ML18051B069
| ML18051B069 | |
| Person / Time | |
|---|---|
| Site: | Palisades  |
| Issue date: | 09/17/1984 |
| From: | CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.) |
| To: | |
| Shared Package | |
| ML18051B068 | List: |
| References | |
| NUDOCS 8409250349 | |
| Download: ML18051B069 (8) | |
Text
3.3 EMERGENCY CORE COOLING SYSTEM (Contd) condition to provide for reduction of the deca~ heat from the fuel and consequent reduction of cooling requirements after a postulated loss-of-coolant accident. This will also permit improved access for repairs in some cases. After a limited time in hot shutdown, if the malfunction(s) is not corrected, the reactor will be placed in the cold shutdown condition utilizing normal shutdown and cooldown procedures.
in the cold shutdown condition, release of fission products or damage of the fuel elements is not considered possible. The plant operating procedures will require immediate action to effect repairs of an inoperable component and, therefore, in most cases, repairs will be completed in less than the specified allowable repair times. The
.limiting times to repair are intended to: (1) Assure that operability of the component will be restored promptly and yet, (2) allow sufficient time to effect repairs using safe and proper procedures.
The requirement for core cooling in case of a postulated loss-of-coolant accident while in the hot shutdown condition is significantly reduced below the requirements for a postulated loss-of-coolant accident during power operation. Putting the reactor in the hot shutdown condition reduces the consequences of a loss-of-coolant accident and also allows more free access to some of the engineered safeguards components in order to effect repairs.
Failure to complete repairs within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> of going to the hot shutdown condition is considered indicative of a requirement for major maintenance and, therefore, in such a case, the reactor is to be put into the cold shutdown condition.
With respect to the core cooling function, there is functional redundancy over most of the range of break sizes. <2 >
Adequate core cooling for the break spectrum up to and including the 42-inch double-ended break is assured with the minimum safety injection which is defined as follows: For the system of four passive safety injection tanks, the entire contents of one tank are assumed to be unavailable for emergency core cooling. In addition, of the two high-pressure safety injection pumps and the two low-pressure safety injection pumps, only one of each type is assumed to operate; and also 8409250349'<840917 . ":'; *1* -
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3-32 MI0684-0015-NL02
3.5
. e Steam and Feedwater Systems Applicability Applies to the operating status of the Steam and Feedwater Systems.
Objective To define certain conditions of the Steam and Feedwater System neces-sary to assure adequate decay heat removal capability.
Specifications 3.5.1 The primary coolant shall not be heated above 325°F unless the follow-ing conditions are met:
a All three Auxiliary Feedwater Pumps and one fire protection pump shall be operable.*
b The Auxiliary Feedwater System Instrumentation shall meet the minimum operability requirements addressed in Technical Specif i-cation 3.17.
c All flow control valves associated with the Auxiliary Feedwater System shall be operable.
d All valves, interlocks and piping associated with the above components required to function during accident conditions are operable.
e A minimum of 100,000 gallons of water in the condensate storage and primary coolant system makeup tanks combined.
f The main steam stop valves are operable and capable of closing five seconds or less under no-flow conditions.
3-38 OC0684-0010-NL02 PROPOSED
3.5
. e Steam and Feedwater Systems (Continued) 3.5.2 With the Primary Coolant System at a temperature greater than 325°F, the requirements of 3.5.1 may be modified to permit one of the follow-ing conditions to exist. If the system is not restored to meet the requirements of 3.5.1 within the time period specified below, refer to 3.5.3.
a Auxiliary Feedwater Pump P-8A or P-8B may be inoperable for a period of 7 days provided pump P-8C, the Auxiliary Feedwater Actuation System, and all flow control valves are operable to both pipe trains.
b Auxiliary Feedwater Pump P-8C may be inoperable for a period of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
c The fire water makeup to the Auxiliary Feedwater Pump Suction may be inoperable for a period of 7 days.
d The service water makeup to the Auxiliary Feedwater Pump Suction may be inoperable for a period of 7 days.
e One flow control valve may be inoperable for a period of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> provided the pump(s), Auxiliary Feedwater Actuation System, and the flow control valves of the other pipe train are operable.
3.5.3 With the Primary Coolant System at a temperature greater than 325°F and if the system does not satisfy the requirements of 3.5.1 or the conditions of 3.5.2 except as*noted in 3.5.4, the reactor shall be placed in hot standby within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, hot shutdown within the follow-ing 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in cold shutdown within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
3.5.4 With all Auxiliary Feedwater Pumps inoper.able immediately initiate corrective action to restore at least one Auxiliary Feedwater *:Pump to OPERABLE status as soon as possible and reduce power within 24.hours to the lowest stable power level consistent with reliable Main Feedwater System operation.
