ML20235J541

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Forwards Response to Generic Ltr 87-12, Loss of RHR While RCS Partially Filled. Revs 0 to Corrective Maint Procedures 1-6RC-lT-TEMP-1C-3I, Temporary RCS Level Indication for Refueling - C Loop, & 1-6RC-LT-TEMP-1A-3I Encl
ML20235J541
Person / Time
Site: Beaver Valley
Issue date: 09/21/1987
From: Sieber J
DUQUESNE LIGHT CO.
To:
NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
Shared Package
ML20235J542 List:
References
GL-87-12, NUDOCS 8710020007
Download: ML20235J541 (24)
v • d • e


Text

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g h 1ppcc (412) 393-6000 One Oxford Centre 301 Grant Street Pittsburgh, PA 15279 S ptember 21, 1987 U. S. Nuclear Regulatory Commission-l Attn: Document Control' Desk washington, DC 20555

Reference:

Beaver Valley PowercStation, Units No. 1.and No. 2 l

BV-1 DocketsNo. 50-334, License No.-DPR-66 BV-2 Docket No. 50-412, License ~No. NPF-73 Gentlemen:

Attached is our response' to; items 1-though 9 as requested by Generic. Letter 87-12; Loss of Residual Heat Removal (RHR) While the Reactor Coolant System (RCS) is Partially Filled.

Please note that this submittal provides information addressing both Beaver Valley Unit 1 and Unit 2 when the reactor coolant system is to be drained to loop level. . When the reactor. vessel head is to be removed for refueling the vessel level'is maintained below the' reactor -vessel flange but well above the level of the reactor' coolant leops. Due to the level of detail of the questions, we have broken each question into parts in order to provide as detailed and complete a response as possible.

If you have any questions regarding this response, please contact my office.

Very truly yours,

-[

. S ebe,r Vice President, Nuclear cc: Mr. F. I. Young, NRC Sr. Resident Inspector (Unit.1) i Mr. J. Beall, NRC Sr. Resident Inspector (Unit 2) l Regional Administrator, Region 1 Mr.-Peter Tam, Project Manager ,

VEPCO moTeR f@a*

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.4' COMMONWEALTH OF PENNSYLVANIA) .

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) SS: j COUNTY OF BEAVER. '). {

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.t On .this o dib day of , j f hMX vff , 1987, before. me, A u /1 /// Y d f h vo),. a Notary Public in and:for said y Commonwealth and County,' personally' appeared J. D. Sieber, Who being l duly sworn, deposed, and said that- (1). . he is.Vice President'of Duquesne Light, -(2) he is duly authorized to.' execute and file' the-foregoing Submittal on-behalf of'said Company, and-(3).the statements-set forth in the Submittal are true and correct to the best of his knowledge, information and belief.

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e ATTACHMENT l

RESPONSE TO GENERIC LETTER 87-12 i I

I j

QUESTION 1 l

I A. A detailed description of the circumstances and conditions under which your plant would be entered into and brought through a drain down process and operated with the RCS partially filled, including any interlocks that could cause a disturbance to the system.

l

Response

i Past operating experience at Unit No. 1 has shown that operation l with the RCS drained to mid-loop has been limited to certain maintenance and inspection activities on RCS components between the loop stop valves and the reactor vessel. As shown in the ;

Unit 1 UFSAR Figure 4-1 and the Unit 2 Figures 5.1-2, 5.1-3 and 5.1-4, a number of valves are located between the reactor vessel and the loop isolation valves and may only be inspected or have maintenance performed on them when the RCS is drained to mid-loop. The RCS loop isolation valves and loop by-pass valves may also require the RCS to be drained to mid-loop for corrective maintenance procedures to be performed. Additionally, leaks on instrument lines on the RCS which cannot be isolated or work on thermowells may require draining to mid-loop to implement repairs.

There are certain administrative or technical specification actions taken to preclude a disturbance to the RCS. This includes removing the accumulator outlet valve block jacks to prevent inadvertent accumulator injection and placing the pressurizer heaters in the " Pull to lock" position and hanging a caution tag to assure they remain inoperable. We are currently defeating the auto closure interlock of the RHR suction valves at low RCS pressures since a cold overpressure protection system or an open RCS vent is required any time the RCS temperature is below 275"F for Unit No. 1 or 350*F for Unit No. 2.

