GNRO-2011/00077, Report of 10CFR50.59 Evaluations and Commitment Changes July 1, 2010 Through June 30, 2011

Report of 10CFR50.59 Evaluations and Commitment Changes July 1, 2010 Through June 30, 2011

ML112640307
Person / Time
Site:	Grand Gulf
Issue date:	09/20/2011
From:	Perino C Entergy Operations
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
GNRO-2011/00077
Download: ML112640307 (40)

Text

Entergy Christina L.Perino GNRO-2011/00077 September 20, 2011 U.S.Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555

SUBJECT:

Report of 10CFR50.59 Evaluations and Commitment ChangesJuly 1, 2010 through June 30, 2011 Grand Gulf Nuclear Station, Unit NO.1 Docket No.50-416 License No.NPF-29

Dear Sir or Madam:

Pursuant to 10CFR50.59(d)(2)

Entergy Operations, Inc.hereby submits a description of 50.59 and commitment change evaluations for the period of July 1, 2010 through June 30, 2011 in Attachment 1.Attachment 2 contains copies of the full evaluations.

If you have any questions or require additional information, please contact Dennis Coulter at 601-437-6595.

This letter does not contain any commitments.

Sincerely, CLP/DMC Attachments:

1.Table of Contents 2.10CFR50.59 Evaluations and Commitment Change Evaluations cc: (See Next Page) cc: U.S.Nuclear Regulatory Commission A TIN: Mr.Elmo Collins l Jr.(w/2)Administrator l Region IV Blvd l 400 arlitl'\l'Itt'u'I TX 76011-41 U.Nuclear Regulatory Commission ATIN: Mr.Alan Wang l NRR/DORL (w/2)Mail StopOWFN8 B1 Washington l DC ,"V,JV,*,'-V'.IV Attachment 1 to GNRO 2011-00077 Table of Contents Grand Gulf Nuclear Station 10CFR50.59 Evaluation and Commitment Change Evaluation Report for the Period July 1, 2010 through June 30, 2011 10CFR50.59 Evaluations Evaluation Number Initiating Document Description SE 2011-0001-ROO Licensing Basis Technical Specification Bases change to drywell Document Change bypass leakage test start pressure from>3 psid to Request (LBDCR)2011 3+/-0.05 psid.031 SE 2011-0002-ROO Engineering Change Change the safety classification of the Dryer and (EC)23898 Separator strong back from class 3 to"other" to allow use of a replacement strong back.SE 2011-0003-ROO EC 23790 and Modifications to the fuel pool cooling and cleanup EC 23791 system following the station extended power uprate.Commitment Change Evaluations Commitment Source Document Description Number CCE 2010-0009 AECM 84/0508 Procedures provide a method for cross referencing technical manuals.This commitment has been tracked more than two years and is well established in site processes.

Tracking is no longer required.CCE 2011-0001 CNRO-97/00004

-Revises commitment to make a one-cycle one-time Entergy 180 Day extension to the Static Test Frequency interval for Response to Generic the RCIC Minimum Flow to Suppression Pool Letter 96-05 Isolation Valve that will also correspond to a one-time 6 month extension to the maximum interval (10 years)between static tests.CCE 2011-0002 CNRO-97/00004

-Revises commitment to make a one-cycle one-time Entergy 180 Day extension to the Static Test Frequency interval for Response to Generic the RCIC Turbine Exhaust Inboard Vacuum Letter 96-05 Breaker Valve that will also correspond to a one-time 4 month extension to the maximum interval (10 years)between static tests.

Attachment 2 to GNRO 2011-00077 10CFR50.59 Evaluations and Commitment Change Evaluations GGNS 50.59 Evaluation Number SE 2011-0001-ROO I.OVERVIEW I SIGNATURES 1 Facility: Grand Gulf Nuclear Station E It>/1-"00 J-ROt>Evaluation

1. I Rev.#: Proposed Change I Document: LDC 2010-031 for Technical Specification Bases 3.6.5.1.1 Description of Change: Technical Specification Bases 3.6.5.1.1 describes the drywell bypass leakage test.Procedure 06-ME-1M10-0-0003 was changed based on calculation MC-Q1M24-08008 with EC 8900.The method of evaluation changed from a constant pressure makeup test to a pressure decay test.The Technical Specification Bases were not changed at that time.This LDC changes the Technical Specification Bases to allow a pressure decay test and allow nominal start pressure of 3:t 0.05 psid per procedure 06-ME-1 M10003.Is the validity of this Evaluation dependent on any other change?DYes 0 No If"Yes," list the required changes/submittals.

The changes covered by this 50.59 Evaluation cannot be Implemented without approval of the other identified changes (e.g., license amendment request).Establish an appropriate notification mechanism to ensure this action is completed.

Based on the results of this 50.59 Evaluation, does the proposed change require prior NRC approval?DYes 0 No Preparer: Reviewer: OSRC: Robert W.Fuller//EOI/DE-Mech-Civil

//-2/-II Name (print)/Signature/Company/Department

/Date AI Evans/:M2Z.V---..//EOI/DE-Mech-Civil

/I*Z(.I (Name (print)/SignatureCompany/Department

/Date OSRC Meeting#())..-2{)t l 1 Signatures may be obtained via electronic processes (e.g., peRS, ER processes), manual methods (e.g., ink signature), e-mail, or telecommunication.

If using an e-mail or telecommunication, attach it to this form.EN-L1-101-ATT-9.1, Rev.6 II.50.59 EVALUATION Does the proposed Change being evaluated represent a change to a method of evaluation ONLY?If"Yes," Questions 1-7 are not applicable; answer only Question 8.If"No," answer 0 Yes all questions below.[8J No Doe8 the proposed Change: 1.Result in more than a minimal increase in the frequency of occurrence of an accident 0 Yes previously evaluated in the UFSAR?[8J No BASIS: The drywell leakage test is not an accident initiator so there is no minimal increase in the frequency of occurrence of an accident 2.Result in more than a minimal increase in the likelihood of occurrence of a malfunction of a 0 Yes structure, system, or component important to safety previously evaluated in the UFSAR?[8J No BASIS: The measurement of drywellieak tightness is not a contributor to the likelihood of occurrence of a malfunction of the drywell.3.Result in more than a minimal increase in the consequences of an accident preViously 0 Yes evaluated in the UFSAR?No BASIS: The consequences of an accident in the drywell are evaluated in UFSAR Chapter 15.The accident assumes a 3000 cfm flow rate for drywell to containment leakage flow.This flow rate is based.A 0 L.2.A ft'..A.on a testing.Jk=O.9 n.The deSign.Jk=0.9 w.The pressure assocIated WIth the.Jk IS 3 psid.This is the pressure to expose the vents.In the past GGNS has performed a constant pressure makeup test.Under these conditions, the drywell is maintained at approximately 3 psid and air is added to the drywell to maintain the pressure differential.

The amount of air added to the drywell to maintain the pressure differential is directly measured to determine the leakage rate.This is compared to the acceptable leakage rate.The proposed test is a pressure decay test.This initializes the drywell at a pressure differential between containment not to exceed the pressure that could cause the vents to be exposed.Changing from a constant pressure makeup test to a pressure decay test does not affect the overall system performance in a manner that could lead to an accident, the proposed change to the Technical Specification basis would not increase the overall consequences of an accident preViously evaluated in the UFSAR.Changing the test to start at less than 3 psid will not increase the consequences of an accident.The current margins for radiation dose wm be maintained and will not affect the consequences of an accident preViously evaluated in the FSAR.The basis for the change is the pressure decay curve provided by MC-Q1 M24-08008.

The pressure decay curve demonstrates acceptability of the drywell bypass leakage test.The acceptance criteria is the drywell pressure decay is above the curve provided by the calculation.

A The method still ensures that fk limits are met.EN-L1-101-ATI-9.1, Rev.6 4.Result in more than a minimal increase in the consequences of a malfunction of a structure, Yes or component important to safety previously evaluated in the UFSAR?No BASIS: The consequences of an accident in the drywell are evaluated in UFSAR Chapter 15.The accident assumes a 3000 cfm flow rate for drywell to containment flow.This flow rate is based on MELCOR analysis that was explicitly reviewed and approved by NRC.The thermal hydraulic A analysis assumes a design bypass leakage limit of.The analysis for the pressure drop.A test assumes a testing=0.09 tr.A The pressure associated with the is 3 psid.This is the pressure to expose the vents.This pressure differential is not being changed for accident scenarios and consequences.

