ML12354A415

Revision to the Reply to Notices of Violation Regarding Unapproved III.G.2 Operator Manual Actions

ML12354A415
Person / Time
Site:	Indian Point
Issue date:	12/07/2012
From:	Ventosa J Entergy Nuclear Northeast
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NL-12-179
Download: ML12354A415 (21)

Text

Enter-ay Nuclear Northeast Indian Point Energy Center 450 Broadway, GSB Ei P.O. Box 249 Buchanan, NY 10511-0249 Tel 914 254 6700 John A. Ventosa Site Vice President Administration NL-12-179 December 7, 2012 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001

Subject:

Revision to the Reply to Notices of Violation Regarding Unapproved III.G.2 Operator Manual Actions Indian Point Nuclear Generating Unit Nos. 2 & 3 Docket Nos. 50-247, 50-286 License Nos. DPR-26, DPR-64

References:

1. Entergy letter dated NL-12-122 dated September 17, 2012, "Reply to Notices of Violation Regarding Unapproved III.G.2 Operator Manual Actions"

2. NRC letter dated August 16, 2012, "Indian Point Nuclear Generating Units 2 and 3 - NRC Inspection Report 05000247/2012009 and 05000286/2012008 and Notices of Violation"

3. NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 2 - Exemption from the Requirements of 10 CFR Part 50, Appendix R, Paragraph III.G.2 (TAC No. ME0798)"

4. NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 3 - Exemption from the Requirements of 10 CFR Part 50, Appendix R, Paragraph III.G.2 (TAC No. ME0799)"

Dear Sir or Madam:

By letter dated September 17, 2012 (Reference 1), Entergy Nuclear Operations, Inc.

(Entergy) replied to the violations issued in Reference 2 for Indian Point Nuclear Generating Unit No. 2 (IP2) and Unit No. 3 (IP3) for the use of unapproved operator manual actions (OMAs) to mitigate safe shutdown equipment malfunctions caused by a fire-induced single spurious actuation in lieu of protecting the equipment in accordance with 10 CFR Part 50 Appendix R, Paragraph III.G.2. The violations resulted from the denial of a number of OMAs in the Exemptions transmitted by letters dated February 1, 2012 (References 3 and 4).

NL-12-179 Docket Nos. 50-247 & 50-286 Page 2of 4 Entergy committed in Reference 1 to inform the NRC of any changes in resolution concept and/or completion schedule that may be determined to be necessary as an outcome of the ongoing engineering analysis and evaluation process. Attachments 1, 2 and 3 in Reference 1 have been updated (identified with revision bars) to reflect schedule changes and to indicate completion of a number of OMA resolutions as follows:

For IP2 (Attachment 2), the "Scheduled Completion Date" for OMA 5 in Fire Area F, Fire Zones 27A, 33A, and 59A has been changed from "Q3 2012" to "Spring 2014 RFO". The Planned Resolution for this OMA was to revise the Appendix R safe-shutdown analysis and methodology to credit equipment train independent of the fire area/zone, thereby eliminating this OMA. Although the resolution was completed according to the original Scheduled Completion Date of "Q3 2012,"

the evaluation determined that the ability to eliminate this OMA is linked to planned Charging system modifications associated with OMAs 6, 20, and 21, which have a previously communicated Scheduled Completion Date of "Spring 2014 RFO." This schedule change to OMA 5 was communicated via telecom to NRC Region I on September 28, 2012.

• For IP2 (Attachment 2), the "Scheduled Completion Date" for OMAs 8 and 11 in all applicable Fire Areas/Fire Zones have been changed from "Q3 2012" to "Completed" - "Corrective Steps Taken and Results Achieved" in Attachment 1 has also been revised with this information based on the third quarter 2012 completion of the planned resolution.

• For IP3 (Attachment 3), the "Scheduled Completion Date" for OMAs 13, 25 and 27 in all applicable Fire Areas/Fire Zones have been changed from "Q4 2012" to "Completed" - "Corrective Steps Taken and Results Achieved" in Attachment 1 has also been revised with this information based on the fourth quarter 2012 completion of the planned resolution.

As noted in Reference 1, given the substantial technical challenge imposed by the OMA resolution effort, and recognizing that the requisite engineering evaluations are in progress at this time, the presently conceptualized solutions may change, in that the scope of analyses and/or the nature and scope of plant physical modifications may require revision as the OMA resolutions are finalized. The target completion dates shown in the attachments represent Entergy's current informed projection, and any change in resolution concept and/or completion schedule that may be determined to be necessary as an outcome of the engineering analysis and evaluation process will be communicated to NRC per the commitment in Reference 1.

