GNRO-2014/00057, Letter GNRO-2012/00146, Technical Requirements Manual and Technical Specification Bases Update (ML12361A330)
| ML14241A308 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 08/29/2014 |
| From: | Kevin Mulligan Entergy Operations |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| GNRO-2014/00057 | |
| Download: ML14241A308 (50) | |
Text
~
~Entergy Entergy Operations, Inc; P. O. Box 756 Port Gibson, MS 39150 Kevin Mulligan Site Vice President Grand Gulf Nuclear Station Tel. (601) 437-7500 GNRO-2014/00057 August 29,2014 u.s. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555-0001
SUBJECT:
Technical Requirement Manual Grand Gulf Nuclear Station, Unit 1 Docket No. 50-416 License No. NPF-"29
REFERENCE:
Entergy Letter GNRO-2012/00146, Technical Requirements Manual and Technical Specification Bases Update (ML12361A330)
Dear Sir or Madam:
Pursuant to the Grand Gulf Nuclear Station (GGNS) Technical Requirements Manual (TRM)
Section 1.04 and 10 CFR 50.71 (e), Entergy Operations Inc. (Entergy) herby submits an update of all changes made to the GGNS TRM since the last submittal (GNRO-2012/00146, dated December 21,2012).
This letter contains no new commitments. If you have any questions or require additional information, please contact James Nadeau at 601-437-2103.
th I declare under penalty of perjury that the foregoing is true and correct. Executed on the 29 day of August 2014.
Sincerely,
.~r:-/-ra-m--- .-.--------~-
Attachment(s): 1. Technical Requirements Manual Change Summary
- 2. Technical Requirements Manual Changes
GNRO-2014/00057 Page 2 of 2 cc: without Attachment(s) u.s. Nuclear Regulatory Commission ATTN: Mr. A. Wang, NRR/DORL Mail Stop OWFN/8 G14 11555 Rockville Pike Rockville, MD 20852-2378 u.s. Nuclear Regulatory Commission ATTN: Mr. Nathaniel Ferrer NRR/DLR Mail Stop OWFNI 11 F1 11555 Rockville Pike Rockville, MD 20852-2378 NRC Senior Resident Inspector Grand Gulf Nuclear Station Port Gibson, MS 39150
Attachment 1 GNRO-2014/00057 Technical Requirements Manual Change Summary of GNRO-2014/00057 Page 1 of 1 LBDCR Topic of Change Affected TRM Pages Number 12051 Revision of operating'license manual 3.4-30-1,3.4-31-1,3.4-32-1,3.4-33-1,3.4-to include the pressure and 34-1 temperature limits report (Amendment 191).
13007 Revision of the technical 6.7-10,6.7-11 requirements manual (TRM) TRM 6.7.5 and TRM Bases 6.7.5 for update required by GGNS re-evaluation of localized intense precipitation for near term task force 2.1 for Fukushima on flooding.
13013 Revision ef the TRM for 24 month fuel 3.1-18-1,3.1-18-11,3.1-18-111, 3.3-18-V, 3.3-cycle (EC 42885). 43-IV, 3.4-15-11, 3.5-5-1,3.5-5-111,3.5-9-11,3.6-26-1,3.6 11,3.6-30-11, 3.6-39-IV, 3.6-57-1, 3.6-57-11, 3.7-4-11, 3.7-5-1, 3.8-17-1, 3.8-17-11,3.9-7-1,3.9-7-11,6.3-7,6.3-16, 6.3-18, 6.3-21, 6.8-3, 6.8-26, 7-6 13020 Correction of typographical errors in TRB-1, TRB-2, TRB-3, TRB-4, TRB-5, TRM Bases section B6.3.1 through TRB-6, TRB-7 B7.6.3.10.
13032 Revision of TRM 7.2.1.f to include 7-1 Assistant Operations Manager -
Support as an Operations Middle Manager.
13037 Revision of TRM 7.6.3.10.1 to include 7-8 Code Case OMN-13.
14019 Editorial change to revert TRM 3.3-58-VIII SR3.3.6.1.4 that was inappropriately revise to 24 month frequency back to 18 month frequency (EC 42885)
Attachment 2 GNRO-2014/00057 Technical Requirements Manual Changes
NOTES---------------------------------------
The following surveillance requirement applies to LCO 3.1.5. Failure to meet this surveillance requirement requires entry into LCO 3.1.5.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.1.5.1 Measure and record the time, for up to 10 minutes, 24 months that each individual accumulator check valve maintains the associated accumulator pressure above the alarm set point, starting at normal system operating pressure, with no control rod drive pump pressurizing the tested accumulator.
T~ 3.1 I LBDCR 13013
TR3.1 REACTIVITY CONTROL SYSTEMS TR3.1.5 Control Rod Scram Accumulator Alarms LCO TR3.105 Each control rod scram accumulator alarm shall be OPERABLE.
APPLICABILITY: When associated control rod scram accumulator is OPERABLE per LCO 3.1.5.
ACTIONS
NOTES---------------------------------------
- 1. LCO 3.0.3 is not applicable.
- 2. Separate Condition entry is allowed for each control rod scram accumulator alarm.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more accumulator A.1 Verify the affected Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> pressure detectors or accumulator pressure ~ 1520 alarms inoperable. psig.
B. One or more accumulator B.1 Verify the affected Once per 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> leak detectors or alarms accumulator water drained.
inoperable. AND Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to reactor startup.
C. Required Action and C.1 Declare the associated Immediately associated Completion Time accumulator inoperable.
not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.1.5.2 Perform a CHANNEL FUNCTIONAL TEST on the leak 24 months detector and associated alarm for each control rod scram accumulator.
SR TR3.1.5.3 Perform a CHANNEL CALIBRATION of the pressure 24 months detector for each control rod scram accumulator and verify an alarm setpoint ~ 1520 psig on decreasing pressure.
SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR TR3.3.2.1.6 Perform a CHANNEL FUNCTIONAL TEST. 366 days SR TR3. 3.2 . 1. 7 Perform a CHANNEL FUNCTIONAL TEST. 184 days SR TR3. 3.2.1. 8 Perform a CHANNEL FUNCTIONAL TEST. Within 7 days prior to startup SR TR3.3.2.1.9 ---------------------NOTE----------------------
Neutron detectors may be excluded.
Perform a CHANNEL CALIBRATION. 92 days SR TR3.3.2.1.10 ---------------------NOTES---------------------
- 1. Neutron detectors are excluded.
- 2. APRM recirculation flow transmitters are excluded.
- 3. For Function 1.a, the digital components of the flow control trip reference cards are excluded.
Perform a CHANNEL CALIBRATION. 24 months SR TR3.3.2.1.11 Perform a CHANNEL CALIBRATION. 24 months SR TR3.3.2.1.12 Perform APRM recirculation flow transmitter 24 months calibration.
SR TR3.3.2.1.13 Deleted TRM 3.3 V LBDCR 13013
TR3.3 INSTRUMENTATION TR3.3.5.1 Emergency Core Cooling System (ECCS), Manual Inhibit, Instrumentation LCO TR3 . 3.5 . 1 Automatic Depressurization System (ADS) Trip System A and B, Manual Inhibit Function shall be OPERABLE.
APPLICABILITY: MODE 1, MODE 2 and 3, with reactor steam dome pressure> 150 psig.
ACTIONS
~NOTES---------------------------------------
- 1. LeO 3.0.3 is not applicable.
- 2. Separate Condition entry is allowed for each channel.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more manual inhibit A.1 Restore channel to OPERABLE 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> from channel(s) inoperable. status. discovery of inoperable channel concurrent with HPCS or RCIC inoperable AND 8 days.
B. Required Action and B.1 Declare the associated Immediately associated Completion Time supported ADS valves of Condition A not met. inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.3.5.1.1 Perform CHANNEL FUNCTIONAL TEST. 18 months SR TR3.3.5.1.2 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months TRM 3.3 IV LBDCR 13013
SURVEILLANCE REQUIREMENTS
NOTES---------------------------------
- 1. Refer to Table TR3.3.6.1-2 to determine which SRs apply for each Function.
- 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> provided the associated Function maintains isolation capability.
SURVEILLANCE FREQUENCY SR TR3.3.6.1.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR TR3.3.6.1.2 Perform a CHANNEL FUNCTIONAL TEST. 92 days SR TR3.3.6.1.3 Deleted Not applicable SR TR3.3.6.1.4 Perform CHANNEL CALIBRATION. 18 months TRM 3.3 VIII LBDCR~, 14019
TR3.4 REACTOR COOLANT SYSTEM (RCS)
TR3.4.6 RCS Pressure Isolation Valve (PIV) Leakage, Pressure Monitors and Interlocks.
LCO TR3.4.6 The high/low pressure interface valve pressure monitors and interlocks shall be OPERABLE.
APPLICABILITY: MODES 1 and 2, MODE 3, except valves in the residual heat removal (RHR) shutdown cooling flowpath when in, or during the transition to or from, the shutdown cooling mode of operation.
ACTIONS
NOTES--------------------------------------
- 1. LCO 3.0.3 is not applicable.
- 2. Separate Condition entry is allowed for each channel.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more pressure A.I Restore channel to OPERABLE 30 days monitors or interlocks status.
B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.4.6.1 Perform CHANNEL FUNCTIONAL TEST on the high/low 366 days pressure interface valves leakage pressure monitor alarm and interlock setpoints per Table TR3.4.6-2 and Table TR3.4.6-3.
SR TR3.4.6.2 Perform CHANNEL CALIBRATION on the high/low 24 months pressure interface valves leakage pressure monitor alarm and interlock setpoints per Table TR3.4.6-2 and Table TR3.4.6-3.
DELETED TR.M 3.4-30-1 LBDCR 12051
DELETED TRIvl 3.4.-3:1.-1 LBDeR J.2051
DELETED TRIV1 3.4.-32-1 LBDCR 1.2051
DELETED
'I'RM 3.4***33***1 LBDCH 12051
ElETED 3.4-34-1 LBDeR 12051
NOTE-----------------------------------------
The following surveillance requirement applies to Leo 3.5.1. Failure to met this surveillance requirement requires entry into Leo 3.5.1.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.5.1.1 Verify that the time required for each LPCI and In accordance with LPCS injection valve to travel from fully closed the Inservice to fully open is ~ 29 seconds. Testing Program SR TR3. 5. 1. 2 Perform an extrapolated pressure decay test on the 24 months air system to demonstrate system pressure will be maintained for 7 days at a value ~ 110 psig without makeup air available.
TRM 3.5 I LBDeR 13013
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3. 5. 1. 3 Perform a CHANNEL FUNCTIONAL TEST of the discharge 366 days line "keep filled" pressure alarm instrumentation.
SR TR3.5.1.4 Deleted SR TR3.5.1.5 Perform a CHANNEL FUNCTIONAL TEST of the 366 days accumulator low pressure alarm channels.
SR TR3. 5 . 1. 6 Perform a CHANNEL CALIBRATION of the discharge 24 months line high pressure alarm instrumentation. Verify the high pressure setpoints;
- a. LPCS system to be ~ 575 psig, and
- b. LPCI subsystems to be ~ 475 psig.
SR TR3.5.1.7 Deleted SR TR3. 5 . 1. 8 Perform a CHANNEL CALIBRATION of the accumulator 24 months low pressure alarm channels. Verify an alarm setpoint of ~ 150 psig on decreasing pressure.
SR TR3. 5.1. 9 Perform a CHANNEL CALIBRATION of "keep filled" low 24 months pressure alarm instrumentation. Verify the low pressure setpointi
- a. LPCI A and B subsystem to be ~ 38 psig,
~ 22 psig, and
- c. HPCS system to be ~ 18 psig.
TRM TR3.5.2 - SUPPRESSION POOL LEVEL ALARM INSTRUMENTATION - SHUTDOWN LCO TR3.5.2- Two suppression pool low water level alarm channels shall be OPERABLE with the low water level alarm ~ 12'8".