3-38a OC0684-0010-NL02 PROPOSED
3.5 e
Steam and Feedwater Systems (Continued)
BASIS The Steam and Power Conversion System is designed to receive steam from the NSSS and convert the steam thermal energy into electrical energy. A closed regenerative cycle condenses the steam from the main turbine and returns the condensate as heated feedwater to the steam generators. Normally, the capability to supply feedwater to the steam generators is provided by operation of the turbine-driven main feedwater pumps.
A reactor shutdown from power requires removal of core decay heat.
Immediate decay heat removal requirements are normally satisfied by the steam bypass to the condenser, or by steam discharge to the atmosphere via the main steam safety valves or power operated relief valves. (1,2) If the main feedwater pumps are not operating, any one auxiliary feedwater pump can supply sufficient feedwater for removal of decay heat from the Plant. The Plant is provided with two motor driven auxiliary feedwater pumps (P-8A, P-8C) and one turbine driven auxiliary feedwater pump (P-8B). The Auxiliary Feedwater System is designed so that an automatic start signal is generated to the auxil-iary feedwater pumps upon low secondary side steam generator .. level.
Upon low secondary side steam generator level, auxiliary feedwater pump P-8A would be the first auxiliary feedwater pump to receive an automatic start signal. If pump P-8A failed to start or establish flow within a specified period of time, auxiliary feedwater pump P-8C would receive an automatic start signal. If both pump P-8A and pump P-8C failed to start or establish flow within .each pump's specified period of time, auxiliary feedwater pump P-8B would receive an auto-matic start signal. All three auxiliary feedwater pumps normally take suction from the condensate storage tank. The minimum amount of water in the condensate storage tank is the amount needed for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> of auxiliary feedwater pump operation. If the outage is more than 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, Lake Michigan water can be.used, by utilizing a fire pump to supply water to the auxiliary feedwater pumps P-8A and P-8B, or by utilizing a service water pump to supply water to auxiliary feedwater pump P-8C.
Three fire pumps are provided, one motor driven and two diesel driven, each capable of delivering 1500 gpm at 125 psig. Three servic.e wa.ter pumps are provided, all of which are motor driven, each capable of delivering 8000 gpm at 60 psig.
A closure time of 5 seconds for the main steam stop valves is consid-ered adequate and was selected as being consistent with expected response time for instrumentation as detailed in the steam line break incident analysis. (3)
REFERENCES (1) FSAR, Section 4.3.4 (2) FSAR, Section 14.13.1 (3) FSAR, Section 14.14 3-39 OC0684-0010-NL02 PROPOSED
Table 3.17.4 Minimum Minimum Permissable Operable Degree of Bypass No Functional Unit Channels Redundancy Conditions
- 8. Pressurizer Water 2 1 Not required in Level (LI-0102) Cold or Refuel-ing Shutdown
- 9. Pressurizer Code 1 per None Not Required Safety Relief Valves Valve Below 325°F Position Indication (Acoustic Monitor or Temperature Indication)
- 10. Power Operated Relief 1 per None Not required When Valves (Acoustic Valve PORV Isolation Valve Monitor or Temperature Is Closed and its Indication) Indication System is operable
- 11. PORV Isolation Valves 1 per None Not required When Position Indication Valve Reactor is Depressurized and Vented Through a Vent -1. 3 sq in
- 12. Subcooling Margin 1 None Not Required Monitor Below*325°F
- 13. Auxiliary Feed Flow 1 per ftow None Not required Rate Indication Control Valve below 325°F
- 14. Auxiliary Feedwater 2 (e) 1 Not required Actuation System below 325°F Sensor Channels
- 15. Auxiliary Feedwater 2 (f) 1 Not required Actuation System below 325°F Actuation Channels
- 16. Excore Detector 1 (g) None None (e) Auxiliary Feedwater System Actuation System Sensor Channels contain pump auto initiation circuitry. If two sensor channels are inoperable, one of the steam generator low level bistable modules in the one of the inoperable channels must be in the tripped condition.
(f) With one Auxiliary Feedwater Actuation System Actuation Channel inoperable, in lieu of the requirement of 3.17.2, provide a second licensed operator in the control room within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
With both inoperable, in lieu of following the requirements of 3.17.2, start and maintain in operation the turbine driven auxiliary feed pump.
(g) Calculate the Quadrant Power Tilt using the excore readings at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> when the excore detectors deviation alarms are operable.