In a related matter, per Enforcement Guidance Memorandum (EGM) 09-002 (Enforcement Discretion for Fire Induced Circuit Faults) dated May 14, 2009, the

NL-12-179 Docket Nos. 50-247 & 50-286 Page 3 of 4 resolution of the multiple spurious operations (MSOs) topic was to be completed by November 2, 201-2. In dispositioning each of the PWR generic MSO scenarios identified by NEI 00-01, Rev. 2, Entergy identified that several of the MSO scenarios would be effectively resolved through implementation of planned modifications to resolve OMA concerns for these same issues. Those modifications require, in part, refueling outages to implement, and it was infeasible to develop detailed designs and implement the required OMA modifications in time to credit these modifications for resolution of the related MSO issues by November 2, 2012.

As a result, resolution of several MSO scenarios for IP2 and IP3 remain pending and these are scheduled for resolution through implementation of related OMA modifications during the next scheduled refueling outages. The Scheduled Due Dates for the affected OMAs are "Spring 2014 RFO" for IP2 and "Q2 2013" for IP3 (Spring 2013 RFO).

Additionally, three IP2 MSO scenarios that credit resolution via a modification being implemented to eliminate several IP2 OMAs will be resolved during the fourth quarter of 2012 with the completion of the ongoing modification. Pending completion of the necessary modifications to resolve the remaining OMA and MSO scenarios, compensatory actions consisting of hourly fire watch tours remain in place for all affected plant areas. Note that the condition report tracking resolution of the MSO issue is CR-IP2-2012-06004.

The IP2 and IP3 OMAs that will be resolved by plant modifications as described above, and the related MSO scenarios that credit the OMA modifications for their disposition, are as follows with the indicated Scheduled Completion Dates:

IP2 OMA 6: related MSO scenarios 1,4, 5, 9, 10, 12 Spring 2014 RFO IP2 OMAs 14, 15,19: related MSO scenarios 28, 31, 33 Q4 2012 IP2 0MAs 20, 21: related MSO scenarios 1, 4,,5, 21 Spring 2014 RFO IP3 OMA 10: related MSO scenarios 1, 4, 5, 9, 10, 12 02 2013

NL-12-179 Docket Nos. 50-247 & 50-286 Page 4 of 4 There are no new commitments contained in this letter. In the event of any questions, please contact Mr. Robert W. Walpole, Manager, Licensing at 914-254-6710.

Sincerely, Ace J0- ý It /ý.xz;m ýv J0--

JAV/gd Attachments:

1. Reply to Notices of Violation Regarding Unapproved III.G. 2 Operator Manual Actions (Revised from Entergy Letter NL-12-122 dated September 17, 2012)

2. Resolution of Indian Point Unit 2 Unapproved III.G.2 OMAs (Revised from Entergy Letter NL-12-122 dated September 17, 2012)

3. Resolution of Indian Point Unit 3 Unapproved III.G.2 OMAs (Revised from Entergy Letter NL-12-122 dated September 17, 2012) cc: Mr. Douglas V. Pickett, Senior Project Manager, NRC NRR DORL U.S. Nuclear Regulatory Commission Document Control Desk NRC Resident Inspectors Mr. Francis J. Murray, Jr., President and CEO, NYSERDA Ms. Bridget Frymire, New York State Department of Public Service

Attachment 1 to NL-12-179 Reply to Notices of Violation Regarding Unapproved III.G.2 Operator Manual Actions (Revised from Entergy Letter NL-12-122 dated September 17, 2012)

ENTERGY NUCLEAR OPERATIONS, INC.

Indian Point Nuc!ear Generating Unit Nos. 2 & 3 Docket Nos. 50-247 & 50-286 License Nos. DPR-26 & DPR-64

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 1 Page 1 of 5 Reply to Notices of Violation Regarding Unapproved III.G.2 Operator Manual Actions As transmitted by letters dated February 1,20121, exemptions from the requirements of 10 CFR 50, Appendix R, Paragraph III.G.2 for the use of operator manual actions (OMAs) were granted in part and denied in part for Indian Point Unit 2 (IP2) and Unit 3 (IP3). As a result, a violation was issued for each unit for the use of OMAs without prior NRC approval. The reply provided herein together with Attachments 2 and 3 to this letter address both violations.