The pressure being tested at will be changed to allow margin between the current Technical Specification allowable of 3 psid and the pressure to expose the vents at 3.02 psid.Currently OS-ME-1 M1 0-0-0003 allows the pressure to vary as much as 2.95 psid.This pressure will be adequate to initiate the pressure decay test.The capability of the drywell to containment pressure boundary is not affected.There will be no increase in the consequences to the structure of the drywell by changing the test methodology from a constant pressure test to a pressure decay test Changing the starting pressure to a pressure less than the pressure to expose the drywelVcontainment vents does not affect the consequences of the accident.The basis for the change is the pressure decay curve provided by MC-Q1 M24-08008.

The pressure decay curve demonstrates acceptability of the drywell bypass leakage test.The acceptance criteria is the drywell pressure decay is above the curve prOVided by the calculation.

Ifis met then the drywelVcontainment is within design basis.5.Create a possibility for an accident of a different type than any previously evaluated in the UFSAR?DYes[8]No BASIS: This evaluation does not involve an initiator or failure not considered in the FSAR.The change proposes to change the drywell bypass leakage test from a constant pressure test to a pressure decay test.With this change in test, the starting pressure of the test will be allowed to go below 3 psid.The 3 psid is based on the drywell to containment pressure that will expose the vents.Preoperational testing determined that 3.02 psid between containment and drywell will cause air to pass through the vents.This design feature of the drywell to containment is not being changed.Changing the type of test does not create the possibility for an accident of a different type than any previously evaluated in the FSAR.EN-L1-101-A TT-9.1 , Rev.S 6.a possibility for a malfunction of a structure, system, or component important to safety 0 Yes with a different result than any previously evaluated in the UFSAR?r8]No BASIS: This evaluation does not lead to a fanure mode with a different result previously evaluated in the FSAR.The change proposes to change the drywell leakage test from a constant pressure test to a pressure decay test.With this change in test, the starting pressure of the test will be allowed to go below 3 psid.The 3 psid is based on the drywell to containment pressure that will expose the vents.Preoperational testing determined that 3.02 psid between containment and drywell will cause air to pass through the vents.This design feature of the drywell to containment is not being changed.Changingthe type of test does not create the possibility for an accident of a different type than any A previously evaluated in the FSAR.Since is preserved, there is no different malfunction postulated.

7.Result in a design basis limit for a fission product barrier as described in the UFSAR being exceeded or altered?DYes r8]No BASIS: A.is not changed.The proposed measurement method preserves the limit.No design basis limit or fission barrier is being compromised as a result of a change in the type of test from a constant pressure test to a pressure decay test.8.Result in a departure from a method of evaluation described in the UFSAR used in establishing 0 Yes the design bases or in the safety analyses?r8]No BASIS: Changing from a measured leakage test to a drywell pressure drop test is essentially the same because calculation MC-Q1 M24-08008 demonstrates that assuming the designdrywellbypass leakage limit that the drywell would depressurize in 32.6 minutes.The results from the 2008 calculation is valid for all pressures between 0 psid and 3 psid drywell to containment pressure differential.

The drywell bypass leakage assumed in the calculation is 3 psid for 3456 scfm.This leakage bounds the leak rates received in previous drywell bypass leakage tests.The pressure decay curve from RF16 was acceptable to the pressure decay curve in calculation MC-Q1 M24-08008.

The results of the RF16 pressure decay curve were above the calculations curve which is acceptable.

If any of the above questions is checked"Yes," obtain NRC approval prior to implementing the change by initiating a change to the Operating License in accordance with NMM Procedure EN-LI-103.

EN-1I-101-ATT-9.1, Rev.6 GGNS 50.59 Evaluation Number SE 2011-0002-ROO I.OVERVIEW I SIGNATURES 1 5£2..011-000;2 1<.00 Facility: Grand Gulf Nuclear Station Proposed Change I Document: Table 3.2-1 and 9.1-3 Evaluation

1. I Rev.#: 2011-002 Rev.#0 Description of Change: Change the Safety Classification of the Dryer and Separator Strong back from Class 3 to"other" for replacement Steam Dryer and Separator Strong-back.

This change will allow the replacement of the current Steam Dryer and Separator strongback (special lifting device)with the replacement Steam Dryer and Separator strong back (special lifting device)that issafety related.Is the validity of this Evaluation dependent on any other change?DYes r2:J No If"Yes," list the required changes/submittals.

The changes covered by this 50.59 Evaluation cannot be implemented without approval of the other identified changes (e.g., license amendment request).Establish an appropriate notification mechanism to ensure this action is completed.

N/A Based on the results of this 50.59 Evaluation, does the proposed change require prior NRC approval?DYes r2:J No Preparer: Vikram D.Patell SEE lAS 1 SHAW GROUPI Design Engineering (Civil>>103-07-2011 Name (print)1 Signature 1 Company 1 Department 1 Date Reviewer: Michael Withrowl SEE lAS 1 Entergy Corporation 1 Eng Mgmt 103/10/2011 Name (pr't)1 1 Company 1 Department 1 Date OSRC: AtQi ,3 fJ I Ch rna's arne (rint)1 Signature 1 Date OSRC Meeting#JO,I-oNe 1 Signatures may be obtained via electronic processes (e.g., peAS, EA processes), manual methods (e.g., ink signature), e-mail, or telecommunication.

If using an e-mail or telecommunication, attach it to this form.EN-L1-101-ATT-9.1, Rev.7 II.60.59 eVALUATION Does the proposed Change being evaluated represent a change to a method of evaluation ONLY?If"Yes'" Questions 1-7 are not applicable; answer only Question 8.If"No;'answer Yes all questions below.No Does the proposed Change: 1 Result in more than a minimal increase in the frequency of occurrence of an accident..,v..,.u""v evaluated in the UFSAR?DYes C8:J No'tIf'f'ui.,.,nt evaluated in the UFSAR that could be impacted by the classification and separator strongback is the design basis fuel handling accident described in The dryer is not considered in this analysis since it cannot be used to tiowe'ver in accordance with UFSAR Section 9.1.4.2.5.6, the dryer strongback is a special to transport the steam dryer and the shroud head with the moisture steam separators betwefm the reactor vessel and the pools.As such, the strongback is used to lift heavy loads loads in excess of 1,140 Ibs.defined in the Technical Requirements Manual as the light load limit for postuUlte<J fuel handling accidents) as described in UFSAR section 9.1.4.2.2.5.

The load handling reCIUU'elTlents of UFSAR and 9.are not dependent on the safety classification of str<)flgDaC:K as as the strongback still meets the requirements specified in UFSAR section failure proof structural safety factor margins, proof testing, and post-test weld In addition to meeting the single failure criteria, the new strongback:

is constructed to the requirements of ANSI N 14.6-1978 which ensures compliance with all other requirements of UFSAR section 9.1.4.2.5.6, including stress design margins, load testing, and inspections.

Thefailurefrequency of the new strongback is thus not increased.

Therefore, downgrading the safety classification of the dryer and separator strongback will not result in an increase in the frequency of occurrence of an accident previously evaluated in the UFSAR.2.Result in more than a minimal increase in the likelihood of occurrence of a malfunction of a 0 Yes structure, system, or component important to safety previously evaluated in the UFSAR?C8:J No BASIS: UFSAR Section 9.1.4.2.2.1 summarizes the analyses involving the dropping of the steam dryer assembly from its highest lift point into the open reactor vessel and the dropping of the shroud head/steam separator assembly from its highest lift point into the open reactor vessel.While the replacement steam dryer is heavier than the existing steam dryer, the weight of the new dryer is still less than that of the steam separator head which is the bounding weight considered in the design of the strongback and postulated load drop.UFSAR Section 9.1.4.2.2.5 documents compliance with NUREG 0612, Control of Heavy Loads at Nuclear Power Plants.UFSAR Appendix 9D states that NUREG-0612 provides a defense in depth approach for controlling the handling of heavy loads so that load handling events have a very low probability of occurrence.

In addition, Section 5.1.1 of NUREG-0612 requires that special lifting devices satisfy the guidel ines of ANSI N 14.6-1978.