APPLICABILITY: When ECCS systems are required OPERABLE per LCO 3.5.2.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One low level alarm A.1 Restore the inoperable 7 days inoperable. division to OPERABLE status.
B. Required Action and B.1 Verify the suppression pool Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time water level ~ 12' 8" by at of Condition A not met. least one alternate indicator.
C. Both suppression pool low C.1 Verify the suppression pool Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> water level alarms water level ~ 12' 8" by at inoperable. least one alternate indicator.
SURVEILLANCE REQUIREMENTS
NOTE----------------------------------------
A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> during periods of required surveillance provided at least one other OPERABLE channel in the same system is monitoring that parameter.
SURVEILLANCE FREQUENCY SR TR3.5.2.1 Perform a CHANNEL CHECK. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR TR3.5.2.2 Perform a CHANNEL FUNCTIONAL TEST. 92 days SR TR3.5.2.3 Perform a CHANNEL CALIBRATION. 24 months TRM 3.5 II LDBCR 13013
NOTE----------------------------------------
The following surveillance requirements apply to LCO 3.6.1.9. Failure to meet these surveillance requirements requires entry into LCO 3.6.1.9.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.6.1.9.1 Perform a CHANNEL CHECK of the inboard and 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> outboard pressure instrumentation.
SR TR3.6.1.9.2 Perform a CHANNEL FUNCTIONAL TEST of the 366 days inboard and outboard pressure instrumentation.
SR TR3.6.1.9.3 DELETED Not Applicable SR TR3.6.1.9.4 DELETED Not Applicable SR TR3.6.1.9.5 ----------------------NOTE--------------------- 92 days Not required to be performed in MODES 1, 2 or 3.
Cycle each motor operated valve through at least one complete cycle of full travel.
SR TR3.6.1.9.6 ----------------------NOTE---------------------
The following test is not performed with the MSIV LCS subsystems lined up to the main steam lines and is normally performed as part of SR 3.6.1.9.3.
Verify that each blower develops, at the rated 24 months capacity, ~15" H20 vacuum at ~200 scfm on the outboard subsystem.
SR TR3.6.1.9.7 Perform a CHANNEL CALIBRATION of the inboard 24 months and outboard pressure instrumentation.
3.6-26-1 LBDCR 13013
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3. 6.2. 1. 1 Perform a CHANNEL CHECK. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR TR3. 6.2. 1. 2 Perform a CHANNEL FUNCTIONAL TEST. 366 days SR TR3. 6.2.1.3 Perform a CHANNEL CALIBRATION. 24 months TRM 3.6-29-II LBDCR 13013
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3. 6.2.2.1 Perform a CHANNEL CHECK. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR TR3. 6 . 2 . 2 . 2 Perform a CHANNEL FUNCTIONAL TEST. 366 days SR TR3. 6.2.2. 3 Perform a CHANNEL CALIBRATION. 24 months TRM 3.6-30-11 LBDCR 13013
TR3.6.3.2 Primary Containment Hydrogen Recombiner LCO TR3. 6 . 3 . 2 One Primary Containment Hydrogen Recombiner shall be OPERABLE.
APPLICABILITY: When both divisions of hydrogen igniters are inoperable, requiring entry to TS 3.6.3.2 Condition B
NOTE-------------------------------------------
Refer to Technical Specification 8 3.6.3.2 Actions 8.1 and B.2 regarding recombiner function.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. With no hydrogen A. 1 En t e r TS 3. 6 . 3 . 2 Condition Immediately recombiner OPERABLE. C.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3. 6. 3.2. 1 Perform a FUNCTIONAL TEST for the hydrogen 24 months recombiner.
. SR TR3. 6. 3.2.2 Visually examine the Primary Containment 24 months Hydrogen Recombiner enclosure and verify there is no evidence of abnormal conditions.
SR TR3.6.3.2.3 Perform a resistance to ground test for each 24 months heater phase.
SR TR3.6.3.2.4 Perform a CHANNEL CALIBRATION on control room 24 months recombiner indication instrumentation and control circuits.
NOTE---------------------------------------
The following surveillance requirement applies to LCO 3.6.5.2. Failure to met this surveillance requirement requires entry into LCO 3.6.5.2.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.6.5.2.1 Deleted NA SR TR3.6.5.2.2 Verify drywell air lock seal flask pressure is 7 days
~ 90 psig.
SR TR3.6.5.2.3 Verify from an initial pre sure of 90 psig, the 24 months drywell air lock seal pneumatic system pressure does not decay at a rate equivalent to > 30 psig for a period of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
SR TR3.6.5.2.4 Deleted NA T~ 3.6 I LBDCR 13013
TRM TR3.6 CONTAINMENT SYSTEMS TR3.6.5.2 Drywell Air Lock Instrumentation LCO TR3.6.5.2 Two drywell airlock inflatable seal system seal pressure instrumentation channels per airlock door shall be OPERABLE.
APPLICABILITY: When associated air lock is OPERABLE per LCO 3.6.5.2.
ACTIONS
NOTES---------------------------------------
- 1. Separate Condition entry is allowed for each airlock door.
- 2. LCO 3.0.3 is not applicable.
CONDITION REQUIRED ACTION COMPLETION TIME A. One drywell airlock A.l Restore required channel to 7 days inflatable seal system OPERABLE status.
pressure instrumentation channel inoperable.
B. Required Action and B.1 Verify the associated Once per 12 Hours associated Completion Time inflatable seal pressure to of Condition A not met. be ~ 60 psig.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3~6.5.2.5 Perform a CHANNEL FUNCTIONAL TEST. 24 months SR TR3.6.5.2.6 Perform a CHANNEL CALIBRATION with a low 24 months pressure setpoint of ~ 60 psig.
D. Required Action and 0.1 Enter the Conditions and Immediately associated Completion Time Required Actions for of Condition A or C not associated component or met. subsystem made inoperable, as applicable.
OR One or two required SSW subsystem inoperable.
OR UHS basin inoperable for reasons other than Condition C.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.7.1.1 Verify the water level of each required UHS 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> basin is ~ 7.25 ft.
