Text

Summary of 880614 & 15 Meetings W/Util Re Potential Changes to Tech Specs,Allowing Change in Operational Modes When Limiting Conditions for Operation Not Met.List of Participants & Potential Tech Spec Changes Encl
	ML20151R701
Person / Time
Site:	Grand Gulf
Issue date:	08/08/1988
From:	Kintner L; Office of Nuclear Reactor Regulation
To:	; Office of Nuclear Reactor Regulation
References
	GL-87-09, GL-87-9, NUDOCS 8808120256
	Download: ML20151R701 (16)
	v • d • e

.

Docket No. 50-416 M 0S W DISTRIBUTION:

See attached list LICENSEE: System Energy Resources, Inc.

FACILITY: Grand Gulf Nuclear Station, Unit 1

SUBJECT:

SUMMARY

CF JUNE 14 AND 15, 1988 MEETING REGARDING P0TENTIAL CHANGES TO TECHNICAL SPECIFICATIONS On June 14 and 15, 1988, the NRC staff met with representatives from System Energy Resources Inc., (SERI) to discuss potential changes to Technical Specifications (TS) to be submitted in 1988. Enclosure 1 is a list of participants. Enclosure 2 contains potential TS changes.

The licensee informed the staff that SERI Nuclear Licensing personnel are reviewing the effective Technical Specification Position Statements to determine wht.ther TSPS can be eliminated. Some nf the TSPS which identify specific instrumentation or equipment for surveillance tests may be included in the test procedures. Those TSPS which are more conservative than TS or more specific than TS or interpret TS may be submitted as proposed TS changes.

The licensee stated that the target outage time for the third refueling outage is 45 days, beginning February 15, 1989. Previous target outage times were 60 days. The proposed TS changes will reduce outage time to make the target time viable.

Following are the TS changes being considered for 1988.

1. Implementacion of Generic Letter 87-09, Revision of Section 3/4.0 Applicabilig The licensee will proposed changes to Sections 3.0.4 and 4.0.3 in accordance with Generic Letter 87-09 (GL 87-09). The revised Section 3.0.4 will allow changes in operational modes when limiting conditions for operation are not met, provided applicable action statements permit continued operation for an unlimited time period. The staff requested the licensee to identify and evaluate each TS which will be affected.

Affected TS include those which will not have word changes but have action statements that permit operation for an unlimited time. Also, the staff requested the licensee to propose exceptions to the revised TS 3.0.4 for

. those TS which concern equipment whose function is needed during mode changes (e.g., control rod drive accumulators are needed for startup when reactor pressure is low). For action statements which allow the use of alternate equipment that may not provide the same level of safety as the equipment specified in the limiting condition for operation (LC0),

compensatory administrative controls should be described in the safety analysis. For example, during modes 4 and 5, action statements allow the fN J

8808120256 880808 PDR ADOCK 05000416 P PDC

use of unspecified equipment for alternate shutdown cooling and for coolant recirculation if the RHR or ECC systems are inoperable.

Amendment 38 to the Operating License described equipment to be used during the second refueling shutdown as alternates and adininistrative procedures to minimize the time in this action statement.

The revised Section 4.0.3 will allow up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to permit completion of a missed surveillance test. At the licensee's request, the staff

, agreed to consider changes to the revised Bases section in GL 87-09 to clarify that the time limits are applicable from the time it is identified that a surveillance test has been missed or that an LC0 is not met. The staff also agreed to consider the deletion of the last sentence in the fourth paragraph of the Bases for TS 3.0.3 regarding the addition of allowable outage time limits, since it appeared to be confusing to the licensee and is not necessary.

The licensea said the first paragraph of the Bases for TS 4.0.3 was different than present industry practice regarding reporting of missed surveillance tests. Present Bases do not address missed surveillances as TS violations which are subject to enforcement actions or reporting requirements. The licensee interprets present TS 4.0.3 to mean that failure to perform a surveillance test within the specified time interval would require the system to be declared inoperable and entry into the action statement to be made. However, missed surveillances are not reported under 10 CFR 50.73 as a violation of TS. The GL 87-09 Bases state that failure to perform a surveillance test is a violation of TS and, therefore, reportable under 50.73. The staff said the interpretation in GL 87-09 is the correct interpretation for the present TS as well as the reviseo TS.

