ML20134M234

Responds to NRC Re Resolution of Spent Fuel Pool Safety Issues & Issuance of Final Staff Rept & Notification of Plans to Perform plant-specific,safety-enhancement Backfit Analyses

ML20134M234
Person / Time
Site:	Point Beach
Issue date:	11/13/1996
From:	Link B WISCONSIN ELECTRIC POWER CO.
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
TAC-M88094, VPNPD-96-094, VPNPD-96-94, NUDOCS 9611220283
Download: ML20134M234 (11)

Text

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Wisconsin Electnc POWER COMPANY 231 W Michigan.PO Box 2046. MAvoukee.WI 532o12046 - (4141221 2345 VPNPD-96-094 November 13,1996 Document Control Desk i

US NUCLEAR REGULATORY COMMISSION Mail Station PI-137 Washington, DC 20555 Ladies / Gentlemen:

DOCKETS 50-266 AND 50-301 RESPONSE TO RESOLUTION OF SPENT FUEL STORAGE POOL SAFETY ISSUES _;

LSSUANCE OF FINAL STAFF REPORT AND NOTIFICATION OF STAFF PLANS TO PERFORM PLANT-SPECIFIC. SAFETY ENHANCEMENT BACKFIT ANALYSES POINT BEACH NUCLEAR PLANT. UNITS 1 AND 2 (TAC M88094)

This letter is in response to a NRC letter dated September 19,1996, associated with the resolution of spent fuel pool (SFP) safety issues. The Point Beach Nuclear Plant is a multi-unit site with shared SFP systems and structures where an open path exists from the SFP to areas housing safe shutdown equipment. Wisconsin Electric was requested to provide information to the NRC staffon plant design characteristics, their safety significance, and existing protections provided by administrative controls or other means to evaluate the potential for loss of SFP cooling and the efTect of SFP elevated temperatures on systems needed to support shutdown of an operating reactor.

In the following discussions, the " time to boil" is used in place of the " time to reach an elevated temperature" based en heat transfer characteristics below and at the saturation temperature. Following a loss of SFP cooling, the decay hea. from the stored spent fuel primarily raises the SFP bulk water temperature. Evaporative cooling (from SFP surface water below its saturation temperature) and heat radiation do not transfer heat as efliciently as bulk boiling (at a temperature of 212 F), so relatively little heat or water vapor will be lost from the surface of the SFP until the water reaches the boiling point. When bulk boiling begins in the SFP, nearly all of the decay heat is transferred ofTthe surface of the SFP in the form of saturated water vapor at 212 F, although some heat will also be lost through the SFP structure. Therefore, no significant heat or water vapor is transferred to the area surrounding the SFP until the SFP coolant temperature reaches the bulk boiling point.

The ability to safely shutdown an operating reactor following a limiting loss of SFP cooling scenario has been evaluated based on the time to boil and the effect of the heat and water vapor generated by the boiling on the functional capability of safe shutdown equipment in the vicinity of the SFP. These two factors and the design characteristics of the SFP cooling system with regard to the potential for a complete loss of SFP cooling are addressed in the following sections. l 9611220283 961113 PDR ADOCK 05000266- /7C)D A lg/j h~vvux P PDR-A subsmqonnsmaswEneyfonwMim

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l Document Control Desk -l November.13,1996 j Page 2 -

i SFP Time to Boil Follow'mg Loss of SFP Cooling I Wisconsin Electric has calculated the time to boil following reactor shutdown for a range ofinitial L SFP temperatures [ReE 1] and has concluded that sufficient time exists for plant personnel to take

! corrective actions in accordance with abnormal operating procedures in the event of a complete loss

of SFP cooling. The time to boil calculation is based on the maximum heat load in the SFP which  !

j occurs following a full core ofiload (121 assemblies) that fills the pool to its maximum design capacity (1,502 assemblies). The SFP cooling system is designed to maintain SFP temperature below 120 F-l . with two cooling trains operating [Ref 2]. However, operators monitor and log SFP parameters (e.g. pool cooling flow, temperature, level, pump discharge pressure) each shift and administratively

- control SFP temperature between 70 F and 90 F including times when a full core has been offloaded

[ReE 3]. If SFP temperature rises to 120 F, a high temperature alarm in the control room would also notify operators that SFP cooling is lost [ Ret 4].