SR TR3. 7 . 1. 2 operate each SSW cooling tower fan for ~ 15 31 days minutes.
SR TR3.7.1.3 Verify each required SSW subsystem manual, power 31 days operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.
SR TR3.7.1.4 Verify each SSW subsystem actuates on an actual or 24 months simulated initiation signal.
SR TR3. 7 . 1. 5 -------------------NOTE--------------------------- 24 months An OPERABLE basin shall have a 30 day supply of water either self-contained or by means of an OPERABLE siphon.
Verify the operability of the SSW siphon line TRM 3.7 II LBDCR 13013
TR3.7 PLANT SYSTEMS TR3.7.2 High Pressure Core Spray (HPCS) Service Water System (SWS) - Shutdown LCO TR3.7.2 The HPCS SWS shall be OPERABLE. The system is considered OPERABLE when:
- a. The HPCS service water pump is operable, and
- b. The associated piping, valves, instrumentation, and controls required to perform required support functions are OPERABLE.
APPLICABILITY: MODES 4 and 5, when the HPCS system is required to be OPERABLE.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. HPCS SWS inoperable. A.l Declare the HPCS System Immediately inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.7.2.1 Verify each required HPCS SWS manual, power 31 days operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, ~s in the correct position.
SR TR3.7.2.2 Verify, during shutdown, the HPCS SWS actuates on 24 months an actual or simulated initiation signal.
NOTE----------------------------------------
The following surveillance requirements apply to LCO 3.8.1. Failure to meet these surveillance requirements requires entry into LCO 3.8.1.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.8.1.1 Verify the diesel generator is aligned to provide 31 days standby power to the associated emergency busses.
SR TR3.8.1.2 -----------------------NOTE-----------------------
Inspections that require a retest that cannot be performed on-line, shall not be performed in MODE 1, or 2.
Subject the diesels to an inspection, commensurate Inspection for nuclear standby service, that takes into frequencies for consideration the following factors: the the various manufacturer's recommendations, diesel owners inspections are group recommendations, engine run time, calendar identified in the time, and the GGNS comprehensive maintenance approved inspection program. maintenance program.
SR TR3. 8 . 1. 3 -----------------------NOTE-----------------------
This Surveillance shall not be performed in MODE 1 or 2. ~(Not applicable to DG 13)"
Verify that the auto-connected loads to each 24 months diesel generator do not exceed 5740 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13.
(continued)
SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR TR3.8.1.4 ----------------------NOTES-----------------------
- 1. This Surveillance shall not be performed in MODE 1, 2 or 3.
- 2. All DG starts may be preceded by an engine prelube period.
Verify, when started simultaneously from standby After any condition, each DG achieves: modifications which could
- a. in $ 10 seconds, voltage ~ 3744 V and frequency affect OG
~ 58.8 Hz; and interdependence
- b. steady state voltage ~ 3744 V and $ 4576 V and frequency ~ 58.8 Hz and $ 61.2 Hz.
SR TR3. 8 . 1. 5 Perform a pressure test of those portions of the 10 years diesel fuel oil system designed to Section III, subsection NO of the ASME Code in accordance with ASME Code Section XI, Article IWD-SOOO.
SR TR3.8.1.6 Verify each DG automatic critical protective 24 months functions trip the OG (
Reference:
GNRO-2005/00056, GNRI-2006/00006). The critical protective functions are Engine Overspeed and Generator Differential Current (
Reference:
UFSAR 8.3.1.1.4.1.f(2) and 8.3.1.2.1.b.5. (g>>.
TR3.9 REFUELING OPERATIONS TR3.9.5 Control Rod Scram Accumulator Alarms LCO TR3.9.5 Each control rod scram accumulator alarm shall be OPERABLE.
APPLICABILITY: When associated control rod scram accumulator is OPERABLE per LeO 3.9.5.
ACTIONS
NOTE-------------------------------------
Separate Condition entry is allowed for each control rod scram accumulator alarm.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more accumulator A.1 Verify the affected Once per 24 pressure detectors or accumulator pressure ~ hours alarms inoperable. 1520 psig.
B. One or more accumulator B.1 Verify the affected Once per 48 leak detectors or accumulator water hours alarms inoperable. drained.
AND Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to reactor startup.
C. Required Action and C.1 Declare the associated Immediately associated Completion accumulator inoperable.
Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR TR3.9.5.1 Perform a CHANNEL FUNCTIONAL TEST on the 24 months leak detector and associated alarm for each control rod scram accumulator.
SURVEILLANCE FREQUENCY SR TR3. 9.5.2 Perform a CHANNEL CALIBRATION of the 24 months pressure detector for each control rod scram accumul~tor and verify an alarm setpoint ~
1520 psig on decreasing pressure.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 6.3.2.1 Perform a CHANNEL CHECK on required triaxial 92 days strong motion accelerometers, triaxial seismic switches, vertical seismic trigger and horizontal seismic trigger.
SR 6.3.2.2 Perform a CHANNEL FUNCTIONAL TEST on required 6 months triaxial strong motion accelerometers, triaxial seismic switches, vertical seismic trigger and horizontal seismic trigger.
SR 6.3.2.3 Perform a CHANNEL CALIBRATION on all required 24 months seismic monitoring instruments.
SR 6.3.2.4 -----------------------NOTE-----------------------
Not required to be performed until intrument is actuated by. a seismic event ~ 0.01 g.
Restore to operable. 24 hours AND Perform a CHANNEL CALIBRATION. 5 days AND Initiate action to prepare and submitt a Special Immediately Report to the Commission within 10 days describing the magnitude, frequency spectrum and resultant effect upon unit features important to safety.
SURVEILLANCE REQUIREMENTS
NOTE---------------~-----------------------
When a channel is placed in an inoperable status solely for performance of required surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, provided that the trip Function capability is maintained.
