GNRO-2007/00009, License Amendment Request, Application for Technical Specifications (TS) Change Regarding Mode Change Limitations (TSTF-359) Using the Consolidated Line Item Improvement Process (Cliip), and Correct Example 1.4-1 (TSTF-485)

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License Amendment Request, Application for Technical Specifications (TS) Change Regarding Mode Change Limitations (TSTF-359) Using the Consolidated Line Item Improvement Process (Cliip), and Correct Example 1.4-1 (TSTF-485)
ML070400447
Person / Time
Site: Grand Gulf Entergy icon.png
Issue date: 02/08/2007
From: Brian W
Entergy Operations
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
GNRO-2007/00009
Download: ML070400447 (49)
v • d • e


Text

Entergy P.O. Box 756 Port Gibson, MS 391 50 Tel 601 437 6409 William R. Brian V!ce President ~ Operations Grand Gulf Nuclear Station February 8,2007 US. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555

SUBJECT:

License Amendment Request Application for Technical Specifications (TS) Change Regarding MODE Change Limitations (TSTF-359) Using the Consolidated Line Item Improvement Process (CLIIP), and Correct Example 1.4-1 (TSTF-485)

Grand Gulf Nuclear Station, Unit 1 Docket No. 50-416 License No. NPF-29

Dear Sir or Madam:

Pursuant to 10 CFR 50.90, Entergy Operations, Inc. (Entergy) hereby requests the following amendment for Grand Gulf Nuclear Station, Unit 1 (GGNS).

The proposed amendment would modrfy TS requirements for MODE change limitations in LCO 3.0.4 and SR 3.0.4. The proposed TS changes are consistent with Revision 9 of NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specification Change Traveler, TSTF-359, Increase Flexibility in MODE Restraints.

The availability of this TS improvement was announced in the Federal Register on April 4, 2003 as part of the Consolidated Line Item Improvement Process (CLIIP).

Changes were also required to TS Section 1.4, Frequency, Example I

.4-1 to make the example consistent with the changes to SR 3.0.4. These changes are supported by TSTF-485, Revision 0.

Attachment I provides a description of the proposed changes, the requested confirmation of applicability, and plant-specific verifications. Table 1 of Attachment 1 provides a brief summary of the TS changes. Attachment 2 provides the existing TS pages marked-up to show the proposed changes. Attachment 3 provides the existing TS Bases pages marked-up to show the proposed changes. The Bases changes are provided for information only.

GGNS requests approval of the proposed License Amendment by August 15,2007, with the amendment being implemented within 60 days from the date of approval. In accordance with 10 CFR 50.91, a copy of this application, with attachments, is being provided to the designated Mississippi State Official.

G N RO-2007/00009 Page 2 of 3 The proposed change has been evaluated in accordance with 10 CFR 50.9l(a)(l) using criteria in 10 CFR 50.92(c) and it has been determined that this change involves no significant hazards consideration. The bases for these determinations are included in the attached submittal.

The proposed change includes no new commitments.

If you have any questions or require additional information, please contact Greg Norris at 225-336-6391.

I declare under penalty of perjury that the foregoing is true and correct. Executed on February 8, 2007.

Sincerely, WRB/M LC/amt Attachments:

1. Description and Assessment
2. Proposed Technical Specification Changes (mark-up)
3. Changes to Technical Specification Bases Pages (mark-up) - For Information Only

GNRO-2007/00009 Page 3 of 3 cc:

Dr. Bruce S. Mallett Regional Administrator, Region IV U. S. Nuclear Regulatory Commission 61 1 Ryan Plaza Drive, Suite 400 Arlington, TX 7601 1-4005 U. S. Nuclear Regulatory Commission ATTN: Mr. Bhalchandra Vaidya, NRWDORL (w/2)

All":

ADDRESSEE ONLY ATTN: U. S. Postal Delivery Address Only Mail Stop OWFN/ 0-7D1 A Washington, DC 20555-0001 Mr. Brian W. Amy, MD, MHA, MPH Mississippi Department of Health P. 0. Box 1700 Jackson, MS 3921 5-1 700 NRC Senior Resident Inspector Grand Gulf Nuclear Station Port Gibson, MS 391 50 GNRO-2007/00009 Description and Assessment to Page 1 of 4 GNRO-2007/00009 1.O DESCRIPTION The proposed amendment would modify the Grand Gulf Nuclear Station (GGNS) Technical Specifications (is) requirements for Mode change limitations in LCO 3.0.4 and SR 3.0.4.

The GGNS TS already contain a TS Bases Control Program (TS 5.5.1 1) and SR 3.0.1, thus these requirements do not need to be added as described in NRC-approved Industry Technical Specification Task Force (TSTF) Standard Technical Specification Change, TSTF-359, Rev. 9, Increase Flexibility in MODE Restraints.

The proposed TS changes are consistent with Nuclear Regulatory Commission (NRC) approved Industry Technical Specification Task Force (TSTF) Standard TS (STS) change, TSTF-359, Revision 8, as modified by the notice in the Federal Register; published on April 4, 2003 (68 FR 16579). That Federal Register Notice (FRN) announced the availability of this TS improvement through the Consolidated Line Item Improvement Process (CLIIP).

TSTF-359, Revision 8 was subsequently revised to incorporate the modifications discussed in the April 4,2003, FRN and other minor changes. TSTF-359, Revision 9 was subsequently submitted to the NRC on April 28,2003 and was approved by the NRC on May 9,2003.

2.0 ASSESSMENT

2.1 ADD licabilitv of Published Safetv Evaluation Entergy Operations, Inc. (EOI) has reviewed the safety evaluation published on April 4, 2003 (68 FR 16579) as part of the CLIIP Notice of Availability. This verification included a review of the NRC staffs safety evaluation, as well as the supporting information provided to support TSTF-359, Rev. 9. EOI has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by the NRC staff are applicable to GGNS and justify this amendment for the incorporation of the changes to the GGNS TS.

2.2 Optional Chanqes and Variations EOI is adopting the TS changes described in TSTF-359, Revision 9, and the NRC staffs model safety evaluation published on April 4, 2003, with the following exceptions.

1. Due to differences between the GGNS TS and TS Bases and their corresponding model BWW6 STS (NUREG-1434), in some cases variances from the TSTF marked-up changes are made. These variances are discussed below and do not affect the adoption or application of TSTF-359, Revision 9.
a. In the TSTF mark-ups, BWW6 STS 3.6.3.1, Primary Containment Hydrogen Recombiners, the NOTE LCO 3.0.4 is not applicable, was removed from REQUIRED ACTION A. The GGNS equivalent TS was deleted per TS Amendment 166, issued in NRC letter dated June 16,2004. Therefore, GGNS TS 3.6.3.1 markups are not included in this package.

to Page 2 of 4 GNRO-2007/00009

2. TS Section 1.4 Frequency

==

Description:==

Section 1.4, Frequency, Example 1.4-1, is revised to be consistent with the changes to SR 3.0.4. SR 3.0.4 was revised by TSTF-359, Revision 9, and the current example is not consistent with the Technical Specification requirements. The second paragraph of Example 1.4-1 is revised to reflect the changes made to SR 3.0.4.

Justification: The changes made in TSTF 359 to SR 3.0.4 have made certain statements in Example 1.4-1 incorrect. This change is consistent with TSTF-485, Rev. 0.

Table 1 of this attachment provides a brief summary of the changes.

3.0 REGULATORY ANALYSIS

3.1 No Siqnificant Hazards Consideration Determination EOI has reviewed the proposed no significant hazards consideration determination published on April 4, 2003 (68 FR 16579) as part of the CLIIP. EOI has concluded that the proposed determination presented in the notice is applicable to GGNS and the determination is hereby incorporated by reference to satisfy the requirements of 10 CFR 50.91 (a).