B. Identify the time required between full-power operation and reaching a partially filled condition (used to determine decay heat loads).

Response

Based on past experience we have determined that 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> is the minimum time required to reach mid-loop operation following full power operation.

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Attachment

  • ~

Response To Generic' Letter 87-12 j Page 2

c. Identify-requirements for minimum steam generator levels.

i

Response

l i

There are no current. requirements defining :a minimum steam I generator level .that is to be maintained while in a partially l filled condition. Steam generators could be in a dry or wet j lay-up condition. A steam generator will be maintained available' 1 for heat removal as discussed in response to Question 4.. With '

the conditions presented there, auxiliary feedwater flow'can be established within minutes.

D. Information regarding changes in the status. of equipment for ,

maintenance and testing and coordination of such operations while 1 the RCS is partially filled. l l

Response: -!

I The shift supervisor must authorize all activities that affect a )

change in equipment status by maintenance or testing. These.

activities are normally pre-reviewed during daily planning and j scheduling meetings to assure proper Coordination ~.. All l activities which have the potential to affect the RCS inventory 1 i

must be evaluated by the NSS prior to initiating 'such activities. During periods when the RCS is partially filled, a trend of RCS boron concentration- is also maintained so that changes in boron are identified.

Additionally, significant equipment which is out of service is identified on the ESF status board in the control room and l relevant flow diagrams are kept- current indicating system l status. During shift turnover, a turnover checklist is used to-L l

assist in the coordination of maintenance and test activities.

l E. Provide information identifying restrictions regarding testing, operations, and maintenance that could perturb the nuclear steam supply system (NSSS).

1

Response

The following instructions and precautions ara applied:

i

  • Anytime the RCS is partially drained, the Type C test I

personnel are notified so that any test involving a check valve as the only isolation point between the'RCS and the-penetration being tested will be suspended, i

e A shift supervisor's clearance is placed on all points that

! have the potential for inadvertent dilution of the RCS.

I l

l

Attachm:nt Responsa To Generic Letter 87-12 Page 3

  • Procedure precautions direct the operating staff to pay particular attention to any activity which could result in even small changes to RCS inventory.that could result in air binding the RHR pumps.

. Procedure precautions identify a list of activities the operating staff need to monitor for the possibility of inadvertent dilution.

l e Pressurizer vapor temperature and RCS temperatures must be less than 120"F.

. An appropriate vent path to the containment is established.

  • An RHR pump is in service at a reduced flow rate and a second is operable in standby with a caution tag on the control switch to prohibit starting until it is determined that the loss of the operating pump was not due to air / vapor binding. ,
  • A heat sink for the RCS is available at all times as described in response to Question 4.
  • Pressurizer heaters are in " PULL-TO-LOCK" and caution <

l tagged.

l . A shutdown margin of greater than 5% exists.

  • A boration flow path is verified available and caution tagged.
  • One charging pump and one LHSI pump are operable, or one charging pump is operable and one is available, or one LHSI pump is operable and one is available.
  • The reactor has been shutdown for at least 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

F. Provide information on the ability of the RCS to withstand  !

pressurization if the reactor vessel head and steam generator manway are in place.

j

=

t Response:  ;

By procedure, the RCS is required to be vented when in a drained down condition. At Unit 1, the RCS has a 3.14 square inch vent to the pressure relief tank which in turn is vented to the containment via a 3/4 inch vent valve. At Unit 2, the RCS is vented to containment through a 3.14 square inch vent. These RCS vents are required when the cold overpressure protection system is not available as discussed in Technical Specification 3.4.9.3.

N - - - _ . - - - - - _

Attachment Response To Generic Letter 87-12

' Page 4 G. Provide information identifying requirements pertaining to isolation of containment.

Response

Requirements are defined in the Technical Specification and are detailed in response to Question 4. Additionally our Abnormal Operating Procedure for loss of RHR with the RCS drained to the i mid-loop position requires isolating all penetrations that go directly to atmosphere if RHR cannot be restored prior to the core exit temperatures reaching 200*F. j H. Identify the time required to replace the equipment hatch should replacement be necessary. 1 Response-1 Under emergency conditions, it would be possible to secure the l equipment hatch with four bolts in less than two hours.