SURVEILLANCE FREQUENCY SR 6.3.7.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 6.3.7.2 Perform a CHANNEL FUNCTIONAL TEST. 366 days
. SR 6.3.7.3 Perform a CHANNEL CALIBRATION. The Allowable 24 months Value shall be ~ 56.7 inches and ~ 55.3 inches.
The Trip Setpoint shall be 56.0 inches, nominal.
The Trip Output Relay Time Delay shall be ~ 1.1 seconds and ~ 0.90 seconds with a nominal setting of 1.0 second.
SR 6.3.7.4 Perform a LOGIC SYSTEM FUNCTIONAL TEST and 24 months simulated automatic operation of all channels.
SURVEILLANCE REQUIREMENTS
NOTE----------------------------------------
The provisions of SR 3.0.4 are not applicable.
SURVEILLANCE FREQUENCY SR 6.3.8.1 Cycle each of the following valves through at 92 days least one complete cycle from the running position using the manual test or Automatic Turbine Tester (ATT):
EC 48550 approves a
- 1) Four high pressure turbine stop valves, one time extension
- 2) Four high pressure turbine control valves, of surveillance
- 3) Six low pressure turbine stop valves, and 6.3.8.1. The
- 4) Six low pressure turbine control valves. extension is for 131 days from 10/1/13. The testing frequency will return to the 92 day interval following this one time extension.
SR 6.3.8.2 Test the two mechanical overspeed devices using 8 weeks the Automatic Turbine Tester or manual test.
SR 6.3.8.3 Disassemble at least one of each type of the 48 months following valves and performing a visual and surface inspection of valve seats, disks and stems and verifying no unacceptable flaws. If unacceptable flaws are found, all other valves of that type shall be inspected.
- 1) Four high pressure turbine stop valves,
- 2) Four high pressure turbine control valves,
- 3) Six low pressure turbine stop valves, and
- 4) Six low pressure turbine control valves.
TRM 6.3-18 LBDCR 13013 & 14001
SURVEILLANCE REQUIREMENTS
NOTE-------------------~------------------
Refer to Table 6.3.11-1 to determine which SRs apply to each channel.
SURVEILLANCE FREQUENCY SR 6.3.11.1 Perform CHANNEL CHECK. 31 days SR 6.3.11.2 Perform a CHANNEL FUNCTIONAL TEST. 92 days SR 6.3.11.3 Perform a CHANNEL CALIBRATION. 12 months SR 6.3.11.4 -------------------NOTE--------------------------- 24 months The allowable value for calibration of Function 7, safety/relief valve tail pipe pressure switch position indication, will be 30 +/- 5 psig.
Perform a CHANNEL CALIBRATION SR 6.3.11.5 Perform a CHANNEL CALIBRATION 92 days T~ 6.3-21 LBDCR 13013
6.7. PLANT SYSTEMS 6.7.5 FLOOD PROTECTION LCO 6.7.5 The downstream access road slope at Culvert No. 1 and the drainage basin slopes shall remain stable. Blockage of Culvert No.1 shall be
~ 45% of its cross-sectional area. Blockage of Culverts No. SA, 9A, and 11 shall be less than or equal to 45% of its cross-sectional area.
APPLICABILITY: At all times.
ACTIONS
NOTES---------------------------------------
LCO 3.0.3 and LCO 3.0.4 are not applicable.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the above A.l Clean the Culvert. 7 days requirements not met.
AND A.2 Verify the slope 7 days embankments stable.
B. Required Action and B.l Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> TRM 6.7-10 LBDCR 13007
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 6.7.5.1 Perform a visual inspection of the embankments and 1 year Culvert No.1 to verify within above limits.
Perform a visual inspection of Culverts 8A, 9A, AND and 11 to verify within above limits.
Following the occurrence of earthquakes, hurricanes, tornados, or intense local rainfalls.
SR 6.7.5.2 Perform a survey to confirm no significant 5 years degradation to the base-line slope stability data.
On CuIvert 1. AND Following a visual inspection in which there is evidence of change.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 6.8.1.1 -----------------------NOTE-----------------------
For each circuit breaker found inoperable during the performance of SR 6.8.1.1b, an additional representative sample of at least 15% of all the circuit breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested.
Select, on a rotating basis, a sample of at least 24 months 15% of the 6.9 kV circuit breakers and perform:
- a. A CHANNEL CALIBRATION of the associated protective relays.
AND
- b. An integrated system functional test which includes simulated automatic actuation of the system and verifying that each relay and associated circuit breakers and overcurrent control circuits function as designed and as specified in Table 6.8.1-1.
SR 6.8.1.2 --------------------------NOTE--------------------
For each circuit breaker found inoperable during these functional tests, an additional representative sample of at least 15% of all the circuit breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested.
Functionally test on a rotating basis, a 24 months representative sample of at least 15% of each type of lower voltage circuit breakers. Testing of these circuit breakers shall consist of injecting a current in excess of 120% of each breaker's nominal setpoint and measuring the response time.
The measured response time will be compared to the manufacturer's data to insure that it is less than or equal to a value specified by the manufacturer.
Circuit breakers found inoperable during functional testing shall be restored to OPERABLE status prior to resuming operation of the affected equipment.
(continued TRM 6.8-3 LBDCR 13013
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 6.8.2.1 -----------------------NOTE----------------------- Following periodic Only applicable to thermal overload protection or maintenance which is continuously bypassed and temporarily testing during placed in force only when the valve motor is which the thermal undergoing periodic or maintenance testing. overload protection was Verify that the thermal overload protection is temporarily placed bypassed. in force.
SR 6.8.2.2 -----------------------NOTE-------~--------------- 48 months Only applicable to thermal overload protection which is not bypassed Perform a CHANNEL CALIBRATION on a representative sample of at least 33.3% of all thermal overloads.
for the above required valves.
SR 6.8.2.3 -----------------------NOTE----------------------- Following Only applicable to thermal overload protection maintenance on the which is continuously bypassed and temporarily motor starter.
placed in force only when the valve motor is (Work requiring undergoing periodic or maintenance testing. the lifting of MOV control circuit Verifying by performance of a functional check wires at the Motor that the thermal overload protection is bypassed. Control Center)
SR 6.8.2.4 -----------------------NOTE----------------------- 24 months Only applicable to thermal overload protection which is normally in force during plant operation AND and bypassed under accident conditions.