Using the guidelines for SFP cooling in the Standard Review Plan [Ref. 5], the maximum decay heat in  !

the SFP includes a full core ofiload completed 150 hours0.00174 days <br />0.0417 hours <br />2.480159e-4 weeks <br />5.7075e-5 months <br /> (6.25 days) following reactor shutdown.

i Where a loss of SFP cooling occurs immediately following this limiting core ofiload with an initial SFP

temperature of 120 F, the minimum time to boil is about 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> (see Attachment _1). For an initial i temperature of 90 F, the time to boil is about 14.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> after a 6.25 day core offload.

, These SFP boiling times are conservative. Ambient heat losses with the SFP temperature at about 80 F -

are accounted for in the calculation, but no credit is taken for the increased ambient losses from the SFP l as it heats up. Evaporative cooling and the SFP concrete structure heat sink would provide additional

ambient passive heat losses. Additional cooling of the SFP is also provided from the ventilation system

above the SFP which operates continuously. The drumming station supply fan delivers outside air through ductwork to various areas around and above the SFP, and the SFP exhaust fans draw over 35,000 cubic feet of air per minute across the surface of the SFP which is discharged to a vent stack; 4

These additional ambient losses would increase the actual time to boil from that determined in i

Attachment 1 and minimize the water vapor lost to surrounding equipment spaces.

l The time assumed in the Standard Review Plan for a full core ofiload (6.25 days) is also conservative 4

when compared to refueling outage experience at Point Beach where the time from reactor shutdown to completion of core ofiload is planned to be about 9 days. A recent survey of outage windows at

Westinghouse plants (including Point Beach) with refueling outage leading indicators shows that the j average time for the six surveyed plants to ofiload a full core is 10.2 days. The time to ofiload a full core at Point Beach will likely remain about 9 days for future outages. Additionally, before any fuel is

removed from the reactor core, a calculation of expected decay heat load and SFP cooling system

capacity is performed to ensure that the SFP cooling system design and licensing bases are met [ Ret 6].

Assuming that it takes 9 days for a full core ofiload rather than 6.25 days would add at least an hour to

, the times to boil depending on initial SFP temperature.

4

l l . Document Control Desk i

i November 13,1996 i s Page 3 i

The NRC staff used a time of 4 to 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> as a criterion for the SFP to reach an elevated temperature l j

~

as a design characteristic that could increase the probability that systems necessary for shutdown of an j operating reactor could fail. Under the most limiting conditions (120 F initial SFP temperature with  !

core oilload occurring 6.25 days aRer reactor shutdown), the calculated time to boil is 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />. For a situation representative of Point Beach refueling outages where the core is offloaded 9 days aner I reactor shutdown and the SFP temperature is 90 F, the calculated time to boil is 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />. In the event of a complete loss of SFP cooling, sufficient response time exists for plant personnel to take corrective actions in accordance with AOP-8F, Loss of Spent Fuel Pool Cooling [Ref. 4). These actions would i include: (1) restoring spent fuel pool cooling water flow, (2) restoring service water, (3) establishing 3 alternative cooling if possible, (4) maintaining water level and boron concentration, (5) maximizing ambient losses (e.g. with SFP ventilation system), (6) and making necessary repairs to restore SFP

! cooling.

SFP Boilinu Effect on Safe Shutdown Eauioment The heat and water vapor from SFP bulk boiling will not affect the operability of any safe shutdown l equipment located in areas housing safety systems with an open path to the SFP based upon the physical configuration of the SFP and the Primary Auxiliary Building (PAB). The SFP (including the

~

4 transfer canal) is a large reinforced concrete, open topped structure, approximately 25' wide (east / west), 75' long (north / south) and 42' deep, lined with 3/16" stainless steel plate. The pool -

, structure consists of a 5' 8" thick reinforced concrete floor slab and 5' thick reinforced concrete walls.

s The SFP structure is located in the large' central open bay area of the PAB adjacent to the truck access bay (26' elevation) and about 25' from the west end of the PAB. The bottom of the SFP is at the 26' elevation and the top of the SFP is at about 66'. The roofof the PAB is at the 110' elevation and the floor forming the 46' elevation extends from the east end of the PAB to the SFP. This central area of 4 the PAB above the 46' floor, the SFP, and the truck access bay is essentially open to the rooflevel and can be approximated by a volume 200' long (east / west),75' wide (north / south), and 60' high; this open 1 bay has a volume of about 900,000 cubic feet which is over ten times the volume of the SFP structure.