I. Identify requirements pertinent to reestablishing the integrity of the RCS pressure boundary.

Response

1 Our abnormal operating procedure addressing loss of RHR with the RCS drained to mid-loop requires the RCS pressure boundary to be reestablished, bringing the RCS to normal level in the pressurizer and pressurizing to approximately 300 psig with nitrogen or by drawing a steam bubble.

QUESTION 2 A. A detailed description of the instrumentation and alarms provided I to the operators for controlling thermal and hydraulic aspects of the NSSS during operation with the RCS partially filled.

Response

l j For drain down to the loop level, the following components are required to be available as an initial condition for procedure entry. This would also depend on the maintenance activities planned. Specific instrumentation is identified in the initial conditions of individual procedures.

(Unit 1)

  • Flow transmitters located in the residual heat removal (RHR) system return lines provide control room indication and alarm functions (FT-lRH-605, 0-8000 gpm-normal, 0-4000 gpm rescaled for mid-loop operation)

I I

~ _ _ - _ _ - _ _ - _ _ _ _ _ _ _ l

Attachment R:sponce To Generic Letter 87-12 Page 5 e A pressure switch located in the common pump discharge header provides alarm conditions in the control room (PS-lRH-603, 0-700 psig)

  • Temperature transmitters located in the RHR pump discharge line and system return line provide control room indication with an alarm.

(TE-lRH-604, 50-400*F; pump discharge header)

(TE-lRH-606, 50-400*F; header return)

  • Two temporary level transmitters with high and low level alarms, monitor RCS level, when level is being maintained within the loop, with level indication and recording in the control room.

A tygon hose and test gauge are installed to monitor RCS i

level during the latter phase of drain down 1

i e RHR pump ammeters are available in the Control Room

  • Core exit thermocouple indication is available if the l reactor vessel head is not being removed (0-2500*F on SPDS)

(Unit No. 2) - each train

  • Flow transmitters, located in the RHR return lines, provide control room indication and alarm functions.

1 (2RHS*FT605, 0-5000 gpm) l (2RHS*FT606, 0-2000 gpm)

(2RHS*FT607, 0-700 gpm; pump mini-flow) e Pressure transmitters, located in the RHR pump suction and discharge lines, provide control room indication and alarm functions.

(2RHS*PT602, 0-700 psig; pump discharge)

(2RHS*PT603, 0-700 psig; pump suction)

  • Temperature transmitters located in the RHR pump discharge line and heat exchanger; heat exchanger bypass common line provides control room indication and computer alarm.

(2RHS-TE-604, 50-400*F; pump discharge)

(2RHS-TE-606, 50-400 F; header outlet)

  • RHR pump motor current indication is provided in the control room (2RHS-Il21, 0-100 AMPS)
  • RCS level is indicated, recorded and will be alarmed to provide indication of RCS hot leg water level.

(2 RCS-LT-102, 0-180 inches)

1 Attachment Responce To Generic Letter 87-12 1

.Page:6 '

1 A temporary level transmitter will 1x! installed to add )'

redundancy prior.to draining to the mid-loop level.

e A gauge glas.s provides local vessel level indication. j L

l (2RCS-LG101) e Core . exit thermocouple indication is available if the reactor vessel head is not.being removed.  ;

l (0-2500'F on PSMS) .I l B. Describe- temporary connections, piping and instrumentation used 1 for this' RCS condition and the quality control process to: ensure j proper' functioning of, such connections, piping, -.and )

instrumentation, including.. assurance that they do not contribute.  !

to loss of RCS inventory or otherwisel lead to perturbation of the NSSS while the RCS is partially filled. j i

Response l Unit No. 1; the following procedures have been attached'for your review. These represent the temporary' connections used'for this RCS condition.