Unit 2 Violation License Condition 2.K specifies, in part, that Entergy Nuclear Operations, Inc., (ENO) shall implement and maintain in effect all provisions of the NRC-approved fire protection program as described in the Updated Final Safety Analysis Report.

The Updated Final Safety Analysis Report, Section 9.6 specifies that ENO will meet the requirements of 10 CFR Part 50, Appendix R, Section III.G.2, which requires, in part, except as provided for in paragraph G.3 of this section, where cables or equipment, including associated non-safety circuits that could prevent operation or cause maloperation due to hot shorts, open circuits, or shorts to ground, of redundant trains of systems necessary to achieve and maintain hot shutdown conditions are located within the same fire area, one of the means of ensuring that one of the redundant trains is free of fire damage shall be provided, per the requirements in G.2.a - G.2.f.

Contrary to the above, between June 30, 2006, and April 26, 2012, ENO failed to implement all provisions of the approved fire protection program. Specifically, the safe shutdown strategy for Indian Point Unit 2 relied upon unapproved operator manual actions to mitigate post-fire safe shutdown equipment malfunctions caused by a single spurious actuation, in lieu of protecting the equipment in accordance with 10 CFR Part 50 Appendix R, Section III.G.2, per the requirements in G.2.a - G.2.f . The specific operator manual actions and fire areas and fire zones that are in violation of Appendix R, Section IlI.G.2 are listed in the Indian Point Unit 2 Denied OMA Summary Table of NRC Inspection Report 05000247/2012009 and 05000286/2012008. The use of manual actions in lieu of providing the required protection requires prior NRC approval.

Unit 3 Violation License Condition 2.H specifies, in part, that Entergy Nuclear Operations, Inc., (ENO) shall implement and maintain in effect all provisions of the approved Fire Protection Program as described in the Final Safety Analysis Report.

NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 2 - Exemption from the Requirements of 10 CFR Part 50, Appendix R, Paragraph III.G.2 (TAC No. ME0798)" and NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 3 - Exemption from the Requirements of 10 CFR Part 50, Appendix R,,Paragraph III.G.2 (TAC No. ME0799)"

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 1 Page 2 of 5 The Final Safety Analysis Report, Section 9.6.2 specifies that ENO will meet the requirements of 10 CFR Part 50, Appendix R, Section IlI.G.2, which requires, in part, except as provided for in paragraph G.3 of this section, Where cables or equipment, including associated non-safety circuits that could prevent operation or cause maloperation due to hot shorts, open circuits, or sho rts to ground, of redundant trains of systems necessary to achieve-and maintain hot shutdown conditions are located within the same fire area, one of the means of ensuring that one of the redundant trains is free of fire damage shall be provided, per the requirements in G.2.a - G.2.f.

Contrary to the above, between June 30, 2006 and April 26, 2012, ENO failed to implement all provisions of the approved fire protection program. Specifically, the safe shutdown strategy for Indian Point Unit 3 relied upon unapproved manual operator actions to mitigate post-fire safe shutdown equipment malfunctions caused by a single spurious actuation, in lieu of protecting the equipment in accordance with 10 CFR Part 50 Appendix R, Section III.G.2, per the requirements in G.2.a - G.2.f . The specific operator manual actions and fire areas and fire zones that are in violation of Appendix R,Section III.G.2 are listed in the Indian Point Unit 3 Denied OMA Summary Table of NRC Inspection Report 05000247/2012009 and 05000286/2012008. The use of manual actions in lieu of providing the required protection requires prior NRC approval.

Reason for the Violations 10 CFR 50, Appendix R, Paragraph III.G.2 requires the following:

Except as provided for in paragraph G.3 of this section, where cables or equipment, including associated non-safety circuits that could prevent operation or cause maloperation due to hot shorts, open- circuits, or shorts to ground, of redundant trains of systems necessary to achieve and maintain hot shutdown conditions are located within the same fire area outside of primary containment, one of the following means of ensuring that one of the redundant trains is free of fire damage shall be provided:

a. Separation of cables and. equipment and associated non-safety circuits of redundant trains by a fire barrier having a 3-hour rating. Structural steel forming a part of or supporting such fire barriers shall be protected to provide fire resistance equivalent to that required of the barrier;

b. Separation of cables and equipment and associated non-safety circuits of

.redundant trains by a horizontal distance of more than 20 feet with no intervening combustible or fire hazards. In addition, fire detectors and an automatic fire suppression system shall be installed in the fire area; or

c. Enclosure of cable and equipment and associated non-safety circuits of one redundant train in a fire barrier having a 1-hour rating, In addition, fire detectors and an automatic fire suppression system shall be installed in the fire area;

