ML15085A227
| ML15085A227 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 04/14/2015 |
| From: | Wang A Plant Licensing Branch IV |
| To: | Entergy Operations |
| Wang A | |
| References | |
| TAC MF2798 | |
| Download: ML15085A227 (61) | |
Text
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001
/µil 14, a):J5 Vice President, Operations Entergy Operations, Inc.
Grand Gulf Nuclear Station P.O. Box 756 Port Gibson, MS 39150
SUBJECT:
GRAND GULF NUCLEAR STATION, UNIT 1-OCTOBER15, 2014, ONSITE AUDIT REPORT REGARDING MAXIMUM EXTENDED LOAD LINE LIMIT ANALYSIS PLUS (TAC NO. MF2798)
Dear Sir or Madam :
By letter dated September 25, 2013 (Agencywide Documents Access and Management System Accession No. ML13269A140), Entergy Operations, Inc. (the licensee) , submitted a license amendment request for Maximum Extended Load Line Limit Analysis Plus (MELLLA+). The proposed amendment request would revise the Grand Gulf Nuclear Station , Unit 1 (GGNS)
Technical Specifications to allow operation in the expanded MELLLA+ domain .
An audit was held on October 15, 2014, at the GGNS in Port Gibson, Mississippi. To support the schedule for issuing the proposed amendment, the U.S. Nuclear Regulatory Commission (NRC) staff requested an audit regarding several issues, including the implementation of the Detect and Suppress Solution-Confirmation Density, review of the Supplemental Reload Licensing Report and Traversing lncore Probe Report, simulator exercises/emergency operating procedures, and confirmation of the feasibility of manual actions.
The NRG staff's Audit Report is provided as Enclosure 1 with Appendices Band C as Enclosures 2 and 3, respectively. If you have any questions regarding the Audit Report, please contact me at (301) 415-1445 or by e-mail at Alan.Wang@nrc.gov.
Sincerely,
~\jJ~
Alan B. Wang, Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-416
Enclosures:
- 1. Audit Report
- 2. Appendix B
- 3. Appendix C cc w/encls: Distribution via Listserv
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 AUDIT REPORT MAXIMUM EXTEN DED LOAD LINE LIMIT ANALYSIS PLUS ENTERGY OPERATIONS, INC.
GRAND GU LF NUCLEAR STATION, UNIT 1 DOCKET NO. 50-416
- 1. SCOPE AND PURPOSE The US Nuclear Regulatory Comm ission (NRC) staff performed an onsite audit for the implementation of the Maximum Extende d Load Line Limit Analysis Plus (MELLLA+) operating domain extension , stability long-term sol utions, and the impact of the domain extension on instability and anticipated transient wi th out scram (ATWS) at the Grand Gulf Nuclear Station, Unit 1 (GGNS) on October 15, 2014. The main purpose of the audit was to understand the validity of the 90 seconds operator action time that the licensee assumed during potential instability scenarios in the transient analyses.
The audit was conducted by the fo llowin g members of the NRC staff and a consultant from the Oak Ridge National Laboratory (ORNL):
- Ashley Guzzetta (NRC)
- George Thomas (NRC)
- Alan Wang (NRC)
- Brian Green (NRC)
- Karl Sturzebecher (NRC)
Entergy (the licensee) staff present at the audit included:
- Brandon Meyer
- Christian Conners
- Robert W. Fuller
- Richard Scarbrough
- Greg Broadbent
- Frank Weaver
- Ricky Liddell
- Matt Novogoratz
- Mike Bacon
- Gabe Kimich
- Rich Meister
- Taylor Coles Enclosure 1
- 2. AUDIT ACTIVITIES 2.1 Thermal-Hydraulic Stability Long-Term Solution Implementation For years, the stability long-term solution licensed for use at GGNS was Solution E1A, and GGNS's experience with this solution has been positive. As part of the extended power uprate (EPU) upgrade in 2012, GGNS installed the digital Nuclear Measurement Analysis and Control Power Range Monitor, which includes a stability long-term Option Ill and a Detect and Suppress Solution-Cc;mfirmation Density (DSS-CD), which is a "detect and suppress" option. These solutions are a modification to the reactor protection system (RPS), which shuts down the reactor if a power oscillation is detected. Both of these solutions were reviewed and approved by the NRC staff. Option Ill is approved for EPU use and it is currently installed and armed at GGNS. DSS-CD is approved for MELLLA+ use. It is currently installed at GGNS, but is not yet armed.