3.2 Verification and Commitments As discussed in the notice of availability published in the Federal Register on April 4, 2003 (68 FR 16579) for this TS improvement, the following plant-specific verifications were performed as follows:

EOI has proposed changes to the TS Bases for LCO 3.0.4 and SR 3.0.4 which state that use of the TS mode change limitation flexibility established by LCO 3.0.4 and SR 3.0.4 is not to be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to operable status before entering an associated MODE or other specified condition in the TS Applicability.

The proposed changes also include changes to the Bases for LCO 3.0.4 and SR 3.0.4 that provide details on how to implement the new requirements. The Bases changes provide guidance for changing Modes or other specified conditions in the Applicability when an LCO is not met. The Bases changes describe in detail how: LCO 3.0.4.a allows entry into a MODE or other specified condition in the Applicability with the LCO not met when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; LCO 3.0.4.b allows entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; and LCO 3.0.4.c allows entry into a MODE or other specified condition in the Applicability with the LCO not met to Page 3 of 4 GNRO-2007/00009 based on a Note in the Specification, which is typically applied to Specifications which describe values and parameters (e.g., RCS Specific Activity) though it may be applied to other Specifications based on NRC plant-specific approval. The Bases also state that any risk impact should be managed through the program in place to implement 10 CFR 50.65(a)(4) and its implementation guidance, NRC Regulatory Guide 1.1 82, Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants, and that the results of the risk assessment shall be considered in determining the acceptability of entering the MODE or other specified condition in the Applicability, and any corresponding risk management actions.

Upon entry into a MODE or other specified condition in the Applicability with the LCO not met, LCO 3.0.1 and LCO 3.0.2 require entry into the applicable Conditions and Required Actions until the Condition is resolved, until the LCO is met, or until the unit is not within the Applicability of the Technical Specification. The Bases also state that SR 3.0.4 does not restrict changing MODES or other specified conditions of the Applicability when a Surveillance has not been performed within the specified Frequency, provided the requirement to declare the LCO not met has been delayed in accordance with SR 3.0.3.

Finally, as noted in Section 1.O above, the GGNS TS already contain a TS Bases Control Program (TS 5.5.1 1) and SR 3.0.1, thus these requirements do not need to be added to the TS.

4.0 ENVIRONMENTAL EVALUATION EOI has reviewed the environmental evaluation included in the model safety evaluation published on April 4,2003 (68 FR 16579) as part of the CLIIP. EOI has concluded that the staffs findings presented in that evaluation are applicable to GGNS and the evaluation is hereby incorporated by reference for this application.

to Page 4 of 4 GNRO-2007/00009 1.4 TABLE 1 The second paragraph of Example 1.4-1 is revised to reflect the changes made to SR 3.0.4.

1.4 Description of Change GGNS TS No.

STS No.

LCO 3.0.4 Existing LCO has been replaced in its entirety with the revised LCO 3.0.4 insert.

36.3.2 36.33 3.6.3.2 3.6.3.3 SR 3.0.4 The REQUIRED ACTION A.l NOTE stating LCO 3.0.4 is not applicable. has been deleted.

The REQUIRED ACTION A.l NOTE stating LCO 3.0.4 is not applicable. has been deleted.

Existing SR has been replaced in its entirety with the revised insert.

SR 3.0.4 I 3.3.3.1 1 3.3.3.1 The ACTIONS NOTE stating LCO 3.0.4 is not applicable. has been deleted and the remaining NOTE renumbered.

3.3.3.2 The ACTIONS NOTE stating LCO 3.0.4 is not applicable. has been deleted and the remainina NOTE renumbered.

3.3.3.2 1

The ACTIONS NOTE stating LCO 3.0.4 is not applicable. has 3.4.7 13.4.7 I been deleted.

3.4.8 3.4.8 The existing NOTE for REQUIRED ACTIONS is replaced with a NOTE stating LCO 3.0.4.c is not applicable.

3.4.9 3.4.9 The ACTIONS NOTE stating LCO 3.0.4 is not applicable. has been deleted and the remaining NOTE renumbered.

3.5.1 3.5.3 3.6.3.1 3.5.1 3.5.3 A NOTE is added to the ACTIONS stating LCO 3.0.4.b is not applicable to HPCS.

A NOTE is added to the ACTIONS stating LCO 3.0.4.b is not applicable to RCIC.

Not applicable to GGNS. TS 3.6.3.1 Deleted.

3.8.1 3.8.1 A NOTE is added to the ACTIONS stating LCO 3.0.4.b is not applicable to DGs.

GNRO-2007/00009 Proposed Technical Specification Changes (mark-up) to Page 1 of 16 GNRO-2007/00009 Frequency 1.4 1.4 Frequency EXAMPLES EMPLE 1.4-a (contlnued)

I S U R V E I L M E Verlfy f l o w 1s wlthln limits.

Once wtthln 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after it 25% RTP a

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter Example 1.4-2 has two Frequencles.

The f l r s t t s a one tlm performance Frequency, and the second i s o f the type shown i n Example 1.4-1.

The logical connector 'w indlcotes that both Fdquency requirements must be met.

Each time reactor power i s Increased frw a power level < 25% RTP t o L 25% RTP, the Surveillance must be perfomed wlthln 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

The use o f "once" indicates a single performance w i l l satisfy the specified Frequency (assuming no other Frequencies are connected by "w).

This type o f Frequency does not quallfy for the extension allowed by SR 3.0.2.

(contlnued)

GRAND GULF 1.O-26 Amendment No.

to Page 2 of 16 GNRO-2007/00009 LCO Appl icabil i ty 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the WOES or other specified conditions in the Applicability, except as provided in LCO 3.0.2 and LCO 3.0.7.

LCO 3.0.2 Upon discovery of a fallure to meet an LCO, the Required Actions o f the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO it met or i s no longer applicable prior to expiration o f the speclfied Completion Tlme(s), conpletion o f the Required Actlon(s) i s not required, unless othemlse stated.

'LCO 3.0.3 Yhen an LCO is not met and the associated ACTIONS are not met, an assoclatd ACTION is not provided, or If directed by the associated ACTIONS, the unit shall be placed in a HOOE or other speclfied condltion in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to place the unit, as applicable, in:

a. WE 2 wlthin 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />;
b.

WOE 3 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />; and

c.

WDE 4 within 37 hours4.282407e-4 days <br />0.0103 hours <br />6.117725e-5 weeks <br />1.40785e-5 months <br />.

Exceptions to this Speclfication are stated in the 1 ndivldurl Specif ications.

Where correctlve measures are completed that permit operation In accordance with the LCO o r ACTIMS, completion o f the actions required by LCO 3.0.3 Is not required.

LCO 3.0.3 Is only applicable In MODES 1, 2, and 3.

lcont i nued 1 GRAND GULF 3.0-1 Amendment No. 3p6 to Page 3 of 16 GNRO-2007/00009 LCO A p p l i c a b i l i t y 3.0 3.0 LCO APPLICABILITY I

LCO 3.0.5 Equipment removed from s e r v i c e o r declared i n o p e r a b l e t o comply w i t h ACTIONS may be returned t o s e r v i c e under a d m i n i s t r a t i v e c o n t r o l s o l e l y t o perform t e s t i n g r e q u i r e d t o demonstrate i t s OPERABILITY o r t h e OPERABILITY o f o t h e r equipment.

T h i s i s an exception t o LCO 3.0.2 f o r t h e system r e t u r n e d t o s e r v i c e under a d m i n i s t r a t i v e c o n t r o l t o perform t h e t e s t i n g r e q u i r e d t o demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO i s n o t met s o l e l y due t o a support system LCO n o t being met, t h e Conditions and Required A c t i o n s associated with t h i s supported system a r e n o t r e q u i r e d t o be entered.

Only t h e support system LCO ACTIONS a r e r e q u i r e d t o be entered.

LCO 3.0.2 f o r t h e supported system.

I n t h i s event, an e v a l u a t i o n s h a l l be performed i n accordance w i t h S p e c i f i c a t i o n 5.5.10. "Safety Function Determination Program (SFDP)."