2. Operational Conditions For Fuel Handling Area Radiation Monitors This TS change would change applicable conditions for radiation monitors in the fuel handling area ventilation exhaust and the pool sweep exhaust so the monitors would not be required to be operable in Operational Conditions 4 or 5 except when handling fuel, performing core alterations or oper6tions with a potential for draining the core. (Enclosure 2, pages 1, 2, and 3). The logic for the changes is that they would make the applicability of the radiation monitors consistent with the applicability of the actuated device, tne standby gas treatment system. Tne staff agreed that this appeared to be a reasonable change.

3. Local Leak Rate Testing Of Valves in Small Lines This change would delete the requirement for local leak rate testing of valves in small diameter test, drain and vent lines. The licensee indicated most lines would be i inch diameter although some may be as large as 1 inch diameter.

4 SurveillanceIntervaliforReactorProtectionSystemInstrumentation This enange would be in accord with the approved GE topical report. This is on3 of the line item TS improvements.

5. Fuel Transfer Canal Gate In TS 3/4.5.2 ECCS shutdown and 3/4.5.3 Suppression Pool, tne licensee would propose to change the note for the conditions under which ECCS and suppression pool are not required to be operable (Enclosure 2, sheets 4 and 5). Presently, the note requires the fuel transfer canal gate and spent fuel pool gate to be removed. The change would allow these gates to be in place so that leakage tests of the fuel transfer tube valves and trouble shooting of the fuel transfer mechanism could be accomplished.

The staff said that the risk of loss of the upper pool as well as reduction in available water inventory should be considered in the safety analysis for this change.

6. Diesel Generator 24 Hour Test Regarding TS 4.8.1.1.2(d), the licensee would like to perform the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months test during power operatico, to reduce the amount of testing during shutdown (Sheets 6 and 7, Enclosure 2). The staff indicated that this extended testing of diesel generators during power operation would significantly increase the probability of the simultaneous failure of both offsite power and one onsite diesel generator due to grid disturbances and that such testing has not been previously approved.

7. Deletion Of A Room Requiring Fire Detection The licensee is planning to remove a wall between two rooms, making one larger room. Since the two renos are listed in TS Table 3.3.7.9-1, one of the rooms will need to be deleted from the table after the change.

8. Snubber Reject Conditions The licensee would like to delete the reject region on TS Figure 4.7.4.-1, "Sample Plan For Snubber functional Test" (Sheet 8 of Enclosure 2). This would eliminate the need to test all snubbers for some test failures. The staff indicated this type of change has been considered previously.

9. Secondary Containment Boundary The present secondary containment boundary includes the auxiliary building except for the railroad bay area. The licensee would like to change the secondary containment boundary to include the railroad bay area. This would allow movement of new fuel into the auxiliary building during power operation. This bay area was not included in the secondary containment because the door is not designed to withstand a tornado or seismic loading. The licensee would propose compensatory measures (e.g., a severe weather watch) during the time fuel is troyed into the secondary containment. It is estimated that about one month per fuel cycle would be required to move fuel into the auxiliary building.

The staff requested that submittals for TS changes be upgradad. The safety analysis should describe the effect of the change on the sat ty function of associated equipment. The analysis to determine no significant hazards I

consideration should identify the accidents involved and the margin of safety involved and give specific reasons why the change does not involve a significant

- increase in the probability or consequences of a previously analyzed accident or reduce the margin of safety.

\6\

Lester L. Kintner, Sr. Project Manager Project Directorate Il-I Division of Reactor Projects-1/II, NRR

Enclosures:

As stated cc w/encis:

See attached list l

]

't i

PM: 21:0RPR:NRR .0RPR:NRR LLKintner sam 0$'/c//88 / /88

- . __ _ _ . . . _ . _ , . _ _ _ . . . . _ _ _ _ _ _ . ~ . . . . _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ . - . _ _ _

Mr. Oliver D. Kingsley, Jr.

System Energy Resources, Inc. Grand Gulf Nuclear Station (GGNS) cc:

Mr. Ted H. Cloninger Mr. C. R. Hutchinson Vice President, Nuclear Engineering GGNS General Manager J and Support Systens Energy Rescurces, Inc. )

System Energy Resources, Inc. Post Office Box 756 Post Office Box 23054 Port Gibson, Mississippi 39150 Jackson, Mississippi 39205 Robert B. McGehee, Esquire The Honorable William J. Guste, Jr.