This standard specifies design, fabrication, acceptance testing, maintenance, and continuing compliance requirements for special lifting devices used to move heavy loads.Neither NUREG 0612 nor ANSI N14.6 1978 requires a safety classification for special lifting devices.Since the new strongback continues to meet single failure requirements and complies with NUREG-0612 and ANSI NI4.6-1978, the likelihood of a component failure during load handling is not increased.

Thus, downgrading the safety classification of the dryer and separator strongback wi II not result in an increase in the likelihood of occurrence of a malfunction of a structure, system, or component important to safety previously evaluated in the UFSAR.3.Result in more than a minimal increase in the consequences of an accident previously 0 Yes evaluated in the UFSAR?C8:J No EN-L1-101-ATT-9.1, Rev.7 BASIS: The dryer and separator strongback is a that does not have any defined function and performs no role in the consequences of an In addition, the requirements of UFSAR Appendix 9D and NUREG-0612 that defense in depth associated with heavy load lifts for the protection of safe shutdown and accident equipment are not affected by the replacement dryer strongback.

this will not result in an increase in the of an accident previously evaluated in the UFSAR.4.Result in more than a minimal increase in the consequences of a malfunction of a structure, 0 Yes system, or component important to safety previously evaluated in the UFSAR?l2J No BASIS: UFSAR Section 9.1.4.2.2.1 summarizes the analyses involving the dropping of the steam dryer assembly from its highest lift point into the open reactor vessel and the dropping of the shroud head/steam separator assembly from its highest lift point into the open reactor vessel.These analyses concluded that the postulated drop of either the dryer or the separator head would not affect the ability of the plant to remain in a safe shutdown condition or result in the release of significant amounts of radioactive materials.

Changing the classification of the dryer strongback does not impact any input or assumptions used in these analyses.The strongback also performs no accident mitigation function.Thus, this change will not result in an increase in the consequences of a malfunction of a structure, system, or component important to safety previously evaluated in the UFSAR.5.Create a possibility for an accident of a different type than any previously evaluated in the 0 Yes UFSAR?l2J No BASIS: In accordance with UFSAR Section 9.1.4.2.5.6, the dryer and separator head strongback is a special lifting device that performs no safety function.Changing the safety classification of this equipment will not change its function nor would it introduce any new accident precursor.

Therefore, this change does not create the possibility for an accident of a different type than any previously evaluated in the UFSAR.6.Create a possibility for a malfunction of a structure, system, or component important to safety 0 Yes with a different result than any previously evaluated in the UFSAR?l2J No BASIS: UFSAR Section 9.1.4.2.2.1 summarizes the analyses involving the dropping of heavy loads from their highest lift point into the open reactor vesseL This section summarizes the most serious consequence resulting from the accidental drop of a heavy load as a severe plastic deformation of the vessel top flange.The analysis also concludes that the drop will not produce any vessel leaks or result in the release of significant amounts of radioactive material.The new strongback still meets the single failure proof design requirements as well as all of the requirements for design safety margins, materials of construction, tests, and inspections as the original strongback.

The change in the safety classification does not change the form, fit, or function of the strongback.

Thus, this change will not create a possibility for a malfunction of a structure, system, or component important to safety with a different result than previously evaluated.

7.Result in a design basis limit for a fission product barrier as described in the UFSAR being exceeded or altered?DYes l2J No BASIS: The dryer and separator strongback is a passive lifting device that does not have any defined safety function and is not part of any fission product barrier nor does it affect the design basis limit for any fission product barrier.Therefore, changing the safety classification of the dryer and separator strongback does not result in a design basis limit for a fission product barrier as described in the UFSAR being exceeded or altered.EN-U-101-ATT-9.1, Rev.7 8.Result in a from a method of evaluation described in the UFSAR used in establishing 0 Yes the bases or in the r:8J No BASIS: The UFSAR classification of the dryer and separator stf<)OgoaC:K from Class to"other:'The of this special lifting device is not considered in any UFSAR or in any"U4'"," in the UFSAR.The codes and standards to which the new r-r\lrt"rlMu'r""rt are no different than those previously described in the UFSAR.this d"","",:u'1'11""" from a method of evaluation described in the If any of the above questions is checked"Yes," obtain NRC approval prior to implementing the change by Initiating a change to the Operating License In accordance with NMM Procedure EN-LI..103.EN-Ll-101-ATI-9.1, Rev.7 GGNS 50.59 Evaluation Number SE 2011-0003-ROO S£;2.011*"003 ROD Evaluation

1. I Rev.#: 2011:00031 Rey.00 10 CFR SO.59 EVALUATION FORM Sheet 1 of8 I.OVERVIew I SIGNATURES 1 Facility: Grand Gulf Nuclear Station Proposed Change I Document(s):

Description of Change: This change involves modifying the two redundant trains of the Fuel Pool Cooling and Cleanup (FPCCU)System and associated cooling water systems[Component Cooling Water (CCW)and Standby SeNice Water (SSW)]to increase the Spent Fuel Pool (SFP)decay heat removal capacity.The FPCCU system increased cooling capacity will be required following Extended Power Uprate (EPU)implementation in order to maintain SFP water temperatures below the temperature limits set by the SFP design criteria and licensing limits, for all limiting scenarios.

More specifically, the proposed change indudes the following:

• Replacement of the existing Shell&Tube heat exchangers in the FPCCU System with higher thermal capacity Affa Laval Plate&Frame heat exchangers (ASME Ill, Division 1, Class 3).*Modifying the supply and return piping to the FPCCU heat exchangers in FPCCU System to accommodate the new heat exchanger design and layout*Modifying the common supply and retum piping to the FPCCU heat exchangers in the CCW/SSW system(s)to accommodate the new heat exchanger design and layout*Installation of Simplex Strainers (ASME III, DiVision 1, Class 3)on the cooling water inlet side of the FPCCU heat eXchangers to protect the Plate&Frame FPCCU heat exchangers from iron oxide (rust)partides greater than p: 125 in.coming from the SSW system, which can block flow paths and degrade thermal performance.

This modification does not increase the system susceptibility to hydraUlic transients such as water hammer, startup transients, etc.therefore hydraulic transients are not the focus of this evaluation.

A Process Applicability Determination (PAD for EC#23790)was performed in regards to the proposed change that identified both a change to a Licensing Bases Documents (LBO), namely the UFSAR, as'Neff as a potential adverse effect which is negligible in the current FPCCU System design.The adverse effect introduced by the proposed change is an aggravated failure mode with regards to flow blockage inherent in the smaller flow passages of a Plate&Frame heat exchanger type design.If the heat exchanger flow rate is reduced from blockage the thermal hydraUlics of the system are adversely affected and the result is a reduction in the heat removal capability of the FPCCU System.The result is the potential of no longer being able to maintain the SFP water temperature within the required limits, either during normal operations or an accident.During normal operations, the cooling water is supplied from the Component Cooling Water (CCW)System, and during acddent conditions the cooling water is supplied from the Standby Service Water (SSW)System.The flow blockage of the Plate&Frame heat exchanger during normal operation, with CCW as the cooling fluid, is mitigated by eXisting water chemistry control.Periodic testing of the FPCC heat exchangers will be performed as part of the heat exchanger thermal performance monitoring program to comply with NRC Generic Letter 89-13.This testing will trend heat eXchanger performance and fouling levels to determine when cleaning is required.The FPCCU system water is normally circulated through a filter/demineralizer to maintain water purity and is demineralized.

The CCW is a dosed loop, cooling system that uses chemically controlled water with the capability for chemical additions and further control.The susceptibility to thermal degradation due to flow blockage of the nature described above is low for the FPCCU water in a forced circulation mode of operation given the above preventative actions.In the case of an alignment to the SSW system dUring accident conditions or SSW flow balancing activities, the increase in potential FPCCU heat exchanger cooling water flow blockage is mitigated by the high fluid turbulence caused by the corrugated and parallel heat exchanger plates, thus creating a greater resistance to flow blockage, as'Wetl as by the use of proposed strainers on the cooling water side.The SSW system is the open loop cooling water system which acts as the ultimate heat sink (UHS)for the plant in the case of a design basis accident.The SSW system provides cooling water to several safety related heat exchangers, including the FPCCU heat exchangers.