If a loss of safety f u n c t i o n i s determined t o e x i s t by t h i s program, t h e a p p r o p r i a t e Conditions and Required A c t i o n s o f t h e LCO i n which t h e loss o f s a f e t y f u n c t i o n e x i s t s are r e q u i r e d t o be entered.

When a support system's Required A c t i o n d i r e c t s a supported system t o be declared i n o p e r a b l e o r d i r e c t s e n t r y i n t o Conditions and Required Actions f o r a supported system, t h e a p p l i c a b l e C o n d i t i o n s and Required Actions s h a l l be entered i n accordance w i t h LCO 3.0.2.

T h i s i s an exception t o I

( c o n t i nued)

GRAND G U L F 3.0-2 Amendment No. K9-to Page 4 of 16 G N RO-2007/00009 SR Applicability 3.0 3.0 SR APPLICABILITY (contfnued)

GRAND GULF 3.0-5 hendarent No. 120 to Page 5 of 16 G N RO-2007/00009 CONDITION A.

One or more Functlonr with one required channel i noperabl e.

PAH Instrumentat 1 on 3.3.3.1 REQUIRED ACTION COnFLETION TIME A.1 Restore required 30 days channel t o OPERABLE status.

3.3 INSTRUMENTATION 3.3.3.1 Post Accident Monitoring (Pffl) Instrumentation B.

Required Actlon and associated Colspletlon TIM o f Condltion A not met.

LCO 3.3.3.1 The PAM instrumentation for each Function i n Table 3.3.3.1-1 shall be OPERABLE.

B.l I n i t i a t e action t o IaPadiately prepare and submit a Spec1 a1 Report.

APPLICABILITY:

MODES t and 2.

C.

One or more Functlons with two required channels 1 noperable.

C.1 Restore one required 7 days channel t o OPERABLE status.

I I

I I

I I

I I

~

~~

(continued)

GRAND GULF 3.3-19 Amendment No. %

to Page 6of 16 GNRO-2007/00009 CONDITION A.

One or mre requirad Functions inoperable.

Remote Shutdown System 3.3.3.2

~

REQUIRED ACTION COMPLETIOW TIME A.l Restore requlred 30 days Function to OPERABLE status.

3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System B. Required Action and associ ated Completion Time not mt.

LCO 3.3.3.2 The Remote Shutdown System Functions shall be OPERABLE.

8.1 Be in WOE 3.

APPLICABILIN:

MODES 1 and 2.

SURVE I LLAHCE SR 3.3.3.2.1 Perform CHANNEL CHECK for each requlred instrumentation channel that i s normally energized.

FREQUENCY 31 days 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIRENWrS CRAND GULF 3.3-23 hndment No. -.tQb-to Page 7of 16 GNRO-2007/00009 A.

Drywell floor drain sump monitoring system inoperable.

RCS Leakage Detection Instrumentation 3.4.7

~

A. l Restore drywell floor 30 days I

drain sump monitoring system to OPERABLE 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Leakage Detection Instrumentation

8. Required drywell atmospheric monitoring system inoperable.

LCO 3.4.7 The following RCS leakage de-rc OPERABLE:

B. l Analyze grab samples Once per o f drywell 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> atmosphere.

ion instrumentation shall be

a.

Drywell floor drain sump monitoring system;

b.

One channel o f either drywell atmospheric particulate o r

c.

Drywell air cooler condensate flow rate monitoring atmospheric gaseous monitoring system: and sy s tem.

A P P L I C A B I L I T Y :

MODESJ, 2, and 3.

ACTIONS

~

REQUIRED ACTION I COMPLETION T I M E I

COMDIT ION status.

GRAND GULF 3.4-16 Amendment NO. H 3, e to Page 8 of 16 G N RO-2007/00009 RCS Specific A c t i v i t y 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Specific Activity LCO 3.4.8 The DOSE EQUIVALENT 1-131 specific a c t i v i t y o f the reactor coolant shall be s 0.2 pCf/gnr.

APPLICABILITY:

WE I, MODES 2 and 3 wlth any main steam l i n e not isolated.

ACTIONS CONDITION A.

Reactor coolant I

specific a c t l v i t y

> 0.2 jti/gm and 5 4.0 &i/gm WSE EQUIVALENT 1-131.

8.

Required Actlon and associated Colrpletion Time o f Condition A not met.

!?!l Reactor cool ant specific a c t i v i t y

> 4.0 fii/gm DOSE EQUIVALENT 1-131.

8.1 Determine OISE EQUIVALENT 1-131.

4B2 8.2.1 Isolate a l l main steam lines.

OR 8.2.2.1 Be i n MODE 3.

AND 8.2.2.2 Be in W E 4.

6 N S R T Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> 48 hours Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> 12 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours GRAND GULF 3.4-19 Amendment No. SQ--

to Page 9 of 16 GNRO-2007/00009 CON0 I T ION RHR Shutdown C o o l i n g System-Hot Shutdown 3.4.9 REQUIRED ACTION COMPLETION TIME 3.4 REACTOR COOLANT SYSTEM (RCS)

A.

One or two RHR shutdown cool i n g subsystems inoperable.

3.4.9 Residual Heat Removal (RHR) Shutdown C o o l i n g System-Hot Shutdown A. l I n i t i a t e a c t i o n t o r e s t o r e RHR shutdown c o o l i n g subsystem(s) t o OPERABLE s t a t u s.

LCO 3.4.9 Two RHR shutdown c o o l i n g subsystems s h a l l be OPERABLE, and, w i t h no r e c i r c u l a t i o n pump i n o p e r a t i o n, a t l e a s t one RHR shutdown c o o l i n g subsystem s h a l l be i n o p e r a t i o n.

N O T E S - - - - - - - - - - - - - - - - - - - - - - - - - - -

1.

Both RHR shutdown c o o l f n g subsystems and r e c i r c u l a t i o n pumps may n o t be i n o p e r a t i o n for up t o 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> p e r I

8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> p e r i o d.

One RHR shutdown c o o l i n g subsystem may be i n o p e r a b l e for up t o 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for performance o f S u r v e i l l a n c e s.

2.

APPLICABILITY:

MODE 3 with r e a c t o r steam dome pressure l e s s than t h e RHR c u t i n permissive pressure.

Immediately (continued)

GRAND GULF 3.4-21 Amendment No. M,&&.-

to Page 10 of 16 GNRO-2007/00009 REQUIRED ACTION ECCS-Opera t 1 ng 3.5.1 COMPLETION T I M E 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION C O O L I N G

( R C I C ) SYSTEM I

8.2 Restore HPCS System t o OPERABLE status.

3. 5. 1 ECCS-Operating LCO 3. 5. 1 Each ECCS i n j e c t i o n / s p r a y subsystem and the Automatic Depressurization System (ADS) f u n c t i o n o f e i g h t s a i e t y i r e l i e f valves s h a l l be OPERABLE.

.......................... H O T E - - -. - - - - - - - - - - - - - - - - - - - - - - - - - -

Low pressure coolant i n j e c t i o n ( L P C I ) subsystems may be considered OPERABLE during alignment and operation for decay heat removal w l t h reactor steam dome pressure less than the residual heat removal c u t i n permissive pressure i n MODE 3.

i f capable o f being manually realigned and not otherwise inoperable.

APPLICABILITY:

MODE 1, MODES 2 and 3, except ADS valves a r e not required t o be OPERABLE w i t h reactor steam dome pressure s 150 psig.

ACTIONS COWITION A.

One low pressure ECCS Injection/spray subsystem inoperable.

B.

High Pressure Core Spray (HPCS) System inoperable.

A. l Restore low pressure ECCS injection/spray subsystem t o OPERABLE status.

7 days B.1 V e r i f y by administrative means R C I C System i s OPERABLE when RCIC i s required t o be OPERABLE.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 14 days (continued)

GRAND GULF 3.5-1 Amendment No. W, &

to Page 11 of 16 G N RO-2007/00009 RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY:

MODE 1, HOOES 2 and 3 with reactor s t e m d m

pressure > 150 psig.