Wise, Carter, Child, Steen and Caraway Attorney General P.O. Box 651 Department of Justice Jackson, Mississippi 39205 State of Louisiana Baton Rouge, Louisiana 70804 Nicholas S. Reynolds, Esquire Bishop, Liberman, Cook, Purcell Office of the Governor and Reynolds State of Mississippi 1400 L Street, N.W. Jackson, Mississippi 39201 Wasnington, D. C. 20005-3502 Attorney General Mr. Ralph T. Lally Gartin Building Manager of Quality Assurance Jackson, Mississippi 39205 Middle South Utilities System Services, Inc.

639 Loyola Avenue, 3rd Floor Mr. Jack McMillan, Director New Orleans, Louisiana 70113 Division of Solid Waste Management Mississippi Department of Natural Mr. John G. Cesare Resources Director, Nuclear Licensing Post Office Box 10385 System Energy Resources, Inc. Jackson, Mississippi 39209 P.O. Box 23054 Jackson, Mississippi 39205 Alton B. Cobb, M.D.

State Health Officer Mr. C. 8. Hogg, Project Manager State Board of Health Bechtel Power Corporation P.O. Box 1700 P. O. Box 2166 Jackson, Mississippi 39205 Houston, Texas 77252-2166 President Mr. Ross C. Butcher Claiborne County Board of Supervisors Senior Resident inspector Port Gibson, Mississippi 39150 U. S. Nuclear Regulatory Commission Route 2, Box 399 Regional Administrator, Region !!

Port Gibson, Mississippi 39150 U. S. Nuclear Regulatory Commission 101 Marietta Street Mr. James E. Cross Suite 2900 l GGNS Site Director Atlanta, Georgia 30323 Systems Energy Resources, Inc.

P.O. Box 756 Port Gibson, Mississippi 39150

ENCLOSURE 1 PARTICIPANTS JUNE 15, 1988 MEETING SERI - NRC J. Kent Fortenberry SERI, Nuclear Licensing J. Fowler SERI, Nuclear Licensing L~. Kintner NRC, DRPR, I/II, PD21 T. Dunning

NRC, DOEA, TSB N. Trehan* NRC, DEST, ESB J. Kudrick* NRC, DEST, PSB C. Moon

NRC, 00EA, TSB

Part Time u.._-_. ..._ ,._,_.. _ . _ ..._ , ,. . . - - _ _ _._. _ .- _ _... _.__ . . _ _.....~. _ ._ _ .-. _ __ _ . ,, _ _ ..

e ENCLOSURE 2 P0TENTIAL CHANGES TO TECHNICAL SPECIFICATIONS

TABLE 3.3.7.1-1 *

@ RADIATION MONITORING INSTRUMENTATION s

O o MINIHUM CHANNELS APPLICABLE ALARM / TRIP MEASUREMENT INSTRUMENTATION OPERABLE CONDITIONS SETPOINT RANGE ACTION

{

c'. 1. Component Cooling 5

Water Radiation y

Monitor 1 At all times -<1 x 105cpa/NA 6 10 to 10 cm 70

2. Standby Service Water System Radiation Monitor 5 6

1/ heat 1, 2, 3, and* -<1 x 10 cpa/NA 10 to 10 cpm 70 exchanger train

3. [ DELETED]

4. [ DELETED]

m 5. Carbon Bed Vault 2 Radiation Monitor 1 to 106mR/hr 1 1, 2 < 2 x full power 72 w

Eackground/NA

$ 6. Cont.rol Room Ventila- 2/ trip (h) -2 tion Radiatien Monitor system 1,2,3,5 and** $4 mR/hr/ 10 to 102mR/hr 73

$5 mR/hr#

7. Containment and Drywell Ventilation Exhaust 2/ trip (h) -2 Radiation Monitor system At all times <2.0 mR/hr/ 10 to 102mR/hr 74

! <4 mR/hr(b)#

8. Fuel Handling Area /

Ventilation Exhaust 2 2/ trip g) 1,2,3 g and** /$2mR/hrfd)# 0 to 10 mR/hr M Radiation Monitor system $4 mR/hr

, 9. Fuel Handling Area Pool Sweep Exhaust Radiation 2/ trip g)

Monitor system i,t,3 p **/5 18 mR/hr/

(T.

t_

10

,2 to 102mR/hr 75

<35 mR/br(d)#

kH,gQ f_, & '

m d W S , e j i'r inL

%G Olap/y& % i

/ & d" O p ? 4 m A ~/ -

, TABi.E 3.3.7.1-1 (Continued) ,

RADIATION MONITORING INSTRUMENTATION c) MINIMUM CHANNELS APPLICABLE ALARM / TRIP MEASUREMENT .

