches that could inadvertently isolate the steam lines to llPCI or RCIC systems. De safety function of these switches are to isolate the llPCl/RCIC steam lines on high area temperatures subsequent to a high energy line break. As you indicated, JAF safe shutdown procedures require manual by-pass of these isolation switches to ensure proper operation of IIPC1/RCIC during a SBO. Derefore, there is no need to revise the room heatup analysis for the steam tunnel. All room heatup analyses are documented in Devonrue Quality Assured calculations. There (] are separate calculations for both the original temperatures supporting the April 17,1989 SBO submittal as well as the revised and more realistic temperatures reported here. In Reference [b] we transmitted a copy of five calculations. I have enclosed a copy of the revised Crescent calculation for your files. As we recently discussed the NRC is in the process of issuing a new Generic letter on station blackout requiring licensees with a response as to wether they have followed the guidelines of NUMARC 87 00 and RO 1.155. I have enclosed a copy of the draft generic 1ctter for your information. NUMARC and the station blackout information clearing house feel that the examples cited in this document are plant specific and are not of a generic nature and therefore there is no need for issuing a generic ktter. We will keep you infonned of any new developments on this issue through the SBO clearing house. This letter completes the requested scope of services to perform room heatup analysis in support of JAF station blackout compliance. We appreciate the opportunity to provide our services to you and your organization. We look forward to continuing our association. AV 2
- - - - - - - - ~ ~ - - - - - DEU DLNYPA 0 03/AF %j; -) ? ' If you have any questions or comments please do not hesitate to contact me. I 1% lp,7f 'j] to seeing you on Wednesday, November 1,1989. 1 Very T Yours i/ ' ' /W//bWf Ahmad Faramarzl, PE
Enclosures:
Devonrue QA Calculation 89 JAF-06 Draft SBO Generic 1.ctier Y L .L O 3 4 . -6,J.:~..
I Attachment IV to JPN 91049 i i P 1 I
- Rotay Room Hoatup Analysts
- i Calculation 89 JAF 05 Dated i
June 23,1989 4 Now York Power Authority Jamas A. FitzPatrick Nuclear Power Plant
O 'O A i Devonrue Calculation Cover Sheet I Rev 0.0 i 3 i Project Number NYAt/7Af ( C A t e, # - 9 % SA f *
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- > NewYorkPower tsf Authority W W -D-MAY 30, 1989 KJV-89-25 Mr. Ahmad Faramarzi Devonrue, LTD.
'180 Lincoln Street Boston, liassachusetts 02111
Dear Mr. Faramarzi:
SUBJECT:
JAMES A FITZPATRICK NUCLEAR POWER PLANT STATION BLACKOUT ROOM HEATUP ANALYSES The Authority has reviewed your transmittal 8904-01/AF dated April 18, 1989, concerning predictions of maximum steady state tecperatures in selected plant areas under station blackout conditions. Due to the predicted temperatures being significantly higher than expected in the control room and relay room, NYPA has concentrated on the assumptions and methodology ,q employed for those rooms. Our detailed comments and observations V are attached to this letter. If you have any questions or comments, please contact me at (914) 681-6314 Very truly yours, K. J. VEHSTEDT OPERATIONS & MAINTENANCE-BWR KJV:mac cc: R. H. Lauman, Jr. J. A. Gray, Jr. P. W. Brozenich RMS-WPO-11 O i w .--__._m.__m-____m ___u__,__,___