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 1 Page 3 of 5 Inside noninerted containments one of the fire protection means specified above or one of the following fire protection means shall be provided:

d. Separation of cables and equipment and associated non-safety circuits of redundant trains by a horizontal distance of more than 20 feet with no intervening combustibles or fire hazards;

e. Installation of fire detectors and an automatic fire suppression system in the fire area; or

f. Separation of cables and equipment and associated non-safety circuits of redundant trains by a noncombustible radiant energy shield.

As discussed in the Exemptions transmitted by the February 1, 2012 NRC letters, the NRC stgff denied a number of the requested exemptions based on the lack of fire protection defense-in-depth, particularly detection or automatic suppression, or lack of adequate time margin available

.to complete the OMA.

Entergy requested exemptions because the criteria of III.G.2 were not met, including the lack of detection and/or automatic fire suppression in many of the areas. The areas lacking detection and/or automatic fire suppression were identified in the various submittals, and it was Entergy's belief that the lack of detection/suppression was acceptable as long as the OMAs were demonstrated to be reliable and feasible. Entergy misjudged the significance that the lack of detection/suppression has on the acceptability of using the unapproved OMAs in lieu of, meeting the requirements of III.G.2.

For those OMAs that were denied due to inadequate time margin to complete the action, it was Entergy's judgment that the time margins available were adequate, which made the OMAs feasible. This is supported by the determination during inspections performed in May 2011 and again in April 2012 by Region I that the OMAs (except for an IP3 OMA involving service water

.strainers) are adequate as interim compensatory actions and are feasible. However, considering the scope or complexity of the actions that had to be performed, it was determined by the NRC staff that the OMAs could not be performed with adequate time margin to be acceptable for compliance with Appendix R.

Entergy understands the positions established by the NRC staff and does not contest the violations. Note that the condition reports tracking the resolution of these issues are CR-IP2-2011-02417 and CR-IP3-2011-02853 for IP2 and IP3, respectively.

Regarding the aspect of the IP2 violation where Entergy failed to identify and request exemptions for two OMAs associated with the operation of 21 Charging Pump (operating the pump from the emergency control station in the 480V Switchgear Room and using the scoop tube in the pump room) that were being relied upon to achieve and maintain safe shutdown in the event of a fire impacting Fire Zone 7A in Fire Area F, the following has been determined:

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 1 Page 4 of 5

• A screening report that identified all the OMAs that required an exemption correctly identified that certain actions associated with 21 Charging Pump would require an exemption, but did not explicitly identify the two OMAs of concern. The input to the engineering report was the IP2 Appendix R Analysis and associated database. The database and document did not correctly record and code the actions for the pump as manual actions. Specifically, non-standard nomenclature was used in the IP2 Appendix R Analysis and multiple protective actions were grouped as a single entry for the pump instead of individually. The use of non-standard nomenclature and presentation method resulted in an error of omission in transcribing OMAs from the screening report to the exemption request submitted in March 2009.

• The personnel responsible for preparing the IP2 Appendix R Analysis database did not exhibit a heightened awareness of the importance of maintaining the convention of the database. The erroneous database entries were obviously different from other entries in the database and should have been questioned before becoming part of the permanent record.

Corrective Steps Taken and Results Achieved Entergy was initially informed of the pending denial of a number of OMAs in May 2011 during the IP3 Triennial Fire Protection inspection. Following receipt of the verbal notification, the following actions were taken for IP2 and IP3:

" Hourly fire watch tours were implemented for all areas in which OMAs were credited, not only for areas in which the denied OMAs were credited. For OMAs in the IP2 Containment, a one hour log of containment average temperature was initiated. These actions will remain in effect for each unapproved OMA until the OMA is resolved.

• In May 2011 during the IP3 Triennial Fire Protection inspection, Region I inspectors assessed the feasibility (including time margins) of the IP2 and IP3 OMAs and determined they were adequate as interim compensatory actions pending final disposition of the exemption requests (except for an IP3 OMA involving service water strainers).