PAB rooms with a direct open path to this bay area are located on the 46' and 26' elevations east of the

. SFP. Attachment 2 shows the physical layout of the SFP within the PAB.

i In the unlikely event that corrective measures were unable to restore cooling to the SFP, the effect of

the heat and water vapor from bulk boiling on safe shutdown equipment in the vicinity of the SFP can

be conservatively approximated by using previous evaluations performed for harsh environments in the

. PAB. An engineering evaluation has determined that a heating steam system pipe line break in the

PAB would result in a high temperature and humidity (i.e. harsh) environment in the immediate vicinity l of the break. A 6 inch heating steam pipe containing saturated steam at 30 psig and 274 F passes

! alongside the SFP heat exchangers (HX-13 A/B) and pumps (P-12A/B) which are located east of the SFP and north of the new fuel storage area. A break in this pipe would release approximately the same

heat (BTU / time) and water vapor (ib./ time) as bulk boiling of the SFP. The environmental conditions in the vicinity of the SFP produced by SFP boiling are therefore bounded by the effects of a break in i this heating steam pipe.

i s

l 1

a Document Control Desk

+ November 13,1996 Page 4 j . Safe shutdown mechanical equipment and electrical equipment environmentally qualified (EQ) for l high temperature and humidity are not considered susceptible to a harsh environment and would remain functional following a heating steam pipe break or boiling in the SFP. The vicinity of the harsh environment created by the heating steam line break (or SFP boiling) isjudged to only include equipment on the same elevation and in the same or adjacent confmed area as the steam line break

. (or SFP boiling). Electrical equipmer.t which is not included in the EQ program or only qualified for -

! radiation would be affected by the heat or water vapor from a heating steam pipe break or SFP bulk i- boiling iflocated in the vicinity of the harsh environment.

l The evaluation deiemi-d that no safe shutdown equipment in the open bay area (46' elevation) around the SFP will be renered inoperable following a heating steam line break. Safe shutdown equipment which may be vulnerab e to harsh environments produced by steam line breaks elsewhere j in the PAB are located outside the vicinity of the SFP (e.g. the 480V safeguards motor control centers { IB-42 and 2B-42} on the 26' elevation and the safety injection pump {P-15A/B} motors,

, component cooling water pump {P-!! A/B} motors, and component cooling water instrumentation on -

! the 8' elevation). An open path exists through stairwells and doorways from the top of the SFP to this equipment on the 8' and 26' elevations located about 150' east of the SFP. However, the harsh environment produced by a heating steam line break at the SFP or SFP bulk boiling would be greatly

dissipated by the large volume of the open bay of the PAB. The ventilation systems operating above  !

i the SFP and throughout the PAB would further minimize the spread of heat and water vapor from the )

vicinity of the SFP. No significant increase in temperature or humidity is expected in areas which are

more than 40' below and at a distance of about 150' from the SFP. Therefore, the heat and water i vapor produced by bulk boiling in the SFP would not affect the operability of any safe shutdown equipment in the PAB.

l SFP Cooling System Canability and Reliability

- The SFP cooling system consists of two separate, but cross-connected, cooling trains with a common

suction and return header, each having an identical heat exchanger, HX-13 A/U, and pump, P-12A/B j (see Attachment 3). A pump and/or heat exchanger can be isolated while maintaining one train of i SFP cooling. If necessary, the 'A' pump can be cross-connected with the 'B' heat exchanger or the

'B' pump with the ' A' heat exchanger. Water from the pool is pumped through one or both heat i exchangers for cooling and returned to the pool. Service water provides the heat exchange medium i for removal of decay heat. Borated makeup water to the SFP is available from the boric acid blender, refueling water storage tank (RWST), and holdup tanks while non-borated makeup can be provided 4

from the reactor makeup water, demineralized water, service water, or fire water systems.

Each SFP heat exchanger has a nominal heat removal capability of 15.5E+06 BTU /hr; with both SFP trains in operation,28.2E+06 BTU /hr can be removed [Ref. 2]. One train of SFP cooling is capable l of removing the nominal heat load from a 1/3 core ofiload which fills the pool to 1,502 assemblies (11.5E+06 BTU /hr) and maintaining pool temperature below 120 F. For the maximum design heat l

i i

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i j Document Control Desk November 13,1996

.Page 5 1

i

l. load (23.9E+06 BTU /hr) where a full core offload fdis the pool, two trains of SFP cooling will maintain j pool temperature below 120*F; if one train is unavailable, the operable train can remove this heat and

maintain temperature below 145 F.

l The SFP cooling and service water (SW) supply systems are designated safety-related (Refs. 7 and 8].