ATTACHMENT "A" TO KJV-89-25 V t/ $9- / r_- G RELAY ROOM ANALYSIS O V0LUME 0 Per drawing FA-16A, Rev. 16, the principle dimensions of the relay room are 76 feet (from mark 9 to mark 12 less two foot thickness of the north wall) and 66 feet (from mark G to mark C) for a floor area of 5,016 sq. ft. Per drawing FA-18B, the height of the room is from floor elevation 284'8" to the control room floor 300'0" less the 6 inch thickness of the floor for a height of 14.83 ft. 3 The resultant uncorrected volume is 74,402 FT. For calculational purposes assume a 10% volume reduction to account for structures and equipment, or a net free volume of 66,962 cu. ft. HEAT INPUTS The referenced SWEC calculation, No. 70-25, assumed normally operating (heat) loads from lighting and equipment only, no transmission gains being considered. That calculation is not applicable to these station blackout analyses. Per SWEC calculation No 70-6, the following data and O assumettone were used in aeterminins tran==iseion seine into the relay room for sizing the HVAC system: Room Temperature: 75*F Outdoor Temperature: 93*F " Indoor" Temperature: 105'F* ARE4 WALL (FT') u T Btu /hr WEST 1155 0.305 30 10.550 NORTH 1047 0.305 30 9.560 SOUTH 1047 0.305 50 15.960 EAST 1155 0.350 22 7.750 FLOOR 5030 0.360 30 54.200 TC6'lU = 28. 7 kw
- For non-air conditioned areas The SWEC estimate of the transmission gain, 28.7 KW, should I
be compared with the initial gain predicted using the NUMARC 87-00 Model (i.e., when the room is at 75*F). Per drawing FE-65B, Rev. 10, emergency lighting in the relay g room consists of one lamp fed from lfghting panel EADCl (gowered from the "A" station battery) and five " Appendix t R battery-backed lamp pairs. _ _ - _ _ _ _ _
~ V3/3 ' ATTACHMENT "A" TO KJV-89-25 T#1-O AF 0 ' fl1 RELAY ROOH ANALYSIS Per SWEC Calculation No. 70-6 the normal (operating) ecuipment heat load in the relay room is 14 kw. Assuming an ac,ditional 10% load for margin, the equipment load considered was 52,600 Btu /hr (15.41 kw). Cop'ies of the following drawings are attached for your review / records FA-16A, Rev. 16 FA-16B, Rev. 17 FA-16C, Rev. 6 FA-18B, Rev. 4 FE-65B, Rev. 10 n v i O l
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Attachment V to JPN 91-049 " Plant Coping Capabilities Under Station Blackout Conditions per NUMARC 87-00,* Miscellaneous Calculation JAF 89-048 Dated September 20,1989 New York Power Authority James A. FitzPatrick Nuclear Power Plant
(T O l V V .e-h,u c ia Mod. (or ID) No jQ p, g ~ Cal Set. No. A J#tES A. FITZPATRICK Toti. No. Calc. CALCULATION CONTROL SHEET Sheets M SYSTEM /Meous QA CAT. 7~ ~ SUBJECT S A u 7' $ is Pio G- $_APAS/uTY us)DE2 37M 71oa 0.)(cLL7" codosnecs PEA A/UMARG W-cc PROBLEM STATEMENT /0BJECTIVE/MEDIOD DL4045 TRATE eA /%d/ 74' 76 doPL tat ~r)/ >4 AaR t/cc/R 37A' %d McA;'Ct/ 7" EVED7~ LLS/^)G- ~7~+ff /YE7$* oDCLC&Y' &) VEA /O WOfAM D - QO, SEc 7?cD f DETAILS OF ANALYSIS (DESIGN INPUTS, ASSUMPTIONS, COMPlTTER TYPE - CODE - PROGRAM, ETC.) 0 7kR A/uMARG. 8 9 -00, "n:'E ecPH3& A55E>5so~ FEM SCUSES ou F'u'E 7c~ Ptes, E4cdos:~ tai /,ct/15 Accessseh W As PART ef' n//s cAj cy;.A7;cy. 7~+c,C/VL ~2 P/d5 AAE)Q) OS ~I~ /N v'E+37eA.Y'fWTA 7702 /$A WERY $AA4GJ7Y, (3) (oMPCF3$$E A/R, (4) EFFEe75 cf J oss of VcD77sA77oM, M AJD (S.) eosrsuJasar isoM rm.
SUMMARY
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REFERENCES:
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