The SSW water is cooled by two cooling towers, and is then collected in two concrete basins below the towers.The SSW pumps take suction from their respective basin, and proVide flow back to the I Signatures may be obtained via electronic processes (e.g., PCRS.ER processes).

manual methods (e.g.*ink: signature), e-ITh.'lil.

or telecommunication.

If using an e-mail or telecommunication.

attach it to this form When using other manual methods.type/print Name, electronic method of signature.

Company, and Department (and Date.if desired).where applicable.

EN-Ll-101-ATT-9.1, Rev.7 I"h':"M"Iil"elllu treated to minimize material.In order protected by an debris in size (the minimum heat heat are for a maximum blockclge mode to the aforementioned can occur that can affect The corrosion in the SSW supply piping can be released to the heat installed to address the flow mode.The strainers installed are QA 1, Nuclear and Class 3 Simplex Strainers.

The flow blockclae rate of strainers is therefore the adverse effect requiring evaluation; however additional topics are evaluated herein for The of the Simplex Strainers assumes the maximum predicted particulate Ir\elrllrl,rt from the total of metal oxides in This liftoff is expected to accumulate in the strainers a of time after SSW This is not continuous but rather the result of a burst after forced is The maximum pressure dropfromthe blocKclge in the strainers is accounted for in the hydraulic evaluations and the results shown to meet the existing bases of the SSW The overall scope of this 50.59 evaluation is to demonstrate that the introduction of the new FPCCU Plate&Frame heat oVhCl,nrt,,,,ret and associated strainers do not result in an unresolved question since the new failure mode inherent in can be with a combination of existing water chemistry control, heat mCldifiica1tioriS to the common cooling water system supply by the addition of strainers.

The heat and are therefore shown to be adequate in meeting the IIrOM"lontet of both the bases and the EPU conditions.

The primary sources for demonstrating oU'__\,.j\.AO\.,y of the pro,pOf:;ed are the conformed specifications utilized in the construction and acquisition of the new Plate&Frame (SPEC-10-00021-G) and the cooling water supply Simplex strainers (SPEC-11-00017-G).

Several items related to the proposed change have already been evaluated in the PAD and did not warrant further 50.59 reviews, therefore they are not included in the scope of this document.The items screened out are listed herein for completeness:

• FPCCU Piping and CCW/SSW Piping Qualification and Associated Supports*Civil/Structural Qualification

• FPCCU Heat Exchanger Haul Path Evaluation

• Radiological Impact Review Individual evaluations for the aforementioned excluded topics can be found either in the PAD and/or with independent supplemental evaluations as a function of the pertinent discipline.

The following acronyms and component numbers are utilized throughout this evaluation:

Acronyms: FPCCU Fuel Pool Cooling&Cleanup Component Cooling Water SSW Standby Service Water EPU Extended Power Uprate lBD Licensing Bases Document DBD Design Bases Document EC Engineering Change PAD Process Applicability Determination HXs Heat Exchangers lOCA loss of Coolant Accident lOOP loss of Offsite Power UFSAR Updated Final Safety Analysis Report TS Technical Specifications OlM Operating License Manual TRM Technical Requirements Manual FHA Fire Hazards Analysis EN-L1-101-ATT-9.1

, Rev.7 10 CFR 50.59 EVALUATION FORM'/,,\rYlnn,nl:llnt Numbers: 1 G41 B001 AlB B005A1B D005A1B 1 P42-F028A1B An extensive review of GGNS operating, design, and licensing bases information was performed and compared to EPU conditions to support the proposed change.The review included the following:

• GGNS UFSAR Sections: 1: 1.2.1, 1.2.2.8.1, 1.2.2.8.2, 1.2.2.8.20, 3: 3.1 3.2.4.2.1, Table 3.2-1, 3.9.3.1.1.1 3.9.3.4.3, TableTableTable 7: 7.6.1.9, 7.6.1.10, 7.6.2.8, Table 7.6-10, Table 7.6-13 9: Table 9.1-12,9.1.3,9.2.1,9.2.2, Table 9.2-16, Table 9.2-17 14: 14.2.12.1.22, Chapter 15: 15A.6.2.3.14

• GGNS Technical Specifications and Basis: B 6.7.4, B6.7.4*GGNS Plant Operating Manual 05-1-02-V-1 R021 Off-Normal Event Procedure"Loss of Component Cooling Water" 05-1-02-V-11 R031 Off-Normal Event Procedure"Loss of Plant Service Water" 06-0P-1G41-Q-0001 Surveillance Procedure"FPCCU Pump and Valve Operability Test" Based on the review of thedocumentsabove the following licensing and design conditions exist with which to compare the impact of the proposed change:*From the plant Technical Specifications LCO 6.7.4 requires that the SFP water temperature be maintained less than or equal to 140°F whenever there is irradiated fuel in the SFP.The existing thermal and hydrauliccalculationsassociated with the FPCC heat exchangers were revised to reflect the new configurations.

The revisions demonstrate that with the installation of the new heat exchangers and the cooling water side strainers, the FPCCU System will be capable of:*Dissipating the peak EPU fuel pool heat load of 27.4 MBtu/hr while simultaneously maintaining the SFP temperature below 140°F with either SSW or CCW cooling water.*Maintaining the spent fuel pool temperature below 140°F with only one FPCCU train after approximately 70 days.*Maintaining the spent fuel pool temperature below 150°F during a Loss of Coolant Accident (LOCA)concurrent with a Loss of Offsite Power (LOOP)and the failure of a diesel generator (Note: this cannot be accomplished until just after 15 days after a normal shutdown).

Therefore, from a thermal/hydraulic perspective the new heat exchangers with the associated strainers have the ability to meet the design function of the FPCCU System as described in the UFSAR.The FPCCU System does not in itself mitigate the consequences of an accident as described in Chapter 15 of the UFSAR;however it is essential in maintaining the SFP water temperature within design and licensing limits even during a LOCA via the removal of decay heat from irradiated fuel stored in the spent fuel pool.The effects on several of the accidents discussed in Chapter 15 of the UFSAR were evaluated with respect the proposed change.There are no safety functions being added, altered, or deleted by the proposed change.Nor are there any seemingly positive aspects of the proposed change which under unusual circumstances adversely affect safety.EN-L1-101-ATT-9.1

, Rev.7 Is the validity of this Evaluation dependent on any other change?DYes No If"Yes,1t list the required changes/submittals.

The changes covered by this 50.59 Evaluation cannot be implemented without approval of the other identified changes (e.g., license amendment request).Establish an appropriate notification mechanism to ensure this a.ction is completed.

Note: Although the impetus for the proposed is to accommodate the increase in Spent Fuel Pool decay heat loads at Extended Power Uprate conditions, the license amendment approval for the EPU itself is not a prerequisite for implementation of the modification.

The capabilities of the change/modification exceed the existing system reqUirements and justify implementation if so NRC approval of the EPU license amendment request is not a for the proposed evaluated herein.Based on the results of this 50.59 Evaluation, does the proposed change require prior NRC approval?DYes No Preparer: Reviewer: G.E Broadbent!

See lAS/Entergy/EPU Engineering I 05-02-11 Name (print)I Signature I Company I Department I Date OSRC: EN-L1-101-ATI-9.1

, Rev.7 10 CFR 50.59 EVALUATION FORM II.50.59 EVALUATION

[10 CFR 50.59(c)(2)]

Does the proposed Change being evaluated represent a change to a method of evaluation Yes ONLY?If"Yes, Questions 1-7 are not applicable; answer only Question 8.If"No," answer No all questions below.Does the proposed Change: 1.Result in more than a minimal increase in the frequency of occurrence of an accident evaluated in the UFSAR?Yes No BASIS: A review of the UFSAR Chapter 15 was conducted to determine if the frequency of any UFSAR postulated accidents may be impacted by the modification of the FPCCU System and the addition of the associated cooling water (CCW/SSW)supply strainer.UFSAR Section 15.7.4 discusses a fuel bundle drop accident onto stored irradiated fueL Additionally, Section 15.7.5 discusses a Fuel Cask Drop Accident.Both accidents do not involve the FPCCU System.Accidents involving the FPCCU are discussed neither in this section nor in any other UFSAR Chapter 15 sections.UFSAR Section 15.6.5 discusses a LOCA and the resulting requirement of adequate decay heat removaL In this context, the SSW operability is essential in mitigating the consequences of a LOCA type accident via the removal of heat from the RHR system and from other emergency safeguard equipment.