DSS-CD and Option Ill require the combination of local power range monitor (LPRM) signals in a series of oscillation power range monitor (OPRM) channels, which are similar in nature to the existing average power range monitor (APRM) channels, differing only on the LPRM grouping.
APRM channels attempt to average LPRM signals across the entire core. OPRM channels average LPRM signals from specific regions in the core, so that they can detect regional or out-of-phase oscillations. APRM channels are not sensitive to out-of-phase oscillations because they average them out. The LPRM groupings in the OPRM channels are designed to avoid this problem.
In the GGNS's implementation for the already approved EPU cycles, the licensing basis protection is provided by the standard Option Ill Period Based Detection Algorithm (PBDA). As with all standard Option Ill implementations, the other two defense-in-depth algorithms (growth rate and large oscillation algorithms) are present and would scram the reactor; however, no analysis is required to ensure that the defense-in-depth algorithms protect against specified acceptable fuel design limit's (SAFDL's) for every possible scenario. Only the PBDA setpoint value is determined to ensure that SAFDL's are protected with a high likelihood. General Electric Hitachi (GEH) has been performing the calculations for the OPRM setpoints using approved methods. The OPRM setpoints are reflected in the core operating limits report. All fresh GGNS fuel is supplied by GEH, and currently, GGNS has a full load of Global Nuclear Fuel (GNF)2 fuel.
As part of the MELLLA+ Safety Analysis Report, GEH has performed DSS-CD analysis for GNF2 fuel with the GGNS-chosen setpoint value of amplitude discriminator setpoint (SAo) = 1.10. The analyses demonstrate that this value provides acceptable results following a two-pump recirculation pump trip (2RPT}
2.1.1 Effect of EPU Operation on ATWS Emergency Operation Instructions GGNS has implemented the most recent Emergency Procedure Guidelines and Severe Accident Guidelines (EPG/SAG) Revision 2. The NRC staff reviewed the plant-specific emergency operating procedure's (EOPs) for ATWS procedures, which are implemented in the control room as flow charts that are used by the operators. These instructions were used in the plant simulator for a series of demonstration of ATWS events.
GGNS has 35 percent operating limit thermal power(OLTP) turbine bypass capability. Standby liquid control injects sodium pentaborate solution in the upper plenum through the core spray system. At GGNS, the feedwater spargers are located at approximately -46 inch level , and top of active fuel is located at-167 inch level. Net Positive Suction Head (NPSH) is not a concern for the GGNS emergency core cooling system .
The feedwater (FW) pumps are 100 percent steam driven , but they can use low-pressure steam or high-pressure steam upstream of the turbine stop valve. The transfer from low-pressure to high-pressure steam is automatic. Thus, following a turbine trip, the FW pumps are available.
GGNS is currently operating on 24 month cycles. The current licensed thermal power has been increased to 115 percent OLTP since the March-May 2012 outage.
Because GGNS only has turbine bypass capacity of 35 percent OLTP power, most ATWS.
scenarios that involve full control rod insertion failure lift some safety relief valves (SRVs) and result in some degree of reactor overpressure. And , as demonstrated in the simulator transients, manual water level control during ATWS events, with periodic SRV lifting is difficult and often results in. main steam isolation valve (MSIV) isolation as the water level reaches Level
- 1. Other boiling water reactors have a front panel key lock bypass of the Level 1 MSIV isolation, but in GGNS it requires an instrumentation and control technician to manually jumper the terminations in the back of the panel. This is a lengthy operation and it is not likely to be performed during an ATWS.
The GGNS EOPs contain the EPG/SAG recommendations to mitigate ATWS/Stability, which include: (1) prompt water level reduction to 2 ft. below the spargers, and (2) early boron injection. These ATWS mitigation actions will not be modified for MELLLA+ conditions, and should remain effective. In addition, Entergy has committed to ensure that all Grand Gulf operators initiate water level reduction by terminating FW injection within 90 seconds of transient initiation. This is classified as a critical performance action , and operators cannot pass the training if they don't achieve it.