Resolution plans have been established for all of the unapproved OMAs. For IP2, planned resolutions to eliminate the need for the unapproved OMAs are scheduled to be completed as shown in Attachment 2; OMAs 8 and 11 have been resolved per the Planned Resolutions described in Attachment 2, and they are shown as "Completed." For IP3, planned resolutions to eliminate the need for the unapproved OMAs are scheduled to be completed as shown in ; OMAs 2, 3, 4, 5, 6, 7, 8, cad 11, 13, 23, 24, 25 and 27 have been resolved by

-evieien*of the App..dix R safe shutdown analysis and methodology to credit existing scpraation within the firo areoe-az-ne per the Planned Resolutions described in Attachment 3, and they are shown as "Completed" in At.ta-chmont 3.

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 1 Page 5 of 5 Regarding the aspect of the!1P2 violation where Entergy failed to identify and request exemptions for the two OMAs associated with the operation of 21 Charging Pump, the following corrective actions as documented in CR-IP2-2012-03024 have been taken:

• Compensatory measures were verified to be established and adequate to address the OMAs for the operation of the pump, and Operations procedure 2-ONOP-FP-001 (Plant Fires) was revised to include the OMAs.

The feasibility and reliability of the OMAs were validated with*Operations and documented by engineering evaluation.

All of the component protection remarks in the IP2 Appendix R Analysis and the IP3 Appendix R Analysis not coded using conventional nomenclature were reviewed and it was verified that there are no other "unaccounted for" manual actions identified in any of the remarks.

Coaching was provided to applicable engineering staff to reinforce the critical nature of the Safe Shutdown Analysis and continued use of Human Performance tools; coaching was provided to the Programs & Components Engineering department to reinforce the use of Human Performance tools when relying on past reports as a basis for critical decisions.

Corrective Steps That Will be Taken Planned resolutions to eliminate the need for the unapproved OMAs are scheduled to be completed as shown in Attachment 2 for IP2 and in Attachment 3 for IP3. As reflected in these attachments, full compliance with the requirements of Appendix R Paragraph III.G.2will be

,accomplished by Spring 2014 RFO for IP2 and by Q2 2013 for IP3.

Regarding the aspect of the IP2 violation where Entergy failed to identify and request exemptions for two OMAs associated with the operation of 21 Charging Pump, a modification to protect circuits of concern is required (identified in Attachment.2 as OMAs 20 and 21).

Attachment 2' to NL-12-179 Resolution of Indian Point Unit 2 Unapproved III.G.2 OMAs (Revised from Entergy Letter NL-12-122 dated September 17, 2012)

ENTERGY NUCLEAR OPERATIONS, INC.

Indian Point Nuclear Generating Unit Nos. 2 & 3 Docket Nos. 50-247 & 50-286 License Nos. DPR-26 & DPR-64

NL-1 2-179 Docket Nos. 50-247 & 50-286 Attachment 2 Page 1 of 4 F/5A 6 Revise Appendix H sale-shutdown analysis and methodology to Spring 2014 credit equipment train independent of the fire area/zone and RFO implement modification to establish separate fire area OR implement modification to protect circuits of concern, thereby eliminatinq this OMA FI7A 6 Implement modification to protect circuits of concern, thereby Spring 2014 eliminating this OMA RFO 7 As described for OMA 7, Fire Area F, Fire Zone 6 Q4 2012 20 Implement modification to protect circuits of concern, thereby Spring 2014 eliminating this OMA (see Note on page 4) RFO 21 Implement modification to protect circuits of concern, thereby Spring 2014 eliminating this OMA (see Note on page 4) RFO 5 Revise Appendix R safe-shutdown analysis and methodology to Spring 2014 credit equipment train independent of the fire area/zone, thereby RFO Q302012 I F/27A eliminating this OMA i+

6 As described for OMA 6, Fire Area F, Fire Zone 7A Spring 2014 RFO I F/59A 5 As described for OMA 5, Fire Area F, Fire Zone 27A Spring 2014 I I RFO Q3 2012 I H/75A 8 Revise Appendix R safe-shutdown analysis and methodology to Q3 20!2 credit a train of equipment free of fire damage in the fire area/zone, Completed thereby eliminating this OMA As identified in table on pages 5 and 6 in Exemption transmitted by NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 2 - Exemption from the Requirements of 10 CFR Part 50, Appendix R, Paragraph III.G.2 (TAC No. ME0798)", with the exception of OMAs 19, 20 and 21 - see Note on page 4