UFSAR Section 9.1.3 states that SSW was analyzed for Spent fuel pool heat removal following a LOCA with LOOP to ensure heat removaL The addition of a strainer in the CCW ISSW systems to the common supply of the FPCCU HX does not increase the frequency of occurrence of a LOCA as currently established.

The overall performance and reliability of the SSW system during a LOCA is similarly not affected since the replacement FPCCU heat exchangers and the new strainer do not affect SSW system performance, which is flow balanced in advance to ensure adequate flow to other essential loads.The CCW system is not evaluated since it is considered out of service during an accident and is therefore not credited.Theproposedchanges add only passive components that do not affect the electrical loadings in either the FPCCU or SSW systems.The proposed changes do affect the structural loadings with regards to floor loadings, seismic responses, etc.but the effect has been determined to be acceptable, therefore no new failure modes in regards to causing an accident are introduced.

The replacement FPCCU heat exchangers and strainers are designed to remain intact and functional in the event of a safe shutdown earthquake.

While the majority of the work which will install the new heat exchangers, strainers, and piping will be performed while the plant is online, all work which requires dismantling an operating system or component, or breaches an existing system pressure boundary, will be performed while the plant is offline.Therefore, there is no increase in the frequency of occurrence of any accident discussed intheUFSAR.The proposed change is similar in complexity and human factor considerations as the existing system, as the passive components being added do not add any additional operator burdens or challenges during an accident and in this sense can be considered equivalent to the existing system.In summary, the FPCCU and associated cooling systems are credited for maintaining spent fuel pool temperatures during normal and postulated accidents; however, the FPCCU and associated cooling systems do not initiate any accidents evaluated in the UFSAR and accordingly do not change the frequency of any postulated accidents.

EN-L1-101-ATT-9.1, Rev.7 10 CFR 50.59 EVALUATION FORM 2.Result in more than a minimal increase in the Iikel\hood of occurrence of a malfunction of Yes structure, or component important to previously evaluated in the UFSAR?No BASIS: The FPCCU System is considered in the prevention and mitigation of an'=In':>nr7nrt crediting the removal of decay heat from irradiated fuel stored in the fuel The pro1po:sea f"t'H:::InrlOC!

including the addition of new FPCCU heat and the addition of strainers on the 1"'",............

have been evaluated from both a seismic and structural standpoint and have been found to be in their proposed design and construction.

No adjacent that are credited in UFSAR scenarios will be affected by the proposed change from this perspective.

The of the existing Shell&Tube FPCCU heat with new Plate&Frame FPCCU heat ovt"h!:llnnorC!

will not affect the separation criteria between of equipment and will retain the dual train configuration currently employed, including redundancy and cross-tie capabilities.

The required hydraulic performance of the FPCCU pumps and associated diesel loading requirements are unaffected by the proposed The proposed strainer design is sufficient in accommodating the effects of long term flow blockage that arise when the SSW system is in a stagnant configuration.

More specifically, the pressure drop that arises from the periodic use of the SSW across the strainer has been accounted for in the thermal hydraulic of the FPCCU System and shown to be adequate for the most limiting conditions, including during a LOCA concurrent with a LOOP.The strainers prevent the introduction of particles that would be large enough to block the cooling water paths in the FPCCU heat exchangers.

Additionally, the pressure drop from flow blockage does not result in Inf"ra!:IC!lrln the likelihood of occurrence of a malfunction of an SSC discussed in the UFSAR.During a LOCAILOOP scenario, the SSW system is assumed to no longer contribute additional sources of particulate fouling matter to the strainer beyond the initial burst This assumption is reasonable since the long term cooling scenario is still short in comparison to the rate of particulate formation in the SSW system.In summary, there is no increase in the likelihood of occurrence of a malfunction of the FPCC system and associated cooling systems due to the proposed modification.

The new filter has been sized to capture particles which could clog the replacement plate and frame FPCC heat exchanger and the SSW system has been evaluated for the maximum predicted filter loading.The existing train redundancy of the FPCCU System ensures adequate performance under all modes of operation, even assuming single failure criteria.This condition remains unaffected by the introduction of the proposed changes and can be considered equivalent to the existing design.3.Result in more than a minimal increase in the consequences of an accident previously evaluated in the UFSAR?DYes L81 No BASIS: As discussed in the response to Question 1 above, the FPCCU system and the cooling of FPCCU by the SSW is only discussed in the LOCA accident scenario.Accident mitigation via the SSW system as the primary heat sink for the RHR system and other emergency safeguard equipment is unaffected by either the replacement of the FPCCU HXs or the addition of the cooling water Simplex Strainers since the SSW system is flow balanced prior to operation.

The flow balancing ensures adequate cooling to all safety systems by the SSW system in the event of an accident even when the Simplex Strainers are at their maximum fouled condition.

In addition, as discussed in the response to Question 2 above, the FPCCU System and its SSW cooling water maintain SFP water temperature within design limits even during a LOCA;hence the SFP fuel cladding will remain unaffected.

The modification does not affect the containment boundary or any safety systems that circulates the primary fluid outside the containment following an accident.Since the accident mitigation is not affected, including any leakage paths outside the containment, there is no increase in the consequences of an accident previously evaluated in the UFSAR.EN-L1-101-ATT-9.1, Rev.7 10 CFR 50.59 EVALUATION FORM 4.Result in more than a minimal increase in the consequences of a malfunction of a structure, Yes or to previously evaluated in the UFSAR?No BASIS: As discussed in the response to Question 2 the malfunctions of both the FPCCU and SSW are considered and addressed via train redundancy in the existing licensing and design bases of plant.The of the proposed with to the heat exchanger upgrades does not change the OVIC!tll"1lt"l malfunctions and can be considered equivalent in nature to the existing system.With respect to the Simplex the for flow obstruction as a hypothetical malfunction in the SSW system does not increase the consequences of a malfunction since the is flow balanced and will be designed to account for the differential pressure across the strainer due to the maximum predicted particle loading.5.Create a possibility for an accident of a different type than any previously evaluated in the 0 Yes UFSAR?I2$]No BASIS: Both the FPCCU and SSW remain unchanged in their underlying design function.The systems will not cause any new accidents than those already evaluated in the UFSAR.These systems will continue to perform their functions after this modification.

6.Create a for a malfunction of a or component important to safety 0 Yes with a different result than any previously evaluated in the UFSAR?I2$]No BASIS: As discussed in the response to Question 2 above, the malfunctions postulated for FPCCU result in the loss of one of two redundant trains.The proposed change does not adversely affect any SSC that is important to safety.The most limiting malfunction involving both the FPCCU and SSW system has been shown via evaluation to remain unaffected.

The FPCCU System will continue to meet its design bases (maintaining SFP temperature below limits)during a LOCA.The SSW system is flow balanced to ensure adequate flow is delivered to all essential loads even with the postUlated loading on the strainers; therefore the system will provide the heat sink capability assumed in the various scenarios as a boundary condition (Le.design input), thereby ensuring an adequate plant response predicted for all scenarios at both pre-and post-EPU conditions.

The response to all scenarios at EPU is not a function of the proposed changes discussed herein and approval of said responses by the appropriate licensing amendment is independent of this evaluation.

EN-L1-101-ATT-9.1, Rev.7 7.Result in a design basis limit for a fission product barrier as described in the UFSAR being exceeded or altered?Yes No BASIS: Fission product barriers include fuel rod cladding, the reactor coolant system, and the primary/secondary containment buildings.