The GGNS EOPs contain numerous cycle-specific parameters. These parameters are recalculated based on the loading pattern for each cycle to confirm that the existing procedures are applicable for the new cycle. Because GGNS already recalculates EOP-related parameters on a cycle-specific basis, the effect of EPU operation on the EOPs is captured by the existing procedures.
Current cycle EOP charts were reviewed by the NRC staff during the audit, and relevant sections are reproduced in Appendix C. In addition , the EOP charts were followed in the simulator during the simulated ATWS events. Two ATWS transients were performed in the plant simulator during the staff audit. The operators followed the EOPs, and the plant was brought to a safe shutdown for all transients without compromising core coolability or containment limits. The transients were repeated several times to allow the audit team to observe the operations in more detail. Graphical results of the simulator scenarios can be found in Appendix B.
In addition, GGNS performed a simulation of an instability following a loss of FW heater, and a "surprise" transient that involved a 2RPT and required an immediate scram.
The following transients were analyzed in the plant simulator:
- 1. Turbine trip with bypass and hydraulic ATWS (failure to insert rods) ,
- 4. 2RPT.
The transients were initiated at 115 percent OLTP (100 percent CLTP) and 80 percent recirculation flow, which is the most conservative MELLLA+ condition.
For the "surprise" event, the operators were told that they were going to repeat the previous ATWS Turbine Trip event so the audit team could observe the actions in more detail. Instead, the simulator chief introduced a 2RPT and allowed the control rods to be inserted if the operator initiated the scram. The operators were indeed surprised by the unexpected transient, but diagnosed the reactor condition and initiated a manual scram by placing the reactor switch to shutdown mode as required by technical specifications following a 2RPT. The whole simulation took less than 5 seconds.
Because GGNS has 100 percent steam driven FW pumps, which are the large-flow source of high-pressure, water injected into the core. EOPs direct the operator to partially depressurize below 600 pounds per square inch (psi) so that the motor-driven condensate pumps can be used as a source. For both transients 1 and 2 above, partial depressurization was necessary, as indicated by the EOPs. This becomes necessary once containment isolates either by the initial MSIV closure or as a result of a water-level-1-induced isolation.
The suppression pool heat capacity temperature limit or NPSH were not challenged in any of the scenarios tested.
The NRC staff paid special attention to the first 2 minutes of the transient. Recent ATWS-lnstability calculations have shown that large unstable power oscillations can be minimized if the water level is reduced early into the transient. A new operator time critical action has been set to terminate FW injection in less than 90 seconds from transient initiation. This action minimized the oscillations and permits the use of simplifying assumptions in the TRACG (or TRACE) analyses. Namely, if the water level is reduced promptly, oscillations are not large enough to reach the minimum stable film boiling temperature (Tmin).
For all the transients analyzed, the order to initiate water level control at a reduced elevation took significantly less than the 90 seconds allowed by the analyses (typically <60 seconds for the order and <90 seconds to terminate injection). During the early part of the transient, the operators were conducting the following: (1) transient identification, (2) initiating standby liquid control system (SLCS), (3) inhibit high-pressure core spray system and automatic depressurization system on low level , and (4) open SRVs to control pressure between 800 and 1000 psi .
Even though FW pumps are eventually not available following MSIV isolation at GGNS, the licensee can operate for up to 5 minutes with steam that remains stored in the secondary side of the MSIV. The operators utilized the FW pumps for a few minutes using this feature , which is modeled in the Grand Gulf simulator.
The simulator exercises were performed with licensed instructors. Entergy stated that they did not want to confuse their operators with different scenarios before the license amendment request (LAA) was approved. Entergy stated that they will train their operators only after they finalize the training plan and procedures.
The instructors stated that they don't expect the operator actions to be very much different than those that they are trained to now, Instructors were not reluctant to start the SLCS pumps and lowering the level to below the top of the fuel during the ATWS scenarios.
Overall, the GGNS operators promptly and effectively followed the EOPs, as instructed. The ATWS EOPs are not extremely time sensitive; the three operators can easily handle, in a timely manner, the actions required to bring this scenario to a safe shutdown.