CMP l-6RC-LT-TEMP-1A-1I 1 CMP 1-6RC-LT-TEMP-1C-1I J CMP 1-6RC-LT-TEMP-1A-3I CMP 1-6RC-LT-TEMP-1C-3I 1 CMP 1-10RH-F-605-1I 1

Unit No. 2; there are currently no temporary connections required i to be implemented for Unit No. 2. We will install a temporary level transmitter to add redundancy for monitoring vessel level.

This will be installed prior'to draining to the mid-loop level, d C. Provide a description of your' ability to monitor RCS pressure, temperature, and level after the RHR function may:be lost.

Response

The following monitoring capabilities exist-for Unit No. 1:

e RCS temperature is monitored in the control room utilizing:

l-

a. wide range loop RTD's (accuracy dependant upon RCS level)
b. a full thermocouple map is printed every 10 l minutes or a minimum of two thermocouple l per quadrant is' logged every 10' minutes
c. the SPDS is also capable of displaying a full thermocouple map.
  • RCS pressure is monitored in the control room utilizing:

1

Attcchm:nt i RO2ponse To Generic Letter 87-12 1 Page 7 i

a. RCS wide range pressure transmitters (PT-lRC-402A, 0-3000 psig)

(PT-1RC-403, 0-3000 psig)  !

(PT-lRC-440, 0-3000 psig)

(PT-lRC-441, 0-3000 psig)

b. RCS narrow range pressure indication (PT-1RC-402B, 0-600 psig)  !
  • RCS loop and reactor vessel level is monitored as described in response number 2A above.

i The following monitoring capabilities exist for Unit No. 2: '

  • RCS temperature is monitored in the control room utilizing:  ;
a. Plant Safety Monitoring System (PSMS) which provides a core temperature display, average thermocouple temperature and hot and cold leg temperatures for each loop and is logged every 10 minutes.
b. A full thermocouple map which is printed out every 10 minutes or a minimum of two thermocouple per core  ;

quadrant is recorded each 10 minutes.

c. Wide range loop RTD's are recorded at 10 minute l intervals (accuracy dependent upon RCS level)

RCS pressure is monitored in the control room utilizing: i l

a. RHR pump suction and discharge pressure indication '

(2RHS*PT602, 0-700 psig)

(2RHS*PT603, 0-700 psig)

b. PSMS displays RCS wide range pressure
c. RCS wide-range pressure transmitter (2RCS-PT402, 0-3000 psig)

(2RCS-PT403, 0-3000 psig)

(2RCS-PT440, 0-3000 psig)

(2RCS-PT441, 0-3000 psig)

d. RCS narrow range pressure indicator (2RCS-PT441A, 0-700 psig) i

Attachment Response To Generic Letter'87-12

.Page:8:

  • RCS. loop and reactor vessel level is monitored as described in response.to number 2a above.

Question 3 A. Identification of all pumps- that can be used to control NSSS

-inventory; Both Unit 1 and Unit 2 are equipped with- dual function HHSI/ charging. pumps, Boric Acid Transfer Pumps and Low Head SI Pumps, all of which are capable of making up to the RCS. Each plant has three HHSI/ charging pumps with one.as an installed-spare . capable of being powered from-either of two emergency power.

supplies and =the ' remaining two powered from separate emergency power supplies. Each- plant has two Boric Acid Transfer. Pumps powered from separate- emergency power supplies and capable of~

supplying a four percent boric acid solution to the RCS.- Each y plant has two Low Head Safety Injection Pumps powered from I separate emergency. power ' supplies and. capable of injecting 2000 ppm borated water into the RCS from the Refueling Water Storage Tank. Pump parameters are as follows: j 1

Unit Pump Design Pressure- Design Flow I

1 and 2 HHSI/ Charging 2500 psig ~150 gpm-

  • 1 and 2 Boric Acid Transfer 100 psig- 75 gpm 1 1 Lo Head SI Pump 111 psig 3000 gpm .

2 Lo Head SI Pump 240 psig 3000 gpm ,

B. Pumps required to be operable or capable.of operation-(include information about such pumps that may be temporarily removed from service for testing or maintenance).