COHOITION A. RCIC System inoperabl a.

B.

Required Action and associated Completion Time not met.

REQUIRED ACTION A. l Verify by admi n i strat ive means High Pressure Core Spray System i s OPERABLE.

!Y!Q A.2 Restore RCIC System to OPERABLE status.

B.l Be in WE 3.

AND 8.2 Reduce reactor steam d m pressure to s 150 psig.

COnPLETIOn TIME 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 14 days 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours GRAND GULF 3.5-10 to Page 12of 16 GNRO-2007/00009 Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters LCO 3.6.3.2 Two divisions o f primary containment and drywell hydrogen igniters shall be OPERABLE, each with > 90% o f the associated igniter assemblies OPERABLE.

APPLICABILIN:

MIXES I and 2.

ACTIONS CONDITION A. One primary containment and drywell hydrogen igniter division inoperable.

B.

Two primary containment and drywell hydrogen Ignlter dlvisions inoperable.

~

REQUIRED ACTION Restore primary con ta i m e n t and drywell hydrogen igniter division to OPERABLE status.

B.l Verlfy by administrative means that the hydrogen control function is maintained.

A&!

B.2 Restore one primary containment and drywell hydrogen igniter division to OPERABLE status.

GRANO GULF 3.6-37 COMPLETION TIME

)

30 days 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 7 days (continued)

Amendment No. GW--

to Page 13 of 16 GNRO-2007/00009

)

30 days Drywell Purge System 3.6.3.3 3.6 CONTAINMENT SYSTEHS 3.6.3.3 Drywell Purge System LCO 3.6.3.3 Two drywell purge subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTIONS GONOITION A.

One drywell purge subsystem inoperable.

B.

Two drywell purge subsystems inoperable.

C. Required Action and associated Cowl etion Time not met.

~

REQUIRE0 ACTION A. l L

3.0 is t

Restore drywell purge subsystem to OPERABLE status.

B.l Verlfy by admini strati ve means that the hydrogen control function i s mat nta i ned.

AND 8.2 Restore one drywell purge subsystem to OPERABLE status.

~

c. 1 Be in t4OOE 3.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 7 days 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> GRAND GULF 3.6-40 Amendment No.

to Page 14of 16 GNRO-2007/00009 AC Sources-Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources-Operating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a.

Two qualified c i r c u i t s between the o f f s i t e transmission network and the onsite Class 1E AC Electric Power O i s t ri but 1 on System; Three diesel generators (DGs); and Divtsion 1 and Division 2 automatic load sequencers.

b.
c.

A.

One required o f f s i t e c i r c u i t inoperable for reasons other than Condition F.

A.l Perform SR 3.8.1.1 f o r OPERABLE required o f f s i t e c i rcui t.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> m

Once per a hours thereafter AND (continued)

GRAND GULF 3.8-1 Amendment No. +20--

to Page 15 of 16 GNRO-2007/00009 INSERT 1A (LCO 3.0.4)

When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability fix an unlimited period of time;
b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, ifappropriate; exceptions to this Specification are stated in the individual Specifications, or
c. W e n an allowance is stated in the individual value, parameter, or other Specification This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

INSERT 2A (SR 3.0.4)

Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry mto MODES or other specilied conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

INSERT 3A (RCS SPECIFIC ACTIVITY) to Page 16 of 16 G N RO-2007/00009 INSERT 5A (LCO 3.5.3, RCIC SYSTEM)

INSERT 6A (LCO 3.8.1, AC SOURCES - OPERATING)

(b)

SERI is required to notify the NRC in writing prior to any change in (i) the terms or conditions of any new or existing sale or lease agreements executed as part of the above authorized financial transactions, (ii) the GGNS 3nit 1 operating agreement, (iii) the existing property insurance coverage for GGNS Unit 1 that would materially alter the representations and conditions set forth in the Staff's Safety Evaluation Report dated December 19, 1988 attached to Amendment No. 54.

In addition, SERI is required to notify the NRC of any action by a lessor or other successor in interest to SERI that may have an effect on the operation of the facility.

The license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 10CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect: and is subject to the additional conditions specified or incorporated below:

Maximum Power Level Entergy Operations, Inc. is authorized to operate the facility at reactor core power levels not in excess of 3898 megawatts thermal (100 percent power) in accordance with the conditions specified herein.

The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 1 Technical Specifications hereby incorporated into this license. Entergy Operations, Inc. shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

Insert New Amendment The Surveillance Requirements ( S R s ) for Diesel Generator 12 contained in the Technical Specifications and listed below, are not required to be performed immediately upon implementation of Amendment No. 169.

The SRs listed below shall be successfully demonstrated at the next regularly scheduled performance.

SR 3.8.1.9, SR 3.8.1.10, and SR 3.8.1.14 4

Amendment 169 G N RO-2007/00009 Changes to Technical Specification Bases Pages For Information Only to Page 1 of 22 GNRO-2007/00009 LCO A p p l i c a b i l i t y B 3.0 BASES LCO 3.0.3 assemblies i n the associated f u e l storage pool. ' I Therefore, (continued) t h i s LCO can be applicable i n any or a l l MODES.

I f t h e LCO and the Required Actions o f LCO 3.7.6 a r e n o t met w h i l e i n MODE 1, 2, or 3, there i s no safety b e n e f i t t o be gained by p l a c i n g the u n i t i n a shutdown condition.

The Required Action o f LCO 3.7.6 o f "Suspend movement o f i r r a d i a t e d f u e l assemblies i n the associated f u e l storage pool(s)" i s t h e appropriate Required A c t i o n t o complete i n l i e u o f the actions o f LCO 3.0.3.

i n d i v i dual Specifications.

These exceptions are addressed i n the LCO 3.0.4 the requirements p p l i c a b i l i t y d e s i r be entered; and

b.

Continued non red Actions.

permit continued d period o f time i n a GRAND GULF B 3.0-5 Revision No. 8---.

to Page 2 of 22 G N RO-2007/00009 LCO A p p l i c a b i l i t y 6 3.0 BASES remedial measure t o be taken.

The ACTIONS f o r an inoperable required b a t t e r y charger i n LCO 3.8.4, "DC Sources - Operating," and LCO 3.8.5, "DC Sources - Shutdown," include a Note e x p l i c i t l y precluding e n t r y i n t o s p e c i f i c MODES or other specified conditions o f the A p p l i c a b i l i t y while r e l y i n g on the ACTIONS.

With an inoperable required b a t t e r y charger t h i s Note i n LCO 3.8.4 p r o h i b i t s entry i n MODE 1, 2, o r 3, except during power decrease and i n LCO 3.8.5 p r o h i b i t s s t a r t i n g movement o f recently i r r a d i a t e d fuel, (i.e.,

fuel t h a t has occupied p a r t o f a c r i t i c a l reactor core w i t h i n the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />),

entering MODE 4 from MODE 5, or loading f u e l i n t o the vessel i f the vessel i s defueled.

I continued I

GRAND GULF B 3.0-6 P

to Page 3 of 22 GNRO-2007/00009 LCO Appl i cabi 1 i t y B 3.0 BASES I

LCO 3.0.4 I

LCO 3.0.5 LCO 3.0.5 e s t a b l i s h e s t h e allowance f o r r e s t o r i n g equipment t o s e r v i c e under a d m i n i s t r a t i v e c o n t r o l s when i t has been removed from s e r v i c e o r declared i n o p e r a b l e t o comply w i t h ACTIONS.