INSTRUMENTATION OPERABLE CONDITIONS SETPOINf RANGE ACTION E 10. Area Monitors G a. Fuel Handling Area

- Monitors New Fuel -2 to 103 mR/hr

1) 1 (e) 12.5 mR/hr/NA 10 72 Storage Vault

-2 3

2) Sp ot Fuel 1 (f) 12.5 mR/hr/NA 10 to 10 mR/hr 72 Storage Pool

-2

3) Dryer Storage 1 (g) 12.5 mR/hr/NA 10 to 103mR/hr 72 Area

-2

b. Control Room 1 At all times 10.5 mR/hr/NA 10 to 103mR/hr 72

{ Radiation Monitor o

With RHR heat exchangers in operation.

When irradiated fuel is being handled in the primary or secondary containment.

Initial setpoint. Final Setpoint to be determined during startup test program. Any required change to this setpcint shall be submitted to Commission within 90 days after test completion.

(a) Trips system with 2 channels upscale-Hi Hi Hi, or or,e channel upscale Hi Hi Hi and one channel downscale or 2 channels downscale.

(b) Isolates containment /drywell purge penetrations.

(c) With irradiated fuel in spent fuel storage pool.

(d) Ale 9 isolates the Auxiliary Building and Fuel Handling Area Ventilation Systems.

(e) With fuel in the new fuel storage vault.

(f) With fuel in the spent fuel storage pool.

(g) With fuel in the dryer storage area.

(h) Two upscale Hi Hi, one upscale Hi Hi and one downscale, or two downscale signals from the same trip system actuate the trip system and initiate isolation of the associated isolation valves.

)

INSTRUMENT,ATION TABLE 3.3.7.1-1 (Continued)

RAOIATION MONITORING IN3TRUMENTATION ACTION ACTION 70 - With the required monitor inoperaale, obtain and analyze at les.st one grab sample of the monitored parameter at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

AClION 71 -

[0ELETED]

ACTION 72- With the required monitor inoperable, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 73 -

a. With one of the required monitors in a trip system inoperable, place the inoperable channel in the downscale tripped condition within one hour; restore the inoperable enanhel to OPERABLE status within 7 days, or, within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , initiate and maintain operation of at least one control room emergency filtration system in the isolation mode of operation.

5. With both of the required monitors in a trip system inoperable, initiate and maintain operation of at least one control room emergency filtration system in the isolation mode of cperation within one hour.

ACTION 74 -

a. With one of the required monitors in a trip system inoperable, place the inoperable channel in the downscale tripped condition within one hour.

b. With two of the required monitors in a trip system inoperable, isolate the containment and drywell purge and vent penetrations within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 75 -

a. With one of tha t equired monitors in a trip system inoperable, place the inoperable channel in the downscale tripped condition within one hour.

b. With two of the required monitors in a trip system inoperable, establish SECONDARY CONTAINMENT INTEGRITY with at least one standby gas treatment subsystem operating within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

GRAND GULF-UNIT 1 3/4 3-61

~_ _ _. _ , _ _ . _ _ _ - _

EMERGENCY CORE COOLING SYSTEMS ll 3/4 5.2 ECCS - SHUT 00WN LIMITING CONDITION FOR OPERATION 3.5.2 At least two of the following shall be OPERABLE:

a. The low pressure core spray (LPCS) system with a flow path capable of taking suction from the suppression pool and transferring the water through the spray sparger to the reactor vessel.

b. Low pressure coolant injection (LPCI) subsystem "A" of thc. RHR systcrr with a flow path capable of taking suction from the suppression pool upon being manually realigned and transferring the water to the reactor vessel.

c. Low pressure coolant injection (LPCI) subsystem "B" of the RHR system with a flow path capable of taking suction from the suppression pool upon being manually realigned and transferring the water to the reactor vessel.

d. Low pressure coolant injection (LPCI) subsystem "C" of the RHR system with a flow path capable of taking suction from the suppression pool upon being manually realigned and transferring the water to the reactor vessel.

e. The high pressure core spray (HPCS) system with a flow path capable of taking suction from one of the following water sources and trans-ferring the water through the spray sparger to the reactor vessel:

1. From the suppression pool, or

2. When the suppression pool level is less than the limit or is drained, from the condensate storage tank containing at least 170,000 available gallons of water, equivalent to a level of 18 feet.