Design basis limits would be those limits such as temperature, pressure, enthalpy, and strain.Modification of the FPCCU and CCW/SSW systems does not affect any design basis limits for any of the fission product barriers.The FPCCU System is responsible for maintaining SFP water temperature within limits of the SFP liner, racks, and associated criticality analyses.Calculations have demonstrated that the FPCCU System is capable of maintaining the SFP temperature below design limits for all operating conditions, including during a LOCA.The result is that the local fuel cladding of spent nuclear fuel is unaffected by the proposed change since the ambient cooling medium will remain within the limits required.The SSW system operability for all required modes of operation is unaffected by the proposed change since the system is flow balanced to ensure essential loads receive adequate cooling water and can continue to support the removal of decay heat and the operation of the emergency safeguard equipment dUring an accident.Since the LOCA and other accident analyses are unaffected, the proposed changes to both the FPCCU HXs and the CCW/SSW strainers will not result in a design basis limit for a fission product barrier as described in the UFSAR being exceeded or altered.8.Result in a departure from a method of evaluation described in the UFSAR used in establishing Yes the designbasesor in the safety analyses?No BASIS: A review of the UFSAR sections listed previously was performed to determine whether this change departs from a method of evaluation described in the UFSAR used in establishing the design bases or in the safety analyses.Although an industry-standard computer code is required for determining the heat rejection capability of the new plate-and frame heat exchangers, this method of evaluation is not described in the UFSAR 9.1.3 other than merely reporting the performance of the existing components.

Likewise, the piping design methods are also unaffected.

Therefore, this change does not constitute a change to any calculation or methodical framework used in the safety analyses as described in the UFSAR.If any of the above questions is checked"Yes," obtain NRC approval prior to implementing the change by initiating a change to the Operating License in accordance with NMM Procedure EN-Ll-103.

EN-Ll-101-ATT-9.1, Rev.7 GGNS Commitment Change Evaluation Number CCE 2010-0009 LRS/CMS I.D.P-24008 COMMITMENT CHANGE EVALUATION FORM Site Licensing Tracking Number: CCE2010-0009 Document I Date: AECM84/0508 Commitment:

Closure/DeletionHistoric/HistiRetired/NEI o Revision o Superseded Has the original commitment been implemented?YES o NO, notify site Licensing Original Commitment

==

Description:==

Procedure provides a method for cross-ref.

Tech Manuals with the applicable plant procedure (s).Revised Commitment

==

Description:==

I Summary of Justification for Change (attach additional sheets if necessary):

1't.r-EN-\.."C-" 0':.As a result of changes in circumstances a commitment may be rendered irrelevant or no longer useful.This may include commitments that have been tracked for more than two years and are well established in work processes or otherwise embedded in site processes.

In these situations, commitment may be removed from continued tracking (see Step 3.0[13]for status changes that may be used to indicate continuing tracking is no longer required).

Reference Procedures:

EN-DC-132, Control of Engineering Documents and EN-DC-148,.

Vendor Manuals and the Vendor Re-Contact Process.('1fk\dC7v" e..\u.,\v"...;u.\\C"""'1

....J.J).A.",;.\.-......:.c.S£rv i e.u)\.\'2.t.\'0 Prepared By:__

Management Approval: An ela S.Mosb Print Name/Forward completed form to site Licensing.

10/25/2010 Date: 10/25/2010 Site Licensing Management J4)LiJ(or designee)Concurrence:

UlrtJ-0\.

(, e Date: "'/2" j,o I I Print e 1 SIgnature.EN-L1-110-ATT-9.4, Rev.2 COMMITMENT CHANGE EVALUATION FORM PART I 1.1 Is the commitment located in the Updated Final Safety Analysis Report, Emergency Plan, Quality Assurance Program Manual, Fire Hazards Analysis, or Security Plan?o STOP.Use appropriate codified process (e.g., 10 CFR 50.71(e), 10 CFR 50.54,10 CFR 50.59,10 CFR 50.55)to evaluate commitment and then continue to Part", if appropriate.

IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.NO Go to Part".PART II 2.1 Could the change negatively impact the ability of a System, Structure, or Component (SSC)to perform its specified safety function or negatively impact the ability of plant personnel to ensure the sse is capable of performing its specified safety function?o YES Go to Question 2.2.t8J NO Continue with Part III.Briefly describe rationale:

2.2 Perform a safety evaluation using the following 10 CFR 50.92 criteria to determine if a significant hazards consideration exists:-Does the revised commitment involve a significant increase in the probability or consequences of an accident previously evaluated?

DYES o NO Describe basis below-Does the revised commitment create the possibility of a new or different kind of accident from any previously evaluated?

DYES o NO Describe basis below EN-Ll-110-ATT-9.4, Rev.2 COMMITMENT CHANGE EVALUATION FORM the revised commitment involve a significant reduction in a margin of safety?YES NO Describe basis below If any of the above questions are answered Yes, STOP.Do not proceed with the revision, OR discuss change with NRC and obtain necessary approvals.

IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.IF all three questions are answered NO, THEN go to Part III.(Attach additional sheets as necessary.)

PART III 3.1 Was the original commitment (e.g., response to NOV, etc.)to restore an obligation (e.g., rule, regUlation, order or license condition)?

YES Go to Question 3.2.L81 NO Continue with Part IV.3.2 Is the proposed revised commitment necessary and justified?

o YES Briefly describe rationale (attach additional sheets as necessary).

IF commitment not yet implemented, THEN notify NRC of revised commitment prior to the original date in which the commitment was to be completed/satisfied.

o NO STOP.Do not proceed with the revision OR apply for appropriate regulatory relief.IF NRC approval obtained, revise commitment; THEN no further evaluation is required and no further NRC notification is required.PART IV 4.1 Was the original commitment:

(1)explicitly credited as the basis for a safety decision in an NRC SER, (2)made in response to an NRC Bulletin or Generic Letter, or (3)made in response to a request for information under 10 CFR 50.54(f)or 10 CFR 2.204?t8J YES Go to Question 4.2.o NO Continue with Part V.EN-L1-110-ATI-9.4, Rev.2 COMMITMENT CHANGE EVALUATION FORM 4.2 Has the original commitment been implemented?

r81 YES Go to Question 4.3.NO STOP.Do not proceed with revision OR notify NRC of desired change.IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.4.3 Is the proposed revised commitment necessary and justified?

YES STOP.You have completed this evaluation.

Revise the commitment and notify NRC of revised commitment in report.o NO STOP.Do not proceed with revision OR notify NRC of desired change.IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.PART V 5.1 Was the original commitment made to minimize recurrence of a condition adverse to quality (e.g., a long-term corrective action stated in an LER)?o YES Go to Question 5.2.o NO STOP.Revise the commitment.

No NRC notification required.5.2 Is the revised commitment necessary to minimize recurrence of the condition adverse to quality?o YES Revise the commitment and notify NRC of revised commitment in next annuallRFO interval summary report.o NO Revise commitment.

No NRC notification is required.REFERENCES List below the documents (e.g., procedures, NRC submittals, etc.)affected by this change.Doc.Number 110 Description EN-L1-110-ATT-9.4, Rev.2 GGNS Commitment Change Evaluation Number CCE 2011-0001 LRS/CMS 1.0.P-32889 COMMITMENT CHANGE EVALUATION FORM Site Licensing Tracking Number: CCE 2011-0001 Source Document/Date: CNRO-97/00004, dated 3/1 is the Entergy 180 Day Response to NRC Generic Letter 96-05,"Periodic Verification of Design-Basis Capability of nnr...'.....r_.Int::lirl:lt'::ll"l Valves" Commitment:

o Cancellation o Historic/HistJRetired/NEI Revision Superseded the original commitment been implemented?

Original Commitment

==

Description:==

YES o NO, stop and notify site Licensing Commitment P-32889 is addressed in the original GL 96-05 response per CNRO-96/00016, dated 11/15/96, and restated verbatim in the 180-day response per CNRO-97/00004.

This commitment tracks the implementation of general program guidance and methodology at each EOI site in site specific programs.The 180-day response provides a summary of the"EOI Safety-Related Motor Operated Valve Periodic Verification Program" and includes the following: "The following matrix provides the results of the combined risk ranking and setup ratio used to determine a maximum bounding test frequency.

In addition, the maximum interval between static tests is not to exceed10 years.STATIC TEST FREQUENCY MATRIX Revise H (3)3 Cycles 3 Cycles 2 Cycles 2 Cycles M (2)6 Cycles 4 Cycles 4 Cycles 3 Cycles./'L (1)6 Cycles 6 Cycles 6 Cycles 4 Cycles v l RISK i 1 RATIOH-H (1)H (2)M (3)L (4)Oil"', 1-,..RECORD SlJ INITIAlS"tl!""HfR rJ PAGES.l.!l I DAn:!J-';/'-II Gt:lATECJ[$XUM*NT d Commitment

==

Description:==

I.uMt!f:11 Make a one-cycle one-time extension to the Static Test Frequency interval for 1E51F019 (RCIC Minimum Flow to Suppression Pool Isolation Valve), that will also correspond to a one-time 6 month extension to the maximum interval (10 years)between static tests.The valve was last tested on 6/13/2001 and to meet the commitment, the valve must be tested by 6/13/2011.