The s o l e purpose o f t h i s S p e c i f i c a t i o n i s t o

( c o n t i n u e d l GRAND GULF B 3.0-6a 7

to Page 4 of 22 GNRO-2007/00009 SR Applicability 8 3.0 BASES

~

SR 3.0.3 Completion o f the Surveillance within the delay period (continued) allowed by this Specification, or within the Completion T i m o f the ACTIONS, restores compliance with SR 3.0.1.

f this Specificatlo as endorsing the f a i l GRAND GULF 8 3.0-14 Revision Ha. 0 to Page 5 of 22 GNRO-2007/00009 SR Appl icabi 1 i ty 9 3.0 BASES GRAND GULF 8 3.0-15 Revision N 0. L to Page 6 of 22 GNRO-2007/00009 PAM Instrumentation I

8 3.3.3.1 BASES LCO M Penetr&ton Flow P8th. h Conta inmnt Ito 18tIOQ RIV) Potltfoa (contin flow path. the LCO raqulres one channel o f valve position Indlcation I n the control room to br OPERABLE for each automatic PCIV i n r contrinrnt penetration flow prth, i.e.,

two total channels o f PCIV position indicrtion for a panatrrtion f l o w prth with tw autwrtic valves.

For contrimnt penetrrtions with only one rutol~itlc PCIV having control rom indicrtlan, Note (b) requins a single channol o f valve position Indicrtion t o k OPERABLE.

This i s sufficient to verify ndundrntly the isolatlon strtus o f erch Itolable ponetrrtlon via Indicrted status o f the automatic valve and, IS applicable, prior knowledge o f passive valve or s stem boundary status.

I f r penetrrtlan rutoartic vrlve, closed u n u r l VIIVO, blind flange, or check valve with f l o w t h indication for tho Y PC V(s) In the rssocirtd penetration flow prth i s not needed to d e t e r a h status.

Therefon, the positlon fndicrtion for vrlvrt i n an isolated penetrrtlon Is not required t o k O P E W E.

The PCIV position PAM instruwntation consists o f individual position lndlcrtlon ( o m - closed) i n the control m a for each a u t m t i c contritmnt isolrtion valve I S described i n UFSAR Section 7.5 (Reference 4).

i s isolated by at f 0 8 S t M C l o S d Wtd de-activrtd h tho valve secured, position APPLICABILITY The PAN instrta#ntatlon LCO i s 8 pllcrblr i n mwHS 1 rnd 2.

actions required to a i t t ate O M. The applicable 084s are assuIwd t o occur i n WO s 1 and 2.

I n CYloES 3, 4, and 5, plant conditions rra such thrt the Ilkellhood o f an event t h r t would require PHI instruarntrtion i s e x t m l y low:

therefore, PA)) instnrantrtton i s not required to bo OPERABLE i n these W E S.

There vrriablrs rra related to t t diynosls and preplannod Revlsion b..8-ACTIONS GRAND GULF B 3.3-56 to Page 7 of 22 GNRO-2007/00009 PAM Instrumentation B 3.3.3.1 BASES A Note has to PM instrumentatton channels.

Section 1.3, Completlon Tims, speciflet that once a Condltlon has been entered, subsequent divlslons, rubsystenr, colponentr, or variables expressed I n the Condltlon, dlscovord to bo Inoperable o r not wlthln llmlts, w l l l not rosult In separate entry into tho Condltlon.

Soctlon 1.3 rlso r p. d f l r s that Required Actlonr o f tho Conditlon contlnuo t o apply for each addltlonal frllure, wlth Corpletlan Timer based on l n l t i a l entry into tho Condltlon.

HQ)IIver, tho Requlred Actions f o r Inoporablo PhA Instnmntatfon chlnnolr provfdo rpproprlato coqwnsatory masuros for sopprrrto Inoporablo functlonr.

As such, a Note has bmn provlded that allows tcprrato Condltlon entry f o r each Inoporable PM Function.

4a.k Uhen ona o r more Functlons have ono requlred channel that Is lnoperablo, tho mqulrrrd lnoperablo channel must k restored to OPERABLE status within 30 days.

Tho 30 day Completion Tim Is based on operating ox rlenco and takes Into account Functlon that has only on0 requlrad channel, other non-Regulatory Culde 1.97 Instrument chmnrls to mnltor tho Functlon), the patslvo natulv o f the Instrument (no crltlcal autoutlc actlon 1s ass&

to occur froa theso fnttruwntr), and tho low probrblllty o f an event requlrlng PAIl lnrtrullmtatlon during thls lntewrl.

tho remalnlng OPERABLE churn0 r (s) (or I n tho case o f a

$1 I f r channel has not been restored to OPERABLE status I n 30 drys, this R e q u l d Actlon spoclfles initiation o f actlons to prepare and s u b l t a Speclal Report to tho NRC.

This report discusses thr results o f the root cause evaluation o f the inoperabllity md Identlflet proposed rortoratlve actlons.

Tho Specla1 R q m t shall be submitted I n rccordanco wfth 10 CFR 50.4 within 14 days o f entering Condltion 0.

This Action It appropriate i n l i e u o f a (cont i nueQl GRAND GULF B 3.3-57 Revlsion Ha.-O---

to Page 8 of 22 GNRO-2007/00009 Remote Shutdown System B 3.3.3.2 BASS (continutd)

APPLICABILITY The A m t o Shutduwn System LCO I s applicablo i n WE$ 1 and 2.

This i s requirvd SO that tho plant can be placed and maintained i n MOOE 3 for an extended period o f time fras a locatton oth8r than tho control room, This LCO i s not applicablo i n m S

3, 4, and 5.

In these WE$, th8 plant i s already sukritlcal and i n a condition of reducod Reactor Coolant System enorgy, Under thaso conditlonr, conridrrablo tlw i s avollable t o rootore necossary instrmont control Functions if control rooa instruaents or control beams unrvrilrblr.

Consequrntly, tho TS doas not require OPERABXLIPI I n MIDIES 3, 4, and S.

Times, s p ~ i f i o t that once r Conditfon has been entermi, subsequent divislons, subsystems, colpononts, or variables expressed i n thr Condltlon, discowred to k inoperable o r not withln liritt, w f l l not m t u l t i n soparato entry into the Condition.

kttion 1.3 also sprciflrs that Required Actions o f th8 Condltlon contlnw to apply f o r each additional failure, with Colplotion Tlwrs basad on I n l t i s l entry into th8 Conditlon.

tbuevir, the Required Actions for inoporab~8 R m t o Shutdom System Functlons provldo appropriate c#pmtatory matures for scprrato Functions.

As such, a Noto has boan provided that allows soparato Condltlon ontry for each Inoporablr Remto Shutdown System Funct 1 on.

Ll Condition A addresses the situation where one or more requlred Functlonr o f the Rmtr Shutdaun System i s inoperable.

Thls Includes the control and transfer switches f o r any required Function.

lcont i nuad ),

GRANO GULF 8 3.3-64 Revision No.-

to Page 9 of 22 GNRO-2007/00009 RCS Leakage Detection Instrumentation B 3.4.7 BASES APPLICABLE SAFETY ANALYSES (continued)

RCS leakage detection instrumentation s a t i s f i e s C r i t e r i o n 1 o f the NRC P o l i c y Statement.

~

LCO The drywell f l o o r d r a i n sump monitoring system i s required t o quantify the u n i d e n t i f i e d LEAKAGE from the RCS.

Thus, for the system t o be considered OPERABLE, t h e sump l e v e l monitoring p o r t i o n o f the system must be OPERABLE.

The other monitoring systems provide q u a l i t a t i v e i n d i c a t i o n t o t h e operators so closer examination o f other detectlon systems w i l l be made t o determine the extent o f any corrective action t h a t may be required.

detection systems inoperable, monitoring f o r LEAKAGE i n the RCPB i s degraded.

With the leakage APPLICABILITY I n MODES 1, 2, and 3, leakage detection systems are required t o be OPERABLE t o support LCO 3.4.5.

consistent w i t h t h a t f o r LCO 3.4.5.

This A p p l i c a b i l i t y i s Wlth the drywell f l o o r d r a i n sump monitoring system inoperable, no other form of sampling can provide the equivalent information t o quantify leakage.