3.0 CONCLUSION
S
- 1. The proposed long-term solution implementation in GGNS was reviewed by the NRC staff, and it appears to be complete and adequate to satisfy the requirements of a long-term solution up to MELLLA+ operating conditions. Note, that while the MELLLA+ LAA is under review, GGNS is operating with an unrealistically-high confirmation density algorithm (CDA) setpoint to prevent scrams (i.e. , the CDA solution is essentially disabled). Once MELLLA+ is implemented, the setpoint will be corrected according to the approved methodology.
- 2. GGNS personnel have shown good understanding of the issues related to instabilities and their long-term option Ill and DSS-CD implementation. Past operating experience from other plants has been incorporated in their procedures.
- 3. The GGNS EOPs implement the EPG/SAG Revision 2. These EOPs are adequate to manage ATWS events and to mitigate the consequences of unstable oscillations, should they occur during these events (i.e ., ATWS/stability) .
- 4. Because GGNS already recalculates EOP-related parameters on a cycle-specific basis, to confirm the applicability of the existing procedures , the effect of MELLLA+
operation on the EOPs is captured . EOPs and ATWS management strategies need not be modified for GGNS MELLLA+ operation.
- 5. The simulator transients were very helpful and both , the NRC staff and GGNS employees, learned from the experience.
The simulator results support the assumption of prompt water level control by terminating FW injection in less than 90 seconds.
Principal Contributor: Ashley S. Guzzetta, NRA Date: April 14, 2015
APPENDIX B. SIMULATOR RESULTS SIMULATOR RESULTS - LOSS OF FEEDWATER HEATER WITH UNSTABLE POWER OSCILLATIONS
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APPENDIX C. EMERGENCY OPERATING PROCEDURES RELEVANT TO ATWS PLANT OPERATIONS MANUAL Volume 05 05-S-01-EP-2
~:;!sio¢~1'-f Section 01 CONTINUOUS USE EMERGENCY PROCEDURE RPV CONTROL SAFETY RELATED Prepared:
I Reviewed: ¢"z ?~sz~
Technical Reviewer OSRC:
Approved: 3312&
ions List of Effective Pages:
Pages 1-3 EP-2 Flowchart dated 8/8/14 EP-2A Flowchart dated 8/8/14 CONTROLLED COPY _ _ __
List of TCNs Incorporated:
Revision TCN Revision TCN 0 None 23 12 10-11 None 24 13,14,15 12 1 25 16.17.18 13-15 None 26 None 16 2 27-28 None 17 3 (NI) 29 19 18 4,5 30-36 None 19 None 37 20 20 6,7,8 038-044 None 21 9 22 10, 11 J;:\ADM_SRVS\TECH_PUB\REVISION\5\05-S-01-EP-2.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
RPV Control No.: 05-S-01-EP-2 Revision : 044 Page: i RPTS FORM REQUIRED REVIEW PERFORMED D PAD D 50.59 Screen/Eval.
(Check all that apply) (EN-Ll-100) (EN-Ll-101)
D 72.48 Screen/Eva!. D 50 .54 Eval.
Transmit applicable Review Form as a (EN-Ll-112) (EN-NS-210) separate record along with procedure to /
Document Control. [!'J PAD Not Required(EN-Ll-100 or 01-S-02-3)
D Process Applicability Excluded 0Editorial Change D ISl/IST Implementation D TCN Incorporation or Auto Rev.
D Other Process-Number:
PAD Reviewer: 7, z 7 ~~~fl'= I (for PAD Not Required) ~~re/Date Jlht Cross-Disci line review re uired? Yes Note affected De artments Below Pre arer Initials>>>
Department Cross-Discipline Reviews Needed Signoff (signed, electronic, telcon)
Does this directive contain Tech Spec Triggers? ( ) YES ( X) NO J; :\ADM_SRVS\TECH_ PUB\REVISION\5\05-S-01-EP-2.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
RPV Control No.: 05-S-01-EP-2 Revision: 044 Page: ii REQUIREMENTS CROSS-REFERENCE LIST P24895 GNRl-91/00032 91-02-02.2.c(3),Para.2
- P22983 FSAR 18.1 .19.Response Para.4.S1
- P22984 FSAR 18.1.19.Response Para.4.S2
- P22985 FSAR 18.1.19.Response Para.4.S3
- P21983 FSAR 9.3.5.3.S36 '
- P24901 GNRl-91/00032 App.S.2.b, Page 8 (LCTS 16234)
- P32154 GNR0-9500043 ALL
- P32680 GNRl-96/00135 Enclosure (SER)
- P34703 FSAR 6.3.3.9.6.9.Para.3
- P31130 Tech Spec 5.4.1.b
- P35248 GNRO 02/00029 S.5.S *
- Covered by directive as a whole or by various paragraphs of the directive.