Response

i Minimim plant equipment operability requirements, when operating l with a partially filled RCS or during the approach to a partially j filled RCS are defined by the MODE 5 Technical Specifications for i both Unit No. 1 and No. 2. The requirements are the same for I each unit and are:

1. one charging. pump or one low head SI pump, or '

2.. a boric acid transfer pump lined up to a charging pump Depending upon the extent of maintenance work in progress in.the respective plant, redundancy would exist for each of these pumps ,

as described in response 3A above. With'the.RCS vented, makeup j can be provided by gravity drain from the RWST.

i l

Attachment Response To Generic Letter 87-12~

Page 9

c. Other pumps not included in the above.

Response

In addition to the above, each unit is equipped with a hydro' test pump capable of adding borated water to the RCS via the high head SI lines or adding borated water as make-up to the safety injection accumulators (three per unit). The Safety Injection Accumulators may be partially filled with borated water with the remaining gas space pressurized with nitrogen. The accumulators are normally isolated from the RCS with power removed from their respective motor-operated valves when the units are at a reduced RCS pressure.

D. Include an evaluation of the above item with respect to applicable Technical Specification requirements..

Response

Refer to our response to 3B above which reflects the requirements i of Technical Specification LCO 3.1.2.1 and 3.1.2.3. Also refer l to FIGURES 1 through 7 attached. These figures are operations surveillance logs for both Unit No. 1 and No. 2 and are maintained when operating with the RCS partially drained.

Administrative procedures require Initial Conditions to be met prior to procedural entry.

l Question 4 l

A. A description of the containment closure condition you require for the conduct of operations while the RCS is partially filled.

Examples of areas of consideration are the equipment hatch, personnel hatches, containment purge valves. SG secondary side condition upstream of the isolation valves (including the valves), piping penetrations and electrical penetrations.  ;

l l

Response i l For those occasions when the plant is in the refueling mode (MODE

6) while core alterations are in progress, both Beaver Valley Units 1 and 2 are required to maintain containment integrity per l

Technical Specifications (LCO-3.9.4) as follows: l LCO 3.9.4 The containment building penetrations shall be in i the following status:

l a. The equipment door closed and held in place by a 1

minimum of four bolts l b. A minimum of one door in each airlock is closed, and l

c. Each penetration providing direct access from the l

containment atmosphere to the outside atmosphere shall be either:

l t- _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ l

1 Attachm3nt j Reeponce To Generic Letter 87-12 Page 10

)

{

l. Closed by an. isolation valve,_ blind '

flange, or manual valve, or'

2. Exhausting at less than or equal to 7500 cfm through operable containment purge and 1 exhaust isolation valves with isolation times as specified in TABLE 3.6-1 to operable HEpA filters a charcoal adsorbers of the supplemental leak collection and exhaust system. J 4

There are no containment integrity Technical Specification l requirements during all other periods when the RCS is in a j partially filled condition in Mode 5. During these periods, we  ;

will maintain additional components available to assure adequate core cooling is maintained in lieu of additional restrictions on-containment integrity. In response to question 3, we identified l those components that are required to be operable to control RCS j inventory. This equipment included one charging pump or one low l head SI pump, or a boric acid transfer pump lined up to a charging pump. We will revise our mid-loop procedures which  !

control plant evolutions when operating with the RCS in a l mid-loop condition to increase the amount of equipment available. We will require one charging pump and one low head SI pump, or two charging pumps to be available or two LHSI pumps to be available to provide additional make-up capability to the RCS. These additional components will be available for manual ]

start in the event the operating components become inoperable and there is a need for makeup to the RCS. This configuration,  ?

manual start, is required to assure two charging pumps cannot l

. automatically start following a spurious SI signal because this l condition could lead to a violation of our 10 CFR 50 Appendix G limits.

l l

Additionally, we will require' that an alternate means of RCS decay heat removal be available in the unlikely event normal decay heat removal capability f.s lost. Normally, redundant residual heat removal (RHR) flow paths are available, however, we will revise our procedures to require one steam generator and its I associated steam flow path, a motor-driven auxiliary feedwater pump and its flow path with a source of water is available any time the RCS is in a mid-loop condition. This steam generator will permit reflux core cooling upon re-establishing a steam generator level in conjunction with RCS makeup and significantly delay any core uncovery while efforts to restore normal RHR are i being made. We believe that these commitments will enhance our l ability to assure adequate core cooling is maintained and thus further restrictions on containment integrity are not needed. q l

L____-_____

Attachment-Response To Generic Letter 87-121 Page As additional information, we have. determined that the equipment hatch. and personnel hatch could be closed in-less than.two hours if necessary. Also the containment purge system is designedLto maintain containment at a slight negative.' pressure. when- in operation. In the event airborne activity levels increase, radiation monitors will detect this increase and automatically shutdown the purge and exhaust' . system and close the motor-operated dampers.