However, the drywell atmospheric a c t i v i t y monitor and the drywell a i r cooler condensate f l o w r a t e monitor w i l l provide i n d i c a t i o n s o f changes i n leakage.

With the drywell floor d r a i n sump monitoring system inoperable, b u t w i t h RCS u n i d e n t i f i e d and t o t a l LEAKAGE being determined every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (SR 3.4.5.1). operation may continue f o r 30 days.

Manual methods, using approved M&TE, can be used t o monitor sump fill times and leakage and change i n leakage during the 30 day allowed outage time f o r (continued)

GRAND GULF B 3.4-34 LDC B1.B6f---

to Page 10 of 22 GNRO-2007/00009 RCS Specific Activity B 3.4.8 BASES ACT IONS A. l and A.2 (continued)

If the DOSE EQUIVALENT 1-131 cannot be restored to s 0.2 pCi/gm w i t h i n 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, or i f a t any time i t i s > 4.0 pCi/gm, i t must be determined a t least every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> and all the main steam lines must be isolated within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Isolating the main steam lines precludes the possibility of re1 easi ng radi oacti ve materi a1 t o the envi ronment in an amount t h a t i s more t h a n a small fraction o f the requirements o f 10 CFR 50.67 during a postulated MSLB accident.

Alternately, the plant can be brought to MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and t o MODE 4 w i t h i n 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

provided for those instances when isolation of main steam lines i s not desired (e.g., due t o the decay h e a t loads).

I n MODE 4, the requirements of the LCO are no longer applicable.

The Completion Time of once every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> i s based on the time needed to take and analyze a sample.

The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Completion Time i s reasonable, based on operating experience, t o isolate the main steam lines i n a n orderly manner and without challenging plant systems.

Also, the allowed Completion Times for Required Actions 8.2.2.1 and 8.2.2.2 for bringing the p l a n t t o MODES 3 and 4 are reasonable, based on operating experience, t o reach t h e required plant conditions from full power conditions i n a n orderly manner and w i t h o u t challenging plant systems.

This option i s (continued) -

GRAND GULF B 3.4-40 I

to Page 11 of 22 G N RO-2007/00009 RHR Shutdown Cooling System-Hot Shutdown B 3.4.9 BASES APPLICABILITY shutdown c o o l i n g mode t o remove decay heat t o reduce or pump i s r e q u i r e d t o be i n operation.

The requirements f o r decay heat removal i n MODES 4 and 5 are discussed i n LCO 3.4.10, "Residual Heat Removal (RHR)

Shutdown Cooling System-Cold Shutdown";

LCO 3.9.8, "Residual Heat Removal (RHR) -High Water Level"; and LCO 3.9.9, "Residual Heat Removal (RHR)-Low Water Level."

(continued) m a i n t a i n c o o l a n t temperature.