, The SFP cooling system was constructed in accordance with ASME III, Class 3,1974 Edition, Winter

,. 1975 Addenda [Ref. 2]. The SFP pumps receive power from independent 480VAC safeguards buses  !

i l each of which can be supplied from a normal or alternate emergency diesel generator should station j or offsite power be lost. Motor operated valves (MOVs) in the service water discharge froin each SFP i heat exchanger likewise receive power from independent 480VAC safeguards buses. In the event of l 4

a single active failure to the SFP pumps or SW MOVs (mechanical or electrical), one train of SFP j

cooling would remain operable. The redundancy and diversity provided by four emergency diesel )

l _ generators and a gas turbine generator ensures that in the event of a loss of station and off-site power, i power to safeguards buses is quickly restored and available for SFP cooling._

Prior to each refueling outage, an outage safety review is performed to assess the shutd' own risk to nuclear plant safety by considering the redundancy provided to six key safety functions: reactivity, core .

. cooling, power availability, containment, inventory, and SFP cooling [Ref. 9]. During the refueling l outage, an assessment of shutdown risk is conducted by shift outage coordinators (SOC) at least once l ' per shift or when a significant change in the outage schedule affects the condition of a key safety j- function. These safety assessments are communicated to all plant personnel through shutdown safety assessment checklists provided to on-shift watchstanders, outage planning meetings, shutdown safety

assessment boards throughout the plant, and electronic E-mail bulletins.

The safety assessment of SFP cooling is an evaluation of the status of power supplies to the SFP

pumps, the availability of the SFP heat exchangers and service water supply, and a determination of

! the time to boil in the event of a complete loss of cooling. Heightened awareness to maintain the i availability of SFP cooling equipment is provided by designating protected equipment when equipment i redundancy is reduced. Work on protected equipment may be minimized or prohibited depending on 1

the degree of equipment redundancy available and the overall plant safety status. To minimize the potential for loss of SFP cooling from a fire which could affect both trains of SFP cables and pumps,

fire zones for sensitive SFP equipment have been identified. Tours by the SOC and administrative controls on transient combustibles effectively minimize the risk of a fire in these fire zones; backup

. equipment for SFP cooling is designated in the unlikely event of a fire which disables both trains of normal SFP cooling.

[ . Based upon the calculated long times to boil, the demonstration that no safe shutdown equipment would be adversely impacted from the heat and water vapor produced by SFP bulk boiling, the design l

j reliability of the SFP cooling system, and the procedural controls to maintain redundant SFP cooling,

! the risk and consequences of elevated temperatures in the SFP from a complete loss of cooling are not

significant for Point Beach.

Document Control Desk November 13,1996 Page 6 We would be pleased to answer any questions you may have.

Sincerely, ,

B Lii Vice President

. Nuclear Power PGK cc: NRR - PBNP Project Manager (Linda Gundrum)

NRC Resident Inspector -

. NRC Regional Administrator ,

PSCW -

References:

1. Calculation N-93-048, Time to SFP Boiling Following a Loss of SFP Cooling

2. FSAR 9.3, Auxiliary Cooling Systems

3. Point Beach Nuclear Plant Auxiliary Building Shift Log, PBF-2031, Rev 26,5/14/96

4. Abnormal Operating Procedure (AOP)-8F, Loss of Spent Fuel Pool Cooling

5. NRC Standard Review Plan, NUREG-0800, Section 9.1.3 III.l.h.iii.

. 6. Refueling Procedure (RP)-lC, Refueling Initial Conditions

7. QA Classification Diagram, Auxiliary Cooling System,110E018 GLD Sh. 4

8. QA Classification Diagram, Service Water, M 207 GLD Sh. 3

9. NP 10.3.6, Outage Safety Review and Safety Assessment Attachments:

1. AOP-8F, Table 1, Time to Boil - SFP

2. Equipment Location Plans, FSAR Figures 1.2 2,1.2-3, and 1,2-6 '

3. QA Classification Diagram, Auxiliary Cooling (Spent Fuel Pool) System,110E018 GLD Sh. 4 3

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