Question 5 A. Reference to and a summary description of procedures in the control room of your plant which: describe operation while the RCS-is partially filled.

Response

The following procedures are available in the respective. control

! rooms which describe operation while the RCS is at mid-loop.

l Unit 1 (Unit 2):

1.6.4.N (2.6.4.I); Draining the RCS for refueling or draining to.

the centerline of the hotleg loops for maintenance.

l 1AOP-17 (AOP 2.10.2); Abnormal operating procedure; loss of RHR with RCS drained to mid-span of loops.

1 1.10.4.J (2.10.4.D); Normal operating procedure;cRHR operation.

when the RCS is partially drained.

l L5-19, 20 (L5-49, 50); Operator surveillance logs for operating

! with RCS partially drained.

l 1.6.4.P (2.6.4.J); Gravity fill of RCS from the Refueling Water Storage Task (RWST)

Unit 1 Annunciator Response Procedure 1.10.4.AAB; RHR System discharge flow low 1.10.4.AAC; RHR Pump auto stop 1.10.4.AAD; RCS Mid-loop level high 1.10.4.AAE; RCS Mid-loop level low Unit 2 Annunciator Response Procedure 2.10.4.AAC; RHR System Trouble l

t-

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LAttachment l Response To Generic Letter-87-12 Page?l2' 1

l B. Your response should include the- analytic? basis you used for procedures development. 3 Response' The Westinghouse Owners Group is currently' developing a: program. ,

to address the thermal hydraulic and fluid-flow analyses which  !

would support responding- to this issue. This program willLbe reviewed by the utilities' on September 24 .and- 2 5 ,- 19871to l determine- if 1 it will'.be funded' on a generic basis. We will-provide additional- information following this forthcoming meeting.

l C. We l

are. particularly interested in'your treatment of_draindown to l the condition where .the RCS is partially filled,' treatment of ndnor variations from expected' behavior; such as caused by air i entrainment and de-entrainment, treatment of. boiling in the. core j with and without RCS pressure boundary integrity, calculations of J approximate time from loss of' RHR to core damage, level j differences in. the RCS and the effect upon' instrumentation I indications, treatment of air in the RCS/RHR system ~ including the impact of ' air upon NSSS and instrumentation response, Land treatment of vortexing at the- connection of- the RHR suction line(s) to the RCS.

Response

i Refer to SB above.

Question 6 1 l

A. A brief description of training provided_ and other affected personnel that is specific to the issue of operation while the RCS is partially filled. We are particularly interested'in such areas as maintenance personnel training.regarding avoidance of J perturbing the NSS and response to loss of decay heat removal while the RCS is partially filled.

Response l License retraining periodically. includes a review of the plant procedures identified in response to Question 5 above. This maintains operator awareness of operations 'when the RCS is partially filled and the normal, abnormal and emergency ,

procedures - they are required to follow. Additionally,- the information in 'the enclosure to Generic Letter 87-12 will'be included in the Licensed operator Retraining Program and '

presented by the beginning of the sixth refueling. outage tentatively scheduled to start in December 1987.

l i

Attachment i Response To Generic Letter 87-12 {

Page 13

)

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l The maintenance personnel are required to review and sign-off on  ;

all procedures controlling work on safety related equipment prior l to performing their work. Additionally, the shift supervisors I are responsible to assure that work activities do not cause a  !

perturbation of the RCS While it is in a mid-loop condition. l 4

Question 7 A. Identification of additional resources provided to the operators )

while the RCS is partially filled, such as assignment of additional personnel with specialized knowledge involving the phenomena and instrumentation.