The Equipment Database (EDS) Request statement is applicable only to Volume 06 and 07 maintenance directives.
EDS Change Request generated and the backup documentation available for setpoint and/or calibration data only D Yes ~ NI A EDBCR # _ _ __
J;:\ADM_SRVS\TECH_PUS\REVISION\5\05-S-01-EP-2.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
RPV Control No.: 05-S-01 -EP-2 Revision: 044 Page: iii Current Revision Statement Revision 044:
- Updates EP2 and EP2A flow charts which Changes RPV Level band of -30 to +30 to -30 to
+50 inches for reactor water level control to align with 02-S-01 -43 , Transient Mitigation Strategy. This is in answer to CR 2014 3196 CA# 2 J;:\ADM_SRVS\TECH_PUB\REVISION\5\05-S-01 -EP-2.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
RPV Control No. : 05-S-01-EP-2 Revision: 044 Page: 1 TABLE OF CONTENTS Page 1.0 PURPOSE .......... .. .. ......................... ... .. ... ....... ..... ... .. ..... ..... ...... ......... .... ..... ..... .... .... ..... 2 2.0 ENTRY CONDITIONS .. ..... ........ .. ...... ..... ..... ....... ... ......... ............. ....... ........ ................... 2
.3.0 OPERATOR ACTIONS ... .. ................... .... .......... ..... .. ... ... ..... ....... ........ ... .... ..... ... ...... ... .. 2
4.0 REFERENCES
....... ... ... .. ... ........ ... .... .. ... .... ................. ..... .. .. ............ .... ..... .... ........ .... ... . 3 J;:\ADM_SRVS\TECH_PU B\REVISION\5\05-S-01-EP-2.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE Title : RPV Control No. : 05-S-01-EP-2 Revision : 044 Page: 2 1.0 PURPOSE 1.1 Maintain adequate core cooling 1.2 Shut down the reactor 1.3 Cool down the RPV to cold shutdown conditions (RPV water temperature $ 200°F).
2.0 ENTRY CONDITIONS 2.1 Entry conditions are any of the following:
2.1.1 RPV level below 11.4 in.
2.1.2 RPV pressure above 1064. 7 psig 2.1.3 DW pressure above 1.23 psig 2.1.4 A condition which requires a reactor scram AND any control rod is NOT inserted to OR beyond position 02 2.2 Enter this procedure WHEN any entry condition occurs OR an explicit direction to do so is encountered in another procedure, even IF it has already been entered, unless the SAPs are in use.
2.3 This procedure May be exited WHEN it has been determined that an emergency no longer exists.
2.4 The entry conditions for this procedure are symptomatic of Both emergencies AND events which May degrade into emergencies. The existence of an entry condition is therefore NOT necessarily indicative of an emergency. '
2.5 This procedure specifies symptom-based response strategies to maintain the plant in a safe condition without requiring diagnosis of the initiating event. Other procedures intended for use with this procedure Must NOT contradict OR subvert the steps specified in the GGNS Emergency Procedures OR degrade the operability of equipment required by the GGNS Emergency Procedures.