The valve will be tested during RF18 (Feb-April 2012)so GGNS is requesting a 11 month extension beyond the 10 year commitment.

Summary of Justification for Change (attach additional sheets if necessary):

1 E51 F019 was scheduled for static diagnostic testing during CYCLE 18 during the March 2011 RCIC system outage.The RCIC system outage was in the process of being moved to July of 2011 but because of the events to the nuclear plants in Japan in March of 2001, the GGNS management team decided to move all on-line RCIC work to refuel outage 18 to reduce any risk of having RCIC inoperable.

To statically test the 1 E51 F01 9 valve requires that the breaker for the valve be tagged in the OPEN position while the test eqUipment is being connected, thus making RCIC inoperable.

To reduce plant risk, the site (GGNS)is requesting a deferral of the late date for performing the diagnostic test on valve 1 E51 F019 until 5/13/2012 to accommodate diagnostic testing the valve in Refuel 18.To approve this deferral requires a one-time one-cycle test-interval-extension for this valve to be made.This is acceptable because this valve has a high safety margin (CLOSE: 24.4%, OPEN: 215.3%)and there have not been any failures or EN-L1-110 ATT 9.4 Rev.4 COMMITMENT CHANGE EVALUAnON FORM.,...2-4*" have noi been any faih stroke time anomalies noted in the past 10 years based on a review of the results of the quarterly stroke time test performed per 06-0P-1 E51-Q-0002.

The valve has a PM task that monitors the condition of the assembly every 36 months and no abnormalities have been identified.

Also no failures of this MOV has been observed over the past 10 years based on a search of peRS.Prepared By:

Lf,J/-/1 Management Approval:

Print Name I Signature Forward completed form to site Licensing.

Site Licensing Management (or designee)Concurrence:

_C_hr_is:.-t_in_a

.......P_e.:....r_in

.......Print Na*T"'ir"flu/" PART I Date:----'-./S--:..y....;...

...........

--Date: 'f-t'1....Ir 1.1 Is the existing commitment located in the Updated Final Safety Analysis Report, Emergency Plan, Quality Assurance Program Manual, Fire Hazards Analysis, or Security Plan?o YES STOP.Do not proceed with this evaluation.

Instead use appropriate codified process (e.g., 10 CFR 50.71 (e), 10 CFR 50.54,10 CFR 50.59,10 CFR 50.55)to evaluate commitmentNO Go to Part II.PART II 2.1 Could the change negatively impact the ability of a System, Structure, or Component (SSC)to perform its specified safety function or negatively impact the ability of plant personnel to ensure the SSC is capable of performing its specified safety function?YES Go to Question 2.2.o NO Continue with Part III.Briefly describe rationale:

EN-L1-110 ATT 9.4 Rev.4 COMMITMENT CHANGE EVALUATION FORM Page 3 of 5 2.2 Perform a safety evaluation using the following 10 CFR 50.92 criteria to determine if a significant hazards consideration exists: Does the revised commitment involve a significant increase in the probability or consequences of an accident previously evaluated?

DYESNO Describe basis below This commitment is to perform diagnostic testing on 1 E51 F019 to monitor the performance of the MOVon a frequency not to exceed 10 years.The 1 E51 F019 has a safety function to OPEN automatically to provide minimum flow pump protection and to CLOSE automatically when pump flow is greater than minimum flow to provide maximum flow to the reactor.The MOV also has a safety function to CLOSE automatically to provide containment isolation when not required to provide minimum flow protection.

The 1 E51 F019 is normally CLOSED during RCIC standby operation.

The 1 E51 F019 MOV has a PM task that monitors the condition of the assembly every 36 months and no abnormalities have been identified over the past 10 years.Based on a search of PCRS, no failures of this MOV has been observed over the past 10 years.Therehave also not been any failures or stroke time anomalies noted in the past 10 years based on a review of the results of thequarterlystroke time test performed per 06-0P-1 E51-Q-0002.

Therefore based on the discussion above, a one time extension of the committed testing frequency would not cause a significant increase in the probability or consequence of an accident previously evaluated.

-Does the revised commitment create the possibility of a new or different kind of accident from any previously evaluated?

DYESNO Describe basis below Allowing the 1 E51 F019 valve to be diagnostically tested at a one time frequency of 10 years and 11 months will not create the possibility of a new or different kind of accident from any previously evaluated since the diagnostic testing, performed now ona4 year frequency, primarily monitors for valve and actuator degradation and test the actuator capability to produce enough thrust to close the valve against design basis accident pressures.

Past testing has shown little to no changes in the output torque or thrust of thisMOV.Based on the previous static testing and quarterly stroke history, exceeding the 10 static test frequency should in no way jeopardize the functionality of this MOV.EN-Ll-110 ATT 9.4 Rev.4 COMMITMENT CHANGE EVALUAnON FORM 5 the revised commitment involve a significant reduction in a margin of safety?NO Describe basis below This MOV has a safety margin to CLOSE of 24.4%and a safety margin to OPEN of 21 based on the last diagnostic static test performed in 2001.testing began in 1991, this MOV has had little to no change in output thrust and torque, therefore this one time revision to the commitment will not involve a significant reduction in the margin of safety.If any of the above questions are answered Yes, STOP.Do not proceed with the revision, OR discuss change with NRC and obtain necessary approvals.

IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.IF all three questions are answered NO, THEN go to Part III.(Attach additional sheets as necessary.)

PART III 3.1 Was the original commitment (e.g., response to NOV, etc.)to restore an obligation (e.g., rule, regulation, order or license condition)?

o YES Go to Question 3.2.[8J NO Continue with Part IV.3.2 Is the proposed revised commitment date necessary and justified?

o YES Briefly describe rationale (attach additional sheets as necessary).

IF commitment not yet implemented, THEN notify NAC of revised commitment date prior to the original date in which the commitment was to be completed/satisfied.

o NO STOP.Do not proceed with the revision, OR apply for appropriate regulatory relief.IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.PART IV 4.1 Was the original commitment:

(1)explicitly credited as the basis for a safety decision in an NRC SEA, (2)made in response to an NRC Bulletin or Generic Letter, or (3)made in response to a request for information under 10 CFR 50.54(f)or 10 CFR 2.204?YES Go to Question 4.2.o NO Continue with Part V.EN-U-110 An 9.4 Rev.4 COMMITMENT CHANGE EVALUATION FOAM 5 4.2 Has the original commitment been implemented?

STOP.You have completed this evaluation.

Revise the commitment and notify NRC of revised commitment in summary report.o NO Go to Question 5.1.PART V 5.1 Was the original commitment made to minimize recurrence of a condition adverse to quality (e.g., a long-term corrective action stated in an LER)?YES Go to Question 5.2.o NO STOP.You have completed this evaluation.

Revise the commitment.

No NRC notification required.5.2 Is the revised commitment necessary to minimize recurrence of the condition adverse to quality?o YES Revise the commitment and notify NRC of revised commitment in next CCEF summary report.o NO Revise commitment.

No NRC notification is required.REFERENCES List below the documents (e.g., procedures, NRC submittals, etc.)affected by this change.Doc.Number 110 Description CNRO-97/00004, Entergy 180 Day Response to NRC Generic Letter 96-05 dated 3/17/97 EN-L1-110 ATT 9.4 Rev.4 GGNS Commitment Change Evaluation Number CCE 2011-0002 COMMITMENT CHANGE EVALUAnON FORM 1.0.P-32889 Site Licensing Tracking Number:CCE2011-0002

/Date: CNRO-97/00004, dated 3/17/97, is the Entergy 180 Day to NRC Generic Letter 96-05,"Periodic Verification of Design-Basis Capability of:salret\f-Helatea nllrn*,...

...1 lnOlr!:lft:ll"t Valves" Cancellation o Historic/HistiRetired/NEI f2.J Revision o Superseded original commitment been implemented?

Original Commitment

==

Description:==

NO, stop and notify site Licensing Commitment P-32889 is addressed in the original GL 96-05 response per CNRO-96/00016, dated 11/1 and restated verbatim in the 180-day response per CNRO-97/00004.