Following Perform a CHANNEL FUNCTIONAL TEST of the maintenance on the individual valve portion of the bypass circuitry. motor starter.
(Work requiring the lifting of MOV control circuit wires at the Motor Control Center)
SR 6.8.2.5 -----------------------NOTE----------------------- 18 months Only applicable to thermal overload protection which is normally in force during plant operation AND and bypassed under accident conditions.
Following Perform a CHANNEL FUNCTIONAL TEST of the ECCS maintenance on the portion of the bypass circuitry. motor starter.
(Working requiring the lifting of MOV control circuit wires at the Motor
. Control Center)
7.0 ADMINISTRATIVE CONTROLS 7.1 Deleted 7.2 ORGANIZATION 7.2.1 The following are the plant specific titles for the personnel fulfilling responsibilities of positions delineated in Technical Specifications:
- a. The corporate executive responsible for overall plant nuclear safety is the Vice President, Operations.
- b. The Plant manager is the General Manager, Plant Operations.
- c. The shift superintendent is the Shift Manager (SM).
- d. A non-licensed operator is a Nuclear Operator B.
- e. The operations manager is the Manager, Operations.
- f. The operations middle managers are the Assistant Operations Manager, Shift and Assistant Operations Manager, Support.
- g. The radiation protection manager is the Manager, Radiation Protection.
- h. A health physics technician is an individual certified as a Senior Health Physicist.
- i. Health Physics supervision is Radiation Protection personnel, Specialist and above.
7.2.2 As required by 10 CFR 50.54 and Technical Specifications 5.2.2.a and 5.2.2.g except as allowed by Technical Specification 5.2.2.c, each on duty shift shall be composed of at least minimum shift crew composition shown in Table 7.2.2-1. Licensed Personnel shall meet or exceed the criteria of the accredited license training program.
7.2.3 As required by 10 CFR 50.54, all CORE ALTERATIONS shall be observed and directly supervised by either a licensed Senior Reactor Operator or Senior Reactor Operator Limited to Fuel Handling who has no other concurrent responsibilities during this operation.
7.2.4 The Shift Managers, and Control Room Supervisors, shall each hold a Senior Reactor Operators License.
7.2.5 Not Used 7.2.6 INDEPENDENT SAFETY ENGINEERING GROUP (ISEG)
- g. The following are clarifications of the required testing frequency and other requirements:
- 1. Deleted
- 2. At least once per 18 months, during plant or system shutdown, demonstrate the SBLC pump relief valve opens within 3% of the system design pressure and verify that the SBLC relief valve does not actuate during recirculation to the test tank.
7.6.3.4 FILTER TESTING PROGRAM In addition to the requirements of Technical Specification 5.5.7 the following requirements apply to the filter testing program:
- a. The testing requirements of Technical Specification 5.5.7.a will be performed at least once per 24 months or (1) after any structural maintenance on the HEPA filter (2) following painting, fire or chemical release in any ventilation zone communicating with the subsystem, or (3) after each complete or partial replacement of a HEPA filter bank.
- b. The testing requirements of Technical Specification 5.5.7.b will be performed at least once per 24 months or (1) after any structural maintenance on the charcoal adsorber housings, (2) following painting, fire or chemical release in any ventilation zone communicating with the subsystem, or (3) following each complete or partial replacement of a charcoal adsorber bank.
- c. The testing requirements of Technical Specification 5.5.7.c will be performed at least once per 24 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, (2) following painting, fire or chemical release in any ventilation zone communicating with the subsystem, or (3) every 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of charcoal adsorber operation. The representative carbon sample will be tested within 31 days following removal.
- d. The testing requirements of Technical Specification 5.5.7.d will be performed at least once per 24 months.
- e. The testing requirements of Technical Specification 5.5.7.e will be performed at least once per 18 months.
T~ 7-6 LBDCR 13013
- b. a determination that the change will maintain the overall conformance of the solidified waste product to existing requirements of Federal, State, or other applicable regulations.
Shall become effective upon review and acceptance by the OSRC and the approval of the General Manager, Plant Operations.
7.6.3.9 OFFSITE DOSE CALCULATION MANUAL (ODCM)
Licensee initiated changes to the ODCM shall become effective upon review and acceptance by the OSRC.
7.6.3.10 SNUBBER PROGRAM 7.6.3.10.1 Snubber testing and visual examinations will be performed in accordance with the ASME OM Code Subsection ISTD and applicable addenda as required. Code Case OMN-13 may be used to extend the visual examination interval allowed by Table ISTD-4252-1 provided additional service life monitoring requirements are met.
7.6.3.10.2 Deleted 7.6.3.10.3 Deleted 7.6.3.11 INSTRUMENT SETPOINTS AS-FOUND AND AS-LEFT TOLERANCES Entergy Nuclear Management Manual (NMM) Procedure EN-DC-200, "I&C Uncertainties / Setpoint Calculations & Determinations," establishes direction for the performance of instrument uncertainty / setpoint calculations including determining the as-found tolerance (AFT) and as-left tolerance (ALT). NMM Procedure EN-IC-S-010-MULTI, "Instrument Uncertainty and Setpoint Calculation Methodology,"
provides examples using a standard methodology for determination of instrument uncertainties, loop uncertainties, instrument setpoints and instrument setpoint attributes (As-Left Tolerance, As-Found Tolerance, Allowable Value, etc.).
TECHNICAL REQUIREMENTS MANUAL BASES GGNS TRM BASES GGNS TRM BASES BASE~ FOR RELOCATED TECHNICAL SPECIFICATION REQUIREMENTS (TRM)
This Section contains bases discussions for the Technical Requirements Manual.