3.0 OPERATOR ACTIONS 3.1 REFER to:
J; :\ADM_SRVS\TECH_PU B\REVISION\5\05-S-01-EP-2. DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
RPV Control No.: 05-S-01-EP-2 Revision: 044 Page: 3
4.0 REFERENCES
4.1 BWR Owners' Group Emergency Procedure and Severe Accident Guidelines, Revision 2 4.2 Procedure 05-S-01-PSTG, Grand Gulf Nuclear Station Plant Specific Technical Guidelines 4.3 Administrative Procedure 01-S-06-37, Revision and Control of Emergency Procedures and Severe Accident Procedures 4.4 Administrative Procedure 01-S-06-39, Control and Use of Plant Specific Technical Guidelines 4.5 Administrative Procedure 01-S-06-41, Verification and Validation of Emergency Procedures and Severe Accident Procedures 4.6 EC 30912, Calculation XC-01111-99001 Revision 9, EP/SAP Calculations 4.7 Procedure 05-S-01-EP-1, Grand Gulf Nuclear Station Emergency/Severe Accident Procedure Support Documents 4.8 EC 20720, Calculation MC-Q1C41-10002 Revision O, Mass of Natural Sodium Pentaborate Decahydrate for Condensate Storage Tank J;:\ADM_SRVS\TECH_PUB\REVISION\5\05-S-01-EP-2.DOC
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PLANT OPERATIONS MANUAL Volume 05 05-S-01-EP-3 Section 01 Revision: 028 Date:5//s-j/L CONTINUOUS USE EMERGENCY PROCEDURE CONTAINMENT CONTROL SAFETY RELATED Prepared:
Reviewed :
3o2-73 Resp sib anager n Concurred: --"""==~1&.-+~--=>!0....-------------------
OSRC : D Pw~ :; 3 ~,'-f Approved :
List of Effective Pages:
Pages 1-3 EP-3 Flowchart dated 5/15/12 CONTROLLED COPY # ----
List of TCNs Incorporated:
Revision TCN Revision TCN 0 None 24 4 10-12 None 25 5 13 1 26-028 None 14 None 15 2 16 None 17 3 18-23 None J:\ADM_SRVS\TECH_PUB\REVISION\O\ONEP3.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
Containment Control No.: 05-S-01-EP-3 Revision : 028 Page:
RPTS FORM REQUIRED REVIEW PERFORMED D PAD D 50 .59 Screen/Eva!.
Check all that a I EN-Ll-100 EN-Ll-101 D 72.48 Screen/Eva!. D 50 .54 Eval.
Transmit applicable Review Form as a EN-Ll-112 EN-NS-210 separate record along with procedure to D PAD Not Required(EN-Ll-100 or 01-S-02-3)
Document Control. D Process Applicability Excluded D Editorial Change D ISl/IST Implementation 8' TCN Incorporation or Auto Rev .
.)&Other Process-Number: EC 30912
~. ~- / 3--7z .. 12 Cross-Disci line review re uired? (Note affected Departments Below)
Pre arer Initials>>>
Department Cross-Discipline Reviews Needed Sign off (siQned, electronic, telconl Nuclear Safety Analysis Jl"':'::Jl (} 4.llt. ~ f/<.,,.,.., LJJ,._ ..,I t-/-/l-11..
I Does this directive contain Tech Spec Triggers? ( ) YES (X) NO J:\ADM_SRVS\TECH_PUB\REVISION\O\ONEP3.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
Containment Control No.: 05-S-01-EP-3 Revision : 028 Page: ii REQUIREMENTS CROSS-REFERENCE LIST Re uirement Im lemented b Directive Name Para ra h Number P24130 AECM 86/0175 AT.5, Pg. 1, Para 4.S2 P24132 AECM 86/0175 AT.5, Pg. 2, Para 1.S3
- P31130 Tech Spec 5.4.1.b
- P32154 GNR0-95/00043 ALL
- P35629 FSAR 7.3.2.5.2.H *
- Covered by directive as a whole or by various paragraphs of the directive.
The Equipment Database (EDB) Request statement is applicable only to Volume 06 and 07 maintenance directives.
EDB Change Request generated and the backup documentation available for setpoint and/or calibration data only D Yes !El N/A EDBCR # _ _ __
Current Revision Statement Revision 028 implemented changes:
- Minor editorial changes to clarify EP steps and update references.
J:\ADM_SRVS\TECH_PUB\REVISION\O\ONEP3.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
Containment Control No.: 05-S-01-EP-3 Revision : 028 Page: 1 TABLE OF CONTENTS Page 1.0 PURPOSE ................................................................................................. ......... ........... 2 2.0 ENTRY CONDITIONS ...................... .... .................................................. ....................... 2 3.0 OPERATOR ACTIONS ...................................................................... ........................... 2
4.0 REFERENCES
............................................ ............................................. ........... ..... ..... 3 J:\ADM_SRVS\TECH_PUB\REVISION\O\ONEP3.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
Containment Control No.: 05-S-01-EP-3 Revision : 028 Page: 2 1.0 PURPOSE 1.1 Maintain containment integrity, and 1.2 Protect equipment in the containment.