Otherwise, a r e c i r c u l a t i o n

~~~~

~

ACTIONS A d N

o t

e has been provided t o modify t h e ACTIONS r e l a t e d t o RHR shutdown c o o l i n g subsystems.

Section 1.3, Completion Times, s p e c i f i e s once a C o n d i t i o n has been entered. subsequent d i v i s i o n s, subsystems, components o r v a r i a b l e s expressed i n t h e Condition, discovered t o be i n o p e r a b l e o r n o t w i t h i n l i m i t s, w i l l n o t r e s u l t i n separate e n t r y i n t o t h e Condition.

Section 1.3 a l s o s p e c i f i e s Required Actions o f the C o n d i t i o n continue t o apply f o r each a d d i t i o n a l f a i l u r e, w i t h Completion Times based on i n i t i a l e n t r y i n t o t h e Condition.

However, t h e Required Actions f o r i n o p e r a b l e shutdown c o o l i n g subsystems p r o v i d e appropriate compensatory measures f o r separate inoperable shutdown c o o l i n g subsystems.

As such, a Note has been provided t h a t a l l o w s separate Condition e n t r y f o r each inoperable RHR shutdown c o o l i n g subsystem.

A.1.

A.2.

and A.3 With one r e q u i r e d RHR shutdown c o o l i n g subsystem inoperable f o r decay heat removal, except as p e r m i t t e d by LCO Note 2, t h e inoperable subsystem must be r e s t o r e d t o OPERABLE s t a t u s w i t h o u t delay.

I n t h i s c o n d i t i o n. t h e remaining OPERABLE subsystem can p r o v i d e the necessary decay heat removal.

The (continued 1 GRAND GULF B 3.4-44 Revision No. 4-to Page 12 of 22 GNRO-2007/00009 ECCS-Operat i ng B 3.5.1 BASES (continued)

If any one low pressure ECCS injection/spray subsystem is inoperable, the inoperable subsystem must be restored to OPERABLE status within 7 days. In this Condition, the remaining OPERABLE subsystems provide adequate core cool ing during a LOCA. However, overall ECCS reliability i s reduced because a single failure in one of the remaining OPERABLE subsystems concurrent with a LOCA may result in the ECCS not being able to perfom its intended safety function. The 7 day Completion Time i s based on a reliability study (Ref. 12) that evaluated the impact on ECCS availability by assuming that various components and subsystems were taken out of service. The results were used to calculate the average availability of ECCS equipment needed to mitigate the consequences of a LOCA as a function o f allowed outage times (i.e., Completion Times).

8.1 and 8.Z If the HPCS System i s inoperable, and the RCIC System is verified to be OPERABLE (when RCIC is required to be OPERABLE), the HPCS System must be restored to OPERABLE status within 14 days. In this Condition, adequate core cooling i s ensured by the OPERABILITY o f the redundant and diverse low pressure ECCS injection/spray subsystems in conjunction wjth the ADS. Also, the RCIC System will automatically provide makeup water at most reactor operating pressures. Verification of RCIC OPERABILITY within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is therefore required when HPCS i s inoperable and RCIC is required to be OPERABLE. This may be performed by an administrative check, by examining logs or other information, to determine if RCIC is out o f service for maintenance or other reasons. It is not necessary to perform the Surveillances needed to demonstrate the OPERABILITY o f the RCIC System. However, if the OPERABILITY of the RCIC System cannot be verified and RCIC i s required to be OPERABLE, Condition D must be imdiately entered. If a single active component fails concurrent with a design basis LOCA, there i s a potential, depending on the specific failure, that the minimum required ECCS equipment will not be available. A 14 day Completion Time i s based on the results o f a reliability study (Ref. 12) and has been found to be acceptable through operating experience.

B 3.5-6 Revision No. 8 GRAND GULF to Page 13 of 22 GNRO-2007/00009 RCIC System B 3.5.3 BASES BACKGROUND The RCIC pump i s provided with a minimum flow bypass line, which discharges to the suppression pool. The valve in this line automatically opens to prevent pump damage due to overheating when other discharge line valves are closed. To ensure rapid delivery of water to the RPV and to minimize water hamer effects, the RCIC System discharge llne "keep fill" system is designed to maintain the pump discharge line filled with water.

(continued)

APPLICABLE SAFETY ANALYSES The function of the RCIC System is to respond to transient events by providing makeup coolant to the reactor. The RCIC System is not an Engineered Safety Feature System and no credit is taken in the safety analyses for RClC System operation. Based on its contribution to the reduction of overall plant risk, however, the system is included in the Technical Specifications as required by the NRC Policy Stat emen t.

LCO The OPERABILITY of the RCIC System provides adequate core cooling such that actuation o f any o f the ECCS subsystems i s not required in the event of RPV isolation accompanied by a loss o f feedwater flow.

The RCIC System has sufficient capacity to maintain RPV inventory during an isolation event.

t i APPLICABILITY The RCIC System i s required to be OPERABLE in MODE 1, and MODES 2 and 3 with reactor steam dome pressure > 150 psig since RCIC i s the primary non-ECCS water source for 'core cooling when the reactor is Isolated and pressurized.

In MOOES 2 and 3 with reactor steam dome pressure 5 150 psig, and in HODES 4 and 5, RCIC is not required t o be OPERABLE since the ECCS injection/spray subsystems can provide sufficient flow to the vessel.

ACTIOEIS

/%.I and A.Z If the RCIC System is inoperable during MODE 1, or MODES 2 HPCS System is verified to be OPERABLE, the RCIC System must be restored to OPERABLE status within 14 days.

Condition, loss of the RCIC System will not affect the overall plant capability to provide makeup inventory at high (cont i nuedl or 3 with reactor steam dome pressure > 150 psig, and the In this GRAND GULF B 3.5-22 Revision NO.^

to Page 14 of 22 GNRO-2007/00009 Primary Containment and Orywell Hydrogen Ignt ters B 3.6.3.2 BASES (continued)

APPLICABILITY In MODES 1 and 2, the hydrogen igniter is required to control hydrogen concentration to near the fl anmabil ity limit of 4.0 v/o following a degraded core event that would generate hydrogen i n amounts equivalent to a metal water reaction o f 75% o f the core cladding. The control of hydrogen concentration prevents overpressurization of the primary containment. The event that could generate hydrogen in quantities sufficiently high enough to exceed the flamability limit is limited to MODES 1 and 2.

In MODE 3, both the hydrogen production rate and the total hydrogen produced after a degraded core accident would be less than that calculated for the DBA L O U.

Also, because of the limited t i w in this WE, the probability o f an accident requiring the hydrogen igniter is low, Therefore, the hydrogen igniter is not requlred in HODE 3.

In W E S 4 and 5, the probability and consequences of a degraded core accident are reduced due to the pressure and temperature 1 imitations. Therefore, the hydrogen igniters are not required to be OPERABLE in W E S 4 and 5 to control hydrogen.

ACTIONS A. 1 With one hydrogen igniter division inoperable, the inoperable division must be restored to OPERABLE status within 30 days. In this Conditfon, the remaining OPERABLE hydrogen igniter division is adequate to perform the hydrogen burn function. However, the overall reliability i s reduced because a single failure in the OPERABLE subsystem could result i n reduced hydrogen control capabil ity. The 30 day Completion Time is based on the low probability o f the occurrence o f a degraded core event that would generate hydrogen in amounts equivalent to a metal water reaction of 75% of the core cladding, the amount o f time available after the event for operator action to prevent hydrogen accufaulation from exceeding the flamsability limit, and the low probability of failure of the OPERABLE hydrogen igniter GRAND GULF B 3.6-74 Revision N 0

T to Page 15 of 22 GNRO-2007/00009 Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2 BASES ACTIONS B.l and B.2 With two primary containwent and drywell igniter divisions inoperable, the ability to perform the hydrogen control function via alternate capabilities must be verified by administrative means within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. The alternate hydrogen control capabilities are provided by one hydrogen reconrbiner and one drywell purge subsystem. The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time allows a reasonable period of time to verify that a loss of hydrogen control function does not exist. The verification may be performed as an administrative check by examining logs or other information to determine the availability of the a1 ternate hydrogen control capabi 1 it i es.

It does not mean to perform the Surveillances needed to demonstrate OPERABILITY of the a1 ternate hydrogen control capabilities.

If the ability to perform the hydrogen control function i s maintained, continued operation i s permitted with two igniter divisions inoperable for up to 7 days. Seven days is a reasonable time to allow two igniter divisions to be inoperable because the hydrogen control function i s maintained and because of the lw probability of tho occurrence of a LOCA that would generate hydrogen in the a u n t s capable of exceeding the flamability limit.

c.1 If any Required Action and required Completion Time cannot be met, the plant must be brought to a HODE in which the K O does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The allowed Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable, based on operating experience, to reach #ODE 3 from full power conditions in an orderly manner and without challenging pl ant systems.

(continued)

Revision No. -

GRAND GULF 8 3.6-75 to Page 16 of 22 GNRO-2007/00009 Drywell Purge System B 3.6.3.3 BASES APPLICABILITY (continued)

In HQDE 3, both the hydrogen production rate and the total hydro en produced after a LOCA would be less than that time in this WOE, the probability of an accident requiring the Drywell Purge System is low. Therefore, the Drywell Purge System is not required in W D E 3.

In HODES 4 and 5, the probability and consequences of a LOCA are reduced due to the pressure and temperature limltations in these MOOES. Therefore, the Drywell Purge System is not required in these MOOES.

calcu 3 ated for the DBA L O U.

Also, because o f the limited ACTIONS

&1 With one drywell purge subsystem inoperable, the inoperable subsystea must be restored to OPERABLE status within 30 days. In this condition, the m i n i n g OPERABLE subsystem is adequate to perforu the hydrogen mixing function. However, the overall reliability is reduced because a single failure in the OPERABLE subsystem could result in reduced hydrogen mixing capability. The 30 day Completion Time is based on the low probability of failure of the OPERABLE D r p l l Purge System. The low probability of a LOCA that would generate hydrogen in amounts capable of exceeding the flarslsability limit, and the amount of time available after the event for operator action to prevent B.l and 8.2 With two drywell purge subsystems inoperable, the ability to perform the hydrogen control function via alternate capabilities must be verified by administrative means nlthin 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. The alternate hydrogen control capabilities are (continued 1 GRAND GULF B 3.6-80 Revision No. 8--

to Page 17 of 22 GNRO-2007/00009 AC Sources-Operat i ng B 3.8.1 BASES (continued)

ACTIONS To ensure a highly reliable power source remains, it is necessary to verify the availability of the remaining required offsite circuits on a more frequent basis. Since the Required Action only specifies "perform," a failure of SR 3.8.1.1 acceptance criteria does not result in the Required Action not met. However, if a second required circuit fails SR 3.8.1.1, the second offsite circuit i s inoperable, and Condition C, for two offsite circuits inoperable, is entered.

A.2 According to Regulatory Guide 1.93 (Ref. 6), operation may continue in Condition A for a period that should not exceed 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

This Completion Time assumes sufficient offsite power remains to power the minimum loads needed to respond to analyzed events. In the event more than one division i s without offsite power, this assumption is not met.