B 6.3.1 RADIATION MONITORING INSTRUMENTATION The OPERABILITY of the radiation monitoring instrumentation ensures that:
- 1. the radiation levels are continually measured in the areas served by the individual channels;
- 2. the alarm or automatic action is initiated when the radiation level trip setpoint is exceeded; and
- 3. sufficient information is available on selected plant parameters to monitor and assess these variables following an accident. This capability is consistent with the recommendations of NUREG-0737, "Clarification of TMI Action Plan Requirements," November 1980.
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.
B 6.3.2 SEISMIC MONITORING INSTRUMENTATION The OPERABILITY of the seismic monitoring instrumentation ensures that sufficient capability is available to promptly determine the magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to permit comparison of the measured response to that used in the design basis for the unit.
B 6.3.3 METEOROLOGICAL MONITORING INSTRUMENTATION The OPERABILITY of the meteorological monitoring instrumentation ensures that sufficient meteorological data are available for estimating potential radiation doses to the public as a result of routine or accidental release of radioactive materials to the atmosphere. This capability is required to evaluate the need for initiating protective measures to protect the health and safety of the public. This instrumentation is consistent with the recommendations of Regulatory Guide 1.23 "Onsite Meteorological Programs," February 1972.
B 6.3.4 TRAVERSING IN-CORE PROBE SYSTEM The OPERABILITY of the traversing in-core probe system with the specified minimum complement of equipment ensures that the measurements obtained from use of this equipment accurately represent the spatial neutron flux distribution of the reactor core.
The TIP system OPERABILITY is demonstrated by normalizing all operable probes (i.e., detectors) prior to performing an LPRM calibration function. The core monitoring system can also calculate LPRM gain adjustment factors for LPRM strings not scanned by the TIP system (one TIP machine out of service or up to the number of strings equivalent to one TIP machine out of service) .
TECHNICAL REQUIREMENTS MANUAL BASES GGNS TRM BASES B 6.3.5 LOOSE PART DETECTION SYSTEM - Deleted B 6.3.6 MAIN CONDENSER OFFGAS TREATMENT SYSTEM - EXPLOSIVE GAS MONITORING SYSTEM INSTRUMENTATION The explosive gas monitoring system instrumentation of the main condenser off gas treatment system is provided to monitor the concentrations of potentially explosive gas mixtures in the main condenser off gas treatment system. This instrumentation is calibrated in accordance with plant procedures.
B 6.3.8 TURBINE OVERSPEED PROTECTION This specification is provided to ensure that the turbine overspeed protection instrumentation and the turbine speed control valves are OPERABLE and will protect the turbine from excessive overspeed.
Protection from turbine excessive overspeed is required since excessive overspeed of the turbine could generate potentially damaging missiles which could impact and damage safety-related components, equipment or structures. For any valves which become INOPERABLE UFSAR section 3.5.1.3 shall be reviewed for affect on the probability analysis to ensure risk is appropriately addressed.
B 6.3.12 Ultrasonic Flowmeter - Deleted TRM TRB-2 LBDCR 13020
TECHNICAL REQUIREMENTS MANUAL BASES GGNS TRM BASES B 6.3.12 Deleted B 6.4.1 CHEMISTRY The water chemistry limits of the reactor coolant system are established to prevent damage to the reactor materials in contact with the coolant.
Chloride limits are specified to prevent stress corrosion cracking of the stainless steel. The effect of chloride is not as great when the oxygen concentration in the coolant is low, thus the 0.2 ppm limit on chlorides is permitted during power operation. During shutdown and refueling operations, the temperature necessary for stress corrosion to occur is not present so a 0.5 ppm concentration of chlorides is not considered harmful during these periods~
Conductivity measurements are required on a continuous basis since changes in this parameter are an indication of abnormal conditions. When the conductivity is within limits, the pH, chlorides and other impurities affecting conductivity must also be within their acceptable limits. With the conductivity meter inoperable, additional samples must be analyzed to ensure that the chlorides are not exceeding the limits.
The surveillance requirements provide adequate assurance that concentrations in excess of the limits will be detected in sufficient time to take corrective action7 B 6.7.2 SEALED SOURCE CONTAMINATION The limitation on removable contamination for sources requiring leak testing, including alpha emitters, is based on 10 CFR 70.39(c) limits for plutonium. This limitation will ensure that leakage from byproduct, source, and special nuclear material sources will not exceed allowable intake values. Sealed sources are classified into three groups according to their use, with surveillance requirements commensurate with the probability of damage to a source in that group. Those sources which are frequently handled are required to be tested more often than those which are not. Sealed sources which are continuously enclosed within a shielded mechanism, i.e., sealed sources within radiation monitoring or boron measuring devices, are considered to be stored and need not be tested unless they are removed from the shielded mechanism.
B 6.7.3 AREA TEMPERATURE MONITORING The area temperature limitations ensure that safety-related equipment will not be subjected to temperatures in excess of their environmental qualification temperatures. Exposure to excessive temperatures may degrade equipment and can cause loss of its OPERABILITY. The temperature limits include allowance for instrument error7 B 6.7.4 SPENT FUEL STORAGE POOL TEMPERATURE The temperature limit in the spent fuel storage pool ensures proper pool cooling to maintain building accessibility and prevents unacceptable radiological releases particularly during those times of increased fuel pool cooling heat loads, such as a fuel core offload, when supplemental fuel pool cooling utilizing the RHR system is required.
TECHNICAL REQUIREMENTS MANUAL BASES GGNS TRM BASES B 6.7.5 FLOOD PROTECTION The required stability of the downstream slope of the access road embankment and the limit on the maximum permissible blockage of Culvert No. 1 are intended to ensure that Culvert No. 1 is always functional, because, in the event the culvert is blocked, flooding of the plant and safety-related facilities could occur during a PMP event.
The limit on the maximum permissible blockage of Culverts No. 8A, 9A, and 11 are intended to ensure that Culverts No. 8A, 9A, and 11 are always func~ional, because, in the event the culverts are blocked, flooding of the plant and safety-related facilities could occur during a Localized Intense Precipitation event.
B 6.7.6 STRUCTURAL INTEGRITY The inspection programs for ASME Code Class 1, 2, and 3 components ensure that the structural integrity of these components will be maintained at an acceptable level throughout the life of the plant.