2.0 ENTRY CONDITIONS 2.1 Entry conditions are any of the following :
2.1.1 SP temperature above 95°F 2.1.2 DW temperature above 135°F 2.1.3 CTMT temperature above 95°F 2.1.4 OW pressure above 1.23 psig 2.1.5 SP level below 18.34 ft 2.1.6 SP level above 18.81 ft 2.2 Enter this procedure when any entry condition occurs or an explicit direction to do so is encountered in another procedure , even if it has already been entered , unless the SAPs are in use.
2.3 This procedure may be exited when it has been determined that an emergency no longer exists.
2.4 The entry conditions for this procedure are symptomatic of both emergencies and events which may degrade into emergencies. The existence of an entry condition is therefore not necessarily indicative of an emergency.
2.5 This procedure specifies symptom-based response strategies to maintain the plant in a safe condition without requiring diagnosis of the initiating event. Other procedures intended for use with this procedure must not contradict or subvert the steps specified in the GGNS Emergency Procedures or degrade the operability of equipment required by the GGNS Emergency Procedures.
3.0 OPERATOR ACTIONS 3.1 REFER to EP-3, Containment Control Flowchart, dated 5/15/12.
J:\ADM_SRVS\TECH_PUB\REVISION\O\ONEP3.DOC
GRAND GULF NUCLEAR STATION EMERGENCY PROCEDURE
Title:
Containment Control No. : 05-S-01-EP-3 Revision : 028 Page: 3
4.0 REFERENCES
4.1 BWR Owners' Group Emergency Procedure and Severe Accident Guidelines, Revision 2 4.2 Procedure 05-S-01-PSTG, Grand Gulf Nuclear Station Plant Specific Technical Guidelines 4.3 Administrative Procedure 01-S-06-37, Revision and Control of Emergency Procedures and Severe Accident Procedures 4.4 Administrative Procedure 01-S-06-39, Control and Use of Plant Specific Technical Guidelines 4.5 Administrative Procedure 01-S-06-41, Verification and Validation of Emergency Procedures and Severe Accident Procedures 4.6 EC30912, Calculation XC-Q-1111-99001 Revision 9, EP/SAP Calculations 4.7 Cl 08-S-04-957, Post-Accident Gaseous In-line Chemistry Analysis and Grab Sampling 4.8 Procedure 05-S-01-EP-1, Grand Gulf Nuclear Station Emergency/Severe Accident Procedure Support Documents 4.9 Procedure 05-S-01-EP-2, RPV Control 4.10 EC 20720, Calculation MC-Q1C41-10002 Revision 0, Mass of Natural Sodium Pentaborate Decahydrate for Condensate Storage Tank J:\ADM_SRVS\TECH_PUB\REVISION\O\ONEP3.DOC
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The NRG staff's Audit Report is provided as Enclosure 1 with Appendices B and C as Enclosures 2 and 3, respectively. If you have any questions regarding the Audit Report, please contact me at (301) 415-1445 or by e-mail at Alan.Wang@nrc.gov.
Sincerely, IRA/
Alan B. Wang, Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-416
Enclosures:
- 1. Audit Report
- 2. Appendix B
- 3. Appendix C cc w/encls: Distribution via Listserv DISTRIBUTION :
PUBLIC RidsNrrDssSrxb Resource RidsNrrPMGrandGulf Resource LPLIV r/f RidsNrrDor1Lpl4-2 Resource RidsRgn4MailCenter Resource RidsAcrsAcnw_MailCTR Resource RidsNrrDraApla Resource AGuzzetta, NRA RidsNrrDorlDpr Resource RidsNrrLAPBlechman Resource GThomas, NRA BGreen , NRA KSturzebecher, NRA RidsNrrDssSrxb Resource ADAMS Access1on No. ML15085A227 *b1ymemo d ate d OFFICE NRR/DORULPL4/PM NRR/DORULPL4/LA NRR/DSS/SXRB/BC* NRR/DORULPL4-2/BC NRR/DORULPL4/PM NAME ABWang PBlechman CJackson MKhanna ABWang DATE 4/10/15 4/10/ 15 12/8/ 14 4/ 13/ 15 4/ 14/15 OFFICIAL AGENCY RECORD