Response 1 No additional resources are dedicated to be available while the I RCS is partially filled since there are a minimum number of key j parameters to be maintained, i.e., level, temperature, RHR' flow and boron concentration. It has been a routine practice to provide 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> coverage of instrument and control activities during outages. They are therefore usually available to initiate expeditious repairs of equipment required for safe mid-loop I operation. l l

The licensed operators have received training, via procedure l review and licensed retraining, in the loss of RHR with the RCS i drained to mid-loop. Within the license retraining program there ,

are provisions for training on the simulator and scenarios '

involving degraded or loss of RHR are available. As indicated in response to question 6, the details of enclosure 1 to Generic I Letter 87-12 will be presented to the licensed operators prior to our sixth refueling outage.

Question 8 A. Comparison of the requirements implemented while the RCS is partially filled and requirements- used in other MODE 5 operations. Some requirements and procedures followed while the RCS is partially filled may not appear in the other MODES. An example of such differences is operation with a reduced RHR flow rate to minimize the likelihood of vortexing and air ingestion.

Response

As a result of earlier experiences at Unit No. 1, correspondence on the subject and this Generic Letter, the following restrictions either have been or will be implemented for both Unit No. 1 and 2 when operating with the RCS drained to mid-loop.

LA ltachment . t Rooponse'To' Generic Letter 87 .

)

Page'14 .i

.I l

.- RCS - temperature maintained less than -120*F l

- RHR' flow reduced to minimize vortexing and air' ingestion ;j

'RHR pumps are vented daily

- 'Four. hour logs.are completed on' critical RCS and RHRl parameters and initial conditions ~to assure these'are maintained.- ..

's A 5% shutdown margin .

one steam-generatorTand its associated atmospheric dump valve

available

- A motor-driven auxiliary'feedpump and its' flow path-.to the; u

' J available steam generator is available.

RHR auto isolation has been' defeated.

Type "C" testing restrictions placed on certain: valves which-have the potential'to adversely' impact core cooling.-

The reactor is subcritical for 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.. j 1

J Question 9 A.- As a result of your consideration.of.these issues,'you.may have' .

made changes to your current program related to these issues. . If such changes have strengthened your ability to operate safety.

'during a partially- filled l situation, describeithose changes and tell when they were made or'are scheduled to be made.-

Response 'I We have identified additional requirements ; intended to be implemented' as a result of Lthis Generic Letter in. response to  :

Question 4. There have been past incidentsiat . Beaver Valley Umtt' '1 1 involving loss of RHR-as identified in TABLE 1 of the-enclosure l to Generic Letter 87-12. As a result of ourLearlier experiences and the commission supplied'information described below, we'have previously implemented changes to-protect.against a loss of RHR event. Those changes have been effective to date'since there has not been a prolonged loss of RHR since 1981.

The changes proposed in response to question 4 are intended to '

provide greater defense in-depth for the operating condition z where the -RCS is drained to mid-loop. As such these. changes may l be categorized as strengthening our ability.to operate safely- -

during mid-loop operation. These changes _will'be in effect prior, '

j to the next. refueling outage for each unit. l Previously supplied commission information:

i

1. USNRC Case Study LReport . " Decay HeatLRemoval Problems at U. S. Pressurized Water Reactors", December 23, 1985. .
2. IE Bulletin 80-12; " Decay' Heat Removal System Operability".
3. IE Information Notice 80-20 l

__- _ _ _a

L Attachment 1 .

L o

Responsa.To GenericLLetter 87-12~

Page,15 l:

'I L

Summary of Actions'to be Taken j l'

e' Temporary -level' transmitter, with high and low level alarms tx) j; i monitor lthe vessel. level in~ Unit:2 (Pg. 6).

h e Revise operations surveillance logs (Pg'. .9,l Figures'1'through- 1 7).

l

  • Procedure changes:.to maintainfadditional.componentsLavailable.

(Pg. 10). .

  • Review; Westinghouse Owners Group-program and provide additical.

information'to the NRC-(Pg.'12).

  • Review of. loss' of RHR events in Licensed Operator Retraining-prior to being the sixth refueling outage.(Pg. 12). j
  • Procedure changes identifying 1 restrictions to-be implemented; prior to mid-loop operation. (Pg.13 &' 14 ) ,

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