Components of the reactor coolant system were designed to provide access to permit inservice inspections in accordance with Section XI of the ASME Boiler and Pressure Vessel Code, 1977 Edition, and Addenda through Summer 1978.
The inservice inspection program for ASME Code Class 1, 2 and 3 components will be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR Part 50.55a(g) except where specific written relief has been granted by the NRC pursuant to 10 CFR Part 50. 55a (g) (6) (i) .
B 6.8.1 PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES Primary containment electrical penetrations and penetration conductors are protected by either de-energizing circuits not required during reactor operation or demonstrating the OPERABILITY of primary and backup overcurrent protection circuit breakers by periodic surveillance.
The surveillance requirements applicable to lower voltage circuit breakers provide assurance of breaker reliability by testing at least one representative sample of each manufacturer's brand of circuit breaker. Each manufacturer's molded case and metal case circuit breakers are grouped into representative samples which are then tested on a rotating basis to ensure that all breakers are tested. If a wide variety exists within any'manufacturer's brand of circuit breakers, it is necessary to divide that manufacturer's breakers into groups and treat each group as a separate type of breaker for surveillance purposes.
The OPERABILITY or bypassing of the motor operated valve thermal overload protection continuously or under accident conditions by integral bypass devices ensures that the thermal overload protection during accident conditions will not prevent safety-related valves from performing their function. The surveillance requirements for demonstrating the OPERABILITY or bypassing of the thermal overload protection continuously and or during accident conditions are in accordance with Regulatory Guide 1.106, "Thermal Overload Protection for Electric Motors on Motor Operated Valves," Revision 1, March 1977.
TRM TRB-4 LBDCR~, 13020
TECHNICAL REQUIREMENTS MANUAL BASES G~ST~ BASES B 6.8.2 MOTOR OPERATED VALVES THERMAL OVERLOAD PROTECTION The OPERABILITY or bypassing of the motor operated valve thermal overload protection continuously or under accident conditions by integral bypass devices ensures that the thermal overload protection during accident conditions will not prevent safety-related valves from performing their function. The surveillance requirements for demonstrating the OPERABILITY or bypassing of the thermal overload protection continuously and or during accident conditions are in accordance with Regulatory Guide 1.106, "Thermal Overload Protection for Electric Motors on Motor Operated Valves," Revision 1, March 19777 B 6.9.1 DECAY TIME The minimum requirement for reactor subcriticality prior to fuel movement ensures that sufficient time has elapsed to allow the radioactive decay of the short lived fission products. This decay time is consistent with the assumptions used in the accident analyses.
B 6.9.2 COMMUNICATIONS The requirement for communications capability ensures that refueling station personnel can be promptly informed of significant changes in the facility status or core reactivity condition during movement of fuel within the reactor pressure vessel.
B 6.9.3 REFUELING PLATFORM The OPERABILITY requirements in conjunction with 6.9.4 and 6.9.5 ensure that:
- 1. only the main hoist of the refueling platform or the main hoist of the fuel handling ~latform will be used for handling fuel assemblies within the reactor pressure vessel,
- 2. platform hoists have sufficient load capacity for handling fuel assemblies and/or control rods,
- 3. the core internals and pressure vessel are protected from excessive lifting force in the event they are inadvertently engaged during lifting operations, and
- 4. a fuel bundle is protected from excessive lifting force in the event it becomes stuck during lifting operations.
B 6.9.4 AUXILIARY PLATFORM See the discussion for 6.9.3.
B 6.9.5 FUEL HANDLING PLATFORM See the discussion for 6.9.3.
TECHNICAL REQUIREMENTS MANUAL BASES G~ST~ BASES B 6.9.6 CRANE TRAVEL - SPENT FUEL AND UPPER CONTAINMENT FUEL STORAGE POOLS The restriction on the movement of a non-fuel load defined as a heavy load in NUREG-0612 over fuel assemblies in the storage pools ensures that in the event this load is dropped:
- 1. the activity release will be bounded by the activity release in the safety analysis, and
- 2. any possible distortion of fuel in the storage racks will not result in a critical array.
B 6.9.7 HORIZONTAL FUEL TRANSFER SYSTEM The purpose of the horizontal fuel transfer system specification is to control personnel access to those potentially high radiation areas immediately adjacent to the system and to assure safe operation of the system.
B 7.6.3.3 INSERVICE INSPECTION AND TESTING PROGRAMS This specification establishes the requirement that inservice inspection of ASME Code Class 1, 2 and 3 components and inservice testing of ASME Code Class 1, 2, and 3 pumps and valves shall be performed in accordance with a periodically updated version of Section XI of the ASME Boiler and Pressure Vessel Code and Addenda as required by 10 CFR 50.55a. These requirements apply except when relief has been provided in writing by the Commission.
This specification includes a clarification of the frequencies for performing the inservice inspection and testing activities required by Section XI of the ASME Boiler and Pressure Vessel Code and applicable addenda. This clarification is provided to ensure consistency in surveillance intervals throughout the technical specifications and to remove any ambiguities relative to the frequencies for performing the required inservice inspection and testing activities.
Under the terms of this specification, the more restrictive requirements of the technical specifications take precedence over the ASME Boiler and Pressure Vessel Code and applicable addenda. The requirements of the technical specifications to perform surveillance activities before entry into a MODE or other specified condition takes precedence over the ASME Boiler and Pressure Vessel Code provision that allows pumps to be tested up to one week after return to normal operation. The technical specification definition of OPERABLE does not allow a grace period before a component, which is not capable of performing its specified function, is declared inoperable and takes precedence over the ASME Boiler and Pressure Vessel Code provision that allows a valve to be incapable of performing its specified function for up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> before being declared inoperable.
T~ TRB-6 LBDCR 13020
TECHNICAL REQUIREMENTS MANUAL BASES GGNS TRM BASES B 7.6.3.10 SNUBBERS The snubber testing and visual inspection program will be performed in accordance with ASME OM Code Subsection ISTD and applicable addenda as required by 10 CFR 50.55a.