This commitment tracks the of general program guidance and methodology at each EOI site in site specific programs.The 180-day response provides a summary of the"EOI Safety-Related Motor Operated Valve Periodic Verification and includes the following: "The following matrix provides the results of the combined risk ranking and setup ratio used to determine a maximum bounding test frequency.

In addition, the maximum interval between static STATIC TEST FREQUENCY MATRIX3C c1es6C cles6C c1es H-H (1)Revised Commitment

==

Description:==

3C cles4C cles6C c1es H (2)2C c1es4C cles6C cles M (3)2C c1es3C c1es4C cles L (4)Make a one-cycle one-time extension to the Static Test Frequency interval for 1 E51 F078 (RCIC Turbine Exhaust Inboard Vacuum Breaker Valve), that will also correspond to a one-time 4 month extension to the maximum interval (10 years)between static tests.The valve was last tested on 11/17/2001 and to meet the commitment, the valve must be tested by 11/17/2011.

The valve will be tested during RF18 (Feb-April 2012)so GGNS is requestinga6 month extension beyond the 10 year commitment.

Summary of Justification for Change (attach additional sheets if necessary):

1 E51 F078 was scheduled for static diagnostic testing during CYCLE 18 during the March 2011 RCIC system outage.The RCIC system outage was in the process of moved to July of 2011 but because of the events to the nuclear plants in Japan in March of 2001, the GGNS management team decided to move all on-line RCIC work to refuel outage 18 to reduce any risk of having RCIC inoperable.

To statically test the 1 E51 F078 valve requires that the breaker for the valve be tagged in the OPEN position while the test equipment is being connected, thus possibly making RCIC inoperable.

To reduce plant risk, the site (GGNS)is requesting a deferral of the late date for performing the diagnostic test on valve 1 E51 F078 until 5/17/2012 to accommodate diagnostic testing the valve in Refuel 18.To approve this deferral requires a one-time one-cycle test-interval-extension for this valve to be made.This is acceptable because this valve has a high safety margin (CLOSE: 1370.2%)and there have not been any failures or EN-L1-110 An 9.4 Rev.4 COMMITMENT CHANGEEVALUATIONFORM stroke time anomalies noted in the past 10 years based on a review of the results of the quarterly stroke time test performed per 06-0P-1 E51-Q-0002.

The valve has a PM task that monitors the condition of the assembly every 36 months and no abnormalities have been identified.

Also no failures of this MOV has been observed over the past 10 years based on a search of peRS.Prepared By:

_Management Approval:_Li_n_d.....a_P_a_tt.....e_rs.....

__Print Name/Signature Forward completed form to site Licensing.

Site Licensing Management (or designee)Concurrence:

Christina Perino/

O.D-Print Name1I1t.4falll PART I Date:---t.r............

'-f-L-'---

Date: i'1"'/r 1.1 Is the existing commitment located in the Updated Final Safety Analysis Report, Emergency Plan, Quality Assurance Program Manual, Fire Hazards Analysis, or Security Plan?o YES STOP.Do not proceed with this evaluation.

Instead use appropriate codified process (e.g., 10 CFR 50.71(e), 10 CFR 50.54,10 CFR 50.59, 10 CFR 50.55)to evaluate commitmentNO Go to Part It.PART II 2.1 Could the change negatively impact the ability of a System, Structure, or Component (SSC)to perform its specified safety function or negatively impact the ability of plant personnel to ensure the SSC is capable of performing its specified safety function?YES Go to Question 2.2.o NO Continue with Part III.Briefly describe rationale:

EN-L1-110 ATT 9.4 Rev.4 COMMITMENT CHANGE EVALUATION FORM 3 of 5 2.2 Perform a safety evaluation using the following 10 CFR 50.92 criteria to determine if a significant hazards consideration exists:-Does the revised commitment involve a significant increase in the probability or consequences of an accident previously evaluated?

YES NO Describe basis below This commitment is to perform diagnostic testing on 1 E51 F078 to monitor the performance of the MOV on a frequency not to exceed 10 years.The 1 E51 F078 has a safety function to CLOSE automatically on a combination of high drywell pressure and low reactor pressure to provide containment isolation when RCIC is not functional during a LOCA.The 1 E51 F078 is normally CLOSED during RCIC standby operation per system operating instructions 04-1-01-E51-1.

The 1 E51 F078 MOV has a PM task that monitors the condition of the assembly every 36 months and no abnormalities have been identified over the past 10 years.Based on a search of PCAS, no failures of this MOV has been observed over the past 10 years.There have also not been any failures or stroke time anomalies noted in the past 10 years based on a review of the results of the quarterly stroke time test performed per 06-0P-1 E51-Q-0002.

Therefore based on the discussion above, a one time extension of the committed testing frequency would not cause a significant increase in the probability or consequence of an accident previously evaluated.

-Does the revised commitment create the possibility of a new or different kind of accident from any previously evaluated?

DYES r8J NO Describe basis below Allowing the 1 E51 F078 valve to be diagnostically tested at a one time frequency of 10 years and 6 months will not create the possibility of a new or different kind of accident from any previously evaluated since the diagnostic testing, performed now ona4 year frequency, primarily monitors for valve and actuator degradation and test the actuator capability to produce enough thrust to close the valve against design basis accident pressures.

Past testing has shown very minor changes in the output torque or thrust of this MOV.Based on the previous static testing, safety margin and quarterly stroke history, exceeding the 10 static test frequency should innoway jeopardize the functionality of this MOV.EN-U-110 A TT 9.4 Rev.4 COMMITMENT CHANGE EVALUATION FORM Page 4 of 5-Does the revised commitment involve a significant reduction in a margin of safety?DYES r8J NO Describe basis below This MOV has a safety margin to CLOSE of 1370.2%based on the last diagnostic static test performed in 2001.Since testing began in 1991, this MOV has had very minor changes in output thrust and torque, therefore this one time revision to the commitment will not involve a significant reduction in the margin of safety.If any of the above questions are answered Yes, STOP.Do not proceed with the revision, OR discuss change with NRC and obtain necessary approvals.

IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.IF all three questions are answered NO, THEN go to Part III.(Attach additional sheets as necessary.)

PART III 3.1 Was the original commitment (e.g., response to NOV, etc.)to restore an obligation (e.g., rule, regulation, order or license condition)?

o YES Go to Question 3.2.L8l NO Continue with Part IV.3.2 Is the proposed revised commitment date necessary and justified?

o YES Briefly describe rationale (attach additional sheets as necessary).

IF commitment notyetimplemented, THEN notify NRC of revised commitment date prior to the original date in which the commitment was to be completed/satisfied.

o NO STOP.Do not proceed with the revision, OR apply for appropriate regulatory relief.IF NRC approval obtained, THEN revise commitment; no further evaluation is required and no further NRC notification is required.PART IV 4.1 Was the original commitment:

(1)explicitly credited as the basis for a safety decision in an NRC SER, (2)made in response to an NRC Bulletin or Generic Letter, or (3)made in response to a request for information under 10 CFR 50.54(1)or 10 CFR 2.204?r8J YES Go to Question 4.2.o NO Continue with Part V.EN-Ll-110 ATT 9.4 Rev.4 COMMITMENT CHANGE EVALUATION FORM 5 4.2 Has the original commitment been implemented?

C8J YES STOP.You have completed this evaluation.

Revise the commitment and notify NRC of revised commitment in CCEF summary report.o NO Go to Question 5.1.PART V 5.1 Was the original commitment made to minimize recurrence of a condition adverse to quality (e.g., a long-term corrective action stated in an LER)?o YES Go to Question 5.2.o NO STOP.You have completed this evaluation.

Revise the commitment.

No NRC notification required.5.2 Is the revised commitment necessary to minimize recurrence of the condition adverse to quality?o YES Revise the commitment and notify NRC of revised commitment in next CCEF summary report.o NO Revise commitment.

No NRC notification is required.REFERENCES List below the documents (e.g., procedures, NRC submittals, etc.)affected by this change.Doc.Number 110 Description CNRO-97/00004, Entergy 180 Day Response to NRC Generic Letter 96-05 dated 3/17/97 EN-L1-110 An 9.4 Rev.4