Therefore, the optional Completion Time is specifled.

Should two (or more) divisions be affected, the 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Completion Time i s conservatlve with respect to the Regulatory Guide assumptions supportfng a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Completion Tlme for both offsite circuits inoperable. With one offsite circuit inoperable, the reliability of the offsite system i s degraded, and the potential for a loss of offsite p e e r is increased, with attendant potential for a challenge to the plant safety systems.

remaining OPERABLE offsite circuit and DGs are adequate to supply electrical power to the onsite Class 1E distribution system.

The Completion Time takes into account the capacity and capability of the remaining AC sources, reasonable time for repairs, and the low probability of a DBA occurring during this period.

The thlrd Completion Time for Required Action A.2 establishes a limit on the maximum time allowed for any combination o f required AC power sources to be inoperable during any single contiguous occurrence of failing to meet I

In this Conditlon, however, the (continued)

GRAND GULF B 3.8-5 Revision No.-

to Page 18 of 22 GNRO-2007/00009 INSERT 1B (LCO 3.0.4 BASES)

LCO 3.0.4 establishes limitations on changes in MODES or other specified conditions in the Applicability when an LCO is not met. It allows placing the unit in a MODE or other specified condition stated in that Applicability (e.g., the Applicability desired to be entered) when unit conditions are such that the requirements of the LCO would not be met, in accordance with LCO 3.0.4.a, LCO 3.0.4.b, or LCO 3.0.4.c.

LCO 3.0.4.a allows entry into a MODE or other specified condition in the Applicability with the LCO not met when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time.

Compliance with Required Actions that permit continued operation of the unit for an unlimited period of time in a MODE or other specified condition provides an acceptable level of safkty for continued operation. This is without regard to the status of the unit befbre or after the MODE change. Therefbre, in such cases, entry into a MODE or other specified condition in the Applicability may be made in accordance with the provisions of the Required Actions.

LCO 3.0.4.b allows entry into a MODE or other specified condition in the Applicability with the LCO not met aRer performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate.

The risk assessment may use quantitative, qualitative, or blended approaches, and the risk assessment will be conducted using the plant program, procedures, and criteria in place to implement 10 CFR 50.65(a)(4), which requires that risk impacts of maintenance activities to be assessed and managed. The risk assessment, for the purposes of LCO 3.0.4 (b), must take into account all inoperable Technical Specification equipment regardless of whether the equipment is included in the normal 10 CFR 50.65(a)(4) risk assessment scope. The risk assessments will be conducted using the procedures and guidance endorsed by Regulatory Guide 1.182, Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants. Regulatory Guide 1.182 endorses the guidance in Section I 1 of NUMARC 93-01, Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants. These documents address general guidance fix conduct of the risk assessment, quantitative and qualitative guidelines for establishing risk management actions, and example risk management actions.

These include actions to plan and conduct other activities in a manner that controls overall risk, increased risk awareness by shift and management personnel, actions to reduce the duration of the condition, actions to minimize the magnitude of risk increases (establishment of backup success paths or compensatory measures), and determination that the proposed MODE change is acceptable. Consideration should also be given to the probability of completing restoration such that the requirements of the LCO would be met prior to the expiration of ACTIONS Completion Times that would require exiting the Applicability.

LCO 3.0.4.b may be used with single, or multiple systems and components unavailable. NUMARC 93-01 provides guidance relative to consideration of simultaneous unavailability of multiple systems and components.

to Page 19 of 22 GNRO-2007/00009 The results of the risk assessment shall be considered in determining the acceptability of entering the MODE or other specified condition in the Applicability, and any corresponding risk management actions. The LCO 3.0.4.b risk assessments do not have to be documented.

The Technical Specifications allow continued operation with equipment unavailable in MODE 1 for the duration of the Completion Time. Since this is allowable, and since in general the risk impact in that particular MODE bounds the risk of transitioning into and through the applicable MODES or other specified conditions in the Applicability of the LCO, the use of the LCO 3.0.4.b allowance should be generally acceptable, as long as the risk is assessed and managed as stated above. However, there is a small subset of systems and components that have been determined to be more important to risk and use of the LCO 3.0.4.b allowance is prohibited.

The LCOs governing these system and components contam Notes prohi3iting the use of LCO 3.0.4.b by stating that LCO 3.0.4.b is not applicable.

LCO 3.0.4.c allows entry into a MODE or other specified condition in the Applicability with the LCO not met based on a Note m the Specification which states LCO 3.0.4.c is applicable.

These specific allowances permit entry into MODES or other specified conditions in the Applicability when the associated ACTIONS to be entered do not provide for continued operation for an unlimited period of time and a risk assessment has not been performed. This allowance may apply to all the ACTIONS or to a specific Required Action of a Specification.

The risk assessments performed to just@ the use of LCO 3.0.4.b usually only consider systems and components. For this reason, LCO 3.0.4.c is typically applied to Specifications which describe values and parameters (e.g., RCS Specific Activity), and may be applied to other Specifications based on NRC plant-specific approval.

The provisions of this Specification should not be interpreted as endorsing the M u e to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or other specified condition in the Applicability.

The provisions of LCO 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In addition, the provisions of LCO 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that result from any unit shutdown. In this context, a unit shutdown is defined as a change in MODE or other specil5ed condition in the Applicability associated with transitioning fiom MODE 1 to MODE 2, MODE 2 to MODE 3, and MODE 3 to MODE 4.

Upon entry into a MODE or other specified condition in the Applicability with the LCO not met, LCO 3.0.1 and LCO 3.0.2 require entry into the applicable Conditions and Required Actions until the Condition is resolved, until the LCO is met, or until the unit is not within the Applicability of the Technical Specification.

Surveillances do not have to be performed on the associated inoperable equipment (or on variables outside the specified limits), as permitted by SR 3.0.1. Therefore, utilizing LCO 3.0.4 is not a violation of SR 3.0.1 or SR 3.0.4 for any Surveillances that have not been performed on to Page 20 of 22 GNRO-2007/00009 inoperable equipment. However, SRs must be met to ensure OPERABILITY prior to declaring the associated equipment OPERABLE (or variable within limits) and restoring compliance with the affected LCO.

INSERT 2B (SR 3.0.4 BASES)

SR 3.0.4 establishes the requirement that all applicable SRs must be met befbre entry into a MODE or other specified condition in the Applicability.

This Specification ensures that system and component OPERABILITY requirements and variable limits are met before entry into MODES or other specified conditions in the Applicability for which these systems and components ensure safe operation of the unit. The provisions of this Specification should not be interpreted as endorsing the fhilure to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or other specified condition in the Applicability.

A provision is included to allow entry into a MODE or other specified condition in the Applicability when an LCO is not met due to Surveillance not being met in accordance with LCO 3.0.4.

However, in certain circumstances, failing to meet an SR will not result in SR 3.0.4 restricting a MODE change or other specified condition change. When a system, subsystem, division, component, device, or variable is inoperable or outside its specified limits, the associated SR(s) are not required to be performed, per SR 3.0.1, which states that surveillances do not have to be performed on inoperable equipment. When equipment is inoperable, SR 3.0.4 does not apply to the associated SR(s) since the requirement for the SR(s) to be performed is removed Therefbre, &dug to perform the Surveillance(s) within the specified Frequency does not result in an SR 3.0.4 restriction to changing MODES or other specified conditions of the Applicability.

However, since the LCO is not met in this instance, LCO 3.0.4 will govern any restrictions that may (or may not) apply to MODE or other specified condition changes. SR 3.0.4 does not restrict changing MODES or other specified conditions of the Applicability when a Surveillance has not been performed within the specified Frequency, provided the requirement to declare the LCO not met has been delayed in accordance with SR 3.0.3.

The provisions of SR 3.0.4 shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In addition, the provisions of SR 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that result &om any unit shutdown In this context, a unit shutdown is defined as a change in MODE or other specified condition in the Applicability associated with transitioning fiom MODE 1 to MODE 2, MODE 2 to MODE 3, and MODE 3 to MODE 4.

The precise requirements for performance of SRs are specified such that exceptions to SR 3.0.4 are not necessary. The specific time frames and conditions necessary for meeting the SRs are specified in the Frequency, in the Surveillance, or both. This allows performance of to Page 21 of 22 GNRO-2007/00009 Surveillances when the prerequisite condition(s) specified in a Surveillance procedure require entry into the MODE or other specified condition in the Applicability of the associated LCO prior to the performance or completion of a Surveillance. A Surveillance that could not be performed until after entering the LCO's Applicability, would have its Frequency specified such that it is not "due" until the specific conditions needed are met. Alternately, the Surveillance may be stated in the form of a Note, as not required (to be met or performed) until a particular event, condition, or time has been reached Further discussion of the specific formats of SRs' annotation is found in Section 1.4, Frequency.

to Page 22 of 22 GNRO-2007/00009 INSERT 3B (RCS SPECIFIC ACTIVITY BASES)

A Note permits the use of the provisions of LCO 3.0.4.c. This allowance permits entry into the applicable MODE(S) while relying on the ACTIONS.

INSERT 4B (LCO 3.5.1, ECCS - OPERATING)

A Note prohibits the application of LCO 3.0.4.b to an inoperable HPCS subsystem. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable HPCS subsystem and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after perfbrmance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

INSERT 5B (LCO 3.5.3, RCIC SYSTEM)

A Note prohibits the application of LCO 3.0.4.b to an inoperable RCIC system There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable RCIC system and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after perfbrmance of a risk assessment addressing inoperable systems and Components, should not be applied in this circumstance.

INSERT 6B (LCO 3.8.1, AC SOURCES - OPERATING)

A Note prohibits the application of LCO 3.0.4.b to an inoperable DG. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable DG and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance

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