APPLICABILITY: OPERATIONAL CONDITION 4 and 5*.

ACTION:

a. With one of the above required subsystems / systems inoperable, restore at least two subsystems / systems to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or suspend all operations that have a potential for oraining the reactor vessel,

b. With both of the above required subsystems / systems inoperable, suspend CORE ALTERATIONS and all operations that have a potential for draining the reactor vessel. Restore at least one subsystem / system to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or establish SECONDARY CONTAINMENT INTEGRITY within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . 4 -

&& Y2 0^w^4lk 0 w { f The ECCS is not required to be OPERABLE provided 'that the reactor vessel _ head )

is removed, the cavity is flooded, the upper containment fuel pool gates rare removed, tt.: :p =t N:t 4 p :: r: r=ned, and water level is mainYained within the limits of Specifications 3.9.8 and 3.9.9.

GRAND GULF-UNIT 1 3/4 5-6

).

EMERGENCY CORE COOLING SYSTEMS 3/4.5.3 SUPPRESSION POOL LIMITING C(;NDITION FOR OPERATION 3.5.3 The suppression pool shall be OPERABLE:

a. In OPERATIONAL CONDITION 1, 2 or 3 with a contained wate volume of at least 135,291 ft3 , equivalent to a level of 18'4-1/12."

b. In OPERATIONAL CONDITION 4 or 5* with a contained water volume of at least 93,600 ft3 , equivalent to a level of 12'8", except that the suppression pool level may be less than the limit or may be drained provided that:

1. No operations are performed that have a potential for draining the reactor vessel,

2. The reactor code switch is locked in the Shutdown or Refuel position,

3. The condensate storage tank contains at least 170,000 available gallons of water, equivalent to a level of 18', and 4 The HPCS system is OPERABLE per Specification 3.5.2 with an OPERABLE flow path capable of taking suction from the condensate storage tank and transferring the water through the spray sparger to the reactor vessel.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, 4 and 5*.

ACTION:

a. In OPERATIONAL CONDITION 1, 2 or 3 with the suppression pool water level less than the above limit, restore the water level to within the limit within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUT 00WN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

b. In OPERATIONAL CONDITION 4 or 5* with the T 'pression pool water level less than the above limit or drainee ..d the above required conditions not satisfied, suspend CORE ALTERATIONS and all opera-tions that have a potential for draining the reactor vessel and lock the reactor mode switch in the Shutdown position. Establish SECONDARY CONTAINMENT INTEGRITY within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , j See Specification 3.6.3.1 for pressure suppression requ rements. f Wl ThesuppressionpoolisnotrequiredtobeOPERABLEprohidedthatthereactor vessel head is removed, the cavity is flooded or being flooded from the suppression pool, the upper containment fuel pool gateslPare removed when the cavity is flooded, and the water level is maintained within the limits of Specification 3.9.8 and 3.9.9.

GRAND GULF-UNIT 1 3/4 5-8

ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

c. At least once per 92 days and from new oil prior to addition to the storage tanks by verifying that a sample obtained in accordance with ASTM-0270-1965 (reapproved 1980) has a water and sediment content of less than or equal to .05 volume percent and a kinematic viscosity

@ 40 C of greater than or equal to 1.9 but less than or equal to 4.1 when tested in accordance with ASTM-097o-77, and an impurity level of less than 2 mg. of insolubles per 100 ml. when tested in accordance with ASTM-D2274-70, except that the test of new fuel for impurity level shall be performed within 7 days after addition of the new fuel to the storage tank.

d. At least once per 18 months, during shutdown, by:

1. Subjecting the diesel to an inspection in accordance with pro-cedures prepared in conjunction with its manufacturer's recom-mendations for this class of standby service.