3-8la OC0684-0010-NL02 PROPOSED
TABLE 4.1.3 (Continued)
Minimum Frequencies for Checks, Calibrations and- Testing of Miscellaneous Instrumentation and Controls Surveillance Channel Description Function Frequency Surveillance Method
- 15. Auxiliary Feed Pump (a) Check M (5) (a) Comparison of Flow Indication Channels (b) Calibrate R (b) Know differential pressure applied to sensors
- 16. Auxiliary Feed Pump (a) Test M (3) (5) (a) Internal Test Auto Initiation Signal (b) Calibrate R (b) Known low level signal applied to sensors
- 17. Power Operated Relief Valves + Pressurizer Code Safety Relief Valves Position Indication (a) Temperature (a) Check R (a) Known Resistance (b) Calibrate s Substitute for RTD (b) Comparison of Channels (b) Acoustic Monitor (a) Check R (a) Inject Calibrated Test Signal
- 18. Subcooling Margin (a) Check s (a) Comparison of Monitor (b) Calibrate R Channels (b) Known Resistance Substituted for RTD Coincident with known pressure input (4)
(3) Test method to be alternated to include starting Auxiliary Feedwater Pump from the control room hand switch, from the breaker and from the pump test - key switch in a three month period.
(4) In conjunction with item 4 (b), Table 4.1.1.
(5) It is not necessary to perform the specified testing during the cold shutdown condition.
4-lla OC0684-0010B-NL02 PROPOSED
4.6 SAFETY INJECTION AND CONTAINMENT SPRAY SYSTEMS TEST Applicability Applies to the safety injection system, the containment spray system, chemical injection system and the containment cooling system tests.
Object To verify that the subject systems will respond promptly and perform their intended functions, if required.
Specifications 4.6.1 Safety Injection System
- a. System tests shall be performed at each reactor refueling interval.
A test safety injection signal will be applied to initiate operation of the system. The safety injection and shutdown cooling system pump motors may be de-energized for this test.
- b. The system test will be considered satisfactory if control board indication and visual observations indicate that all components have received the safety injection signal in the proper sequence and timing (ie, the appropriate pump breakers shall have opened and closed, and all valves shall have completed their travel).
- c. All high pressure safety injection pumps except those otherwise required to be operable shall be demonstrated inoperable at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> whenever the temperature of one or more of the PCS cold legs is ~ 250° F and the vessel head is not removed by verifying that the control system fuses and their fuse holders for the HPSI pumps (P-66A and P-66B) have been removed from the circuit.
4.6.2 Containment Spray System
- a. System tests shall be performed at each reactor refueling interval.
The test shall be performed with the isolation valves in the spray supply lines at the containment blocked closed. Operation of the system is initiated by tripping the normal actuation instrumentation.
- b. At least every five years the spray nozzles shall be verified to be open.
- c. The test will be considered satisfactory if visual observations indicate all components have operated satisfactorily.
4.6.3
- a. The safety injection pumps, shutdown cooling pumps, and containment spray pumps shall be started at intervals not to exceed three months. Alternate manual starting between control room console and the local breaker shall be practiced in the test program.
4-39 MI0684-0015-NL02
.J
.. e Auxiliary Feedwater System Applicability Applies to periodic testing requirements of the turbine-driven and motor-driven Auxiliary Feedwater Pumps.
Objective To verify the operability of the Auxiliary Feedwater System and its ability to respond properly when required.
Specifications a The operability of the motor-driven and steam-driven Auxiliary Feedwater Pumps shall be confirmed as required by Specification 4.3.c.
b The operability of the Auxiliary Feedwater System flow control valves CV-0736A, CV-0737A, CV-0727 and CV-0749 shall be confirmed every month.
4.9 Auxiliary Feedwater System BASIS The periodic testing of the auxiliary feedwater pumps will verify their operability by recirculating water to the condensate storage tank and simultaneously partially opening the corresponding flow control valves either CV-0736A and CV-0737A, or CV-0727 and CV-0749 to confirm a flow path to the steam generators. The operability of the auxiliary feedwater pump auto initiation shall include starting the auxiliary feedwater pumps from the control room hand switch, from the breaker, and from the pump test-key switch behind panel C-11 in a three month period.
Proper functioning of the steam turbine admission valve and the feedwater pumps start will demonstrate the integrity of the steam driven pumps. Verification of correct operation will be made both from instrumentation with the main control room and direct visual observation of the pumps.
REFERENCE FSAR, Section 9.7 4-45 OC0684-0010-NL02 PROPOSED