2. Verifying the diesel generator capability to reject a load of greater than or equal to 1200 kW (LPCS Pump) for diesel generator 11, greater than or equal to 550 kW (RHR B/C Pump) for diesel generator 12, and greater than or equal to 2180 kW (HPCS Pump) for diesel generator 13 while maintaining less than or equal to 75% of the difference between nominal speed and the overspeed trip setpoint, or 15% above nominal, whichever is less.

3. Verifying the diesel generator capability to reject a load of at least 5450 kW but not to exceed 5740 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13 without tripping.

The generator voltage shall not exceed 5000 volts during and following the load rejection.

4. Simulating a loss of offsite power by itself, and:

a) For Divisions 1 and 2:

1) Verifying deenergization of the emergency busses and load shedding from the emergency busses.

2) Verifying the diesel generator starts on the auto-start signal, energizes the emergency busses with permanently connected loads within 10 seconds, energizes the auto-connected shutdown loads through the load sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the shutdown loads. After ener-gization, the steady state voltage and frequency of the emergency busses shall be maintained at 4160 1 416 volts and 60 1.2 Hz during this test.

b) For Division 3:

1) Verifying de-energization of the emergency bus.

2) Verifying the diesel generator starts on the auto-start signal, energizes the emergency bus with the loads within 10 seconds and operates for greater than or equal to 5 minutes while its generator is loaded with the shutdown loads. After energization, the steady state voltage and frequency of the emergency bus shall be maintained at 4160 416 volts and 6011.2 Hz during this test.

GRAND GULF-UNIT 1 3/4 8-4

6 i

~

l ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

9. Verifying the diesel generator operates for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Diesel generators 11 and 12 shall be loaded to greater than or equal to 5450 kW but not to exceed 5740 kW for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Diesel generator 13 shall be loaded to greater than or equal to 3630 kW for the first 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of this test and to 3300 kW during the remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months . The generator voltage and frequency shall be 4160 416 volts and 60 1.2 Hz within 10 seconds after the start signal; the steady state generator voltage and frequency shall be maintained within these limits during this test. Within 5 minutes after completing this 24-hour test, perform Surveillance Requirement 4.8.1.1.2.d.7.a).2) and b).2)*.

10. Verifying that the auto-connected loads to each diesel generator do not exceed 5740 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13.

11. Verifyina the diesel generator's capability to:

a) Synchronize with the offsite power source while the generator is loaded with its emergency loads upon a simulated restora-tion of offsite power, b) Transfer its loads to tr.e offsite power source, and c) Be restored to its standby status.

12. Verifying that with the diesel generator operating in a test mode and connected to its bus that a simulated ECCS actuation signal:

a) For Divisions 1 and 2, overrides the test mode by returning the diesel generator to standby operation.

b) For Division 3, overrides the test mode by bypassing the diesel generator automatic trips per Surveillance Require-ment 4.8.1.1.2.d.8.b).

13. [0ELETED]g

14. [0ELETED)

15. Verifying that the automatic load sequence timer is OPERABLE with the interval between each load block within i 10% of its design interval for diesel generators 11 and 12.

"If Surveillance Requirement 4.8.1.1.2.d.7.a)2) or b)2) are not satisfactorily completed, it is not necessary to repeat the preceding 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months test. Instead, the diesel generator may be operated at the load specified by Surveillance Requirement 4.8.1.1.2.a.5 for one hour or until operating temperatures have stabilized.

GRAND GULF-UNIT 1 3/4 8-6

d 4

* /A ,

J 10 -

9 S

7 6

7 C 5 O.

4

/ '

s-CONTINUE TESTING j

, JU ACCEPT I

/

l / \ $

0 10 20 30 40 50 60 70 80 90 10 0 N

l FIGURE 4.7.4-1 l (SAMPLE PLAN 2) FOR SNUBBER FUNCTIONAL TEST 1

GRAN0 GULF-UN1T 1 3/4 7-14

DISTRIBUTION FOR MEETING

SUMMARY

DATEDI AUG 0 s 1988' facility: GRAND GULF DocketFile<

NRC PDR Local POR PDil-1 Reading E. Adensam P. Anderson Project Manager OGC E. Jordan (MNBE 3302)

B. Grimes (9A2)

NRC Participants ACRS (10)

W. Troskoski (1709_

cc: Licensee / Applicant Service List

ML20151R701

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