NL-1 2-179 Docket Nos. 50-247 & 50-286 Attachment 2 Page 2 of 4 9,10 Implement modification to protect circuits of concern, thereby Spring 2014 eliminating these OMAs RFO H/77A 8 As described for OMA 8, Fire Area H, Fire Zone 72A 0~22012 Completed 9,10 As described for OMAs 9,10, Fire Area H, Fire Zone 75A Spring 2014 RFO IIH/85A 8 As described for OMA 8, Fire Area H, Fire Zone 72A 3ot 2042 I 11 Reassess electrical circuit and power supply loading analyses and 1 J/1 9 revise Appendix R safe-shutdown analysis and methodology to provide the basis for elimination of this OMA Completed I

1 J/39A I

11 12 As described for OMA 11, Fire Area J, Fire Zone 19 I As described for OMA 12, Fire Area J, Fire Zone 25 I Completed Q4 2012 II Q3 2We2 CompletedI I

11 J/45A 11 1 As described for OMA 11, Fire Area J, Fire Zone 19

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 2 Page 3 of 4 I J/47A 11 As described for OMA 11, Fire Area J, Fire Zone 19 I Completed Q3 20!2 I1 J/270 12 As described for OMA 12, Fire Area J, Fire Zone 25 Q4 2012 I-I I K/60A 14 Implement modification to protect circuits of concern, thereby Q4 2012 eliminating this OMA 15 Implement modification to protect circuits of concern, thereby 1 Q4 2012 eliminating this OMA _

19 Implement modification to protect circuits of concern, thereby Q4 2012 eliminating this OMA (see Note on page 4)

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 2 Page 4 of 4 Description of Unit 2 Unapproved OMAs

5. Open HCV-142 bypass valve 227 to align charging pump makeup path to the Reactor

-Coolant System (RCS) 6, Align charging pump suction source to the Refueling Water Storage Tank (RWST)

7. Transfer instrument buses 23 and 23A to alternate power

8. Fail open valves 204A (charging flow to Loop 2 hot leg) and 204B (charging flow to Loop 1 cold leg) to align charging pump makeup path to the RCS 9, Activate or enable Alternate Safe Shutdown System pneumatic instruments (steam generator level, pressurizer pressure and level) at Fan House local control panel

10. Enable Alternate Safe-Shutdown System source-range channel and Loop 21 and 22 hot leg (Th) and cold leg (T,) temperature channels

11. Trip breakers 52/5A and 52-SAC on Bus 5A and 52/6A and 52/TAO at Bus 6A and remove control power fuses

12. Transfer Instrument Buses 23 and 23A toemergency power source

13. Align charging pump suction to RWST

14. Operate transfer switch EDC5 and close supply breaker at substation 12FD3 to transfer 21 AFW Pump to Alternate Safe Shutdown System power source

15. Open 21 AFW Pump recirculation bypass valve BFD-77

19. Operate 21 AFW Pump flow control valves to control AFW flow to Steam Generators 21 &

22

20. Locally operate 21 Charging Pump scoop tube positioner

21. Locally start 21 Charging Pump using the emergency control station located in the 480V Switchgear Room NOTE: With the exception of OMAs 19, 20 and 21, the descriptions are copied from the table on pages 5 and 6 in Exemption transmitted by NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 2 - Exemption from the Requirements of 10 CFR Part 50, Appendix R, Paragraph III.G.2 (TAC No.

ME0798)". OMA 19 was not addressed in the Exemption transmitted by that letter.

OMAs 20 and 21 were inadvertently omitted from the exemption request process,

.and are therefore unapproved OMAs. The three OMAs have been given the next sequential numbers.

Attachment 3 to NL-12-179 Resolution of Indian Point Unit 3 Unapproved III.G.2 OMAs (Revised from Entergy Letter NL-12-122 dated September 17, 2012)

ENTERGY NUCLEAR OPERATIONS,. INC.

Indian Point Nuclear Generating Unit Nos. 2 & 3 Docket Nos. 50-247 & 50-286, License Nos. DPR-26 & DPR-64

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 3 Page 1 of 5 ETN-4{1}/ 2 Revise Appendix R safe-shutdown analysis and methodology to Completed 7A credit existing separation within the fire area/zone, thereby eliminating this OMA 3 Revise Appendix R safe-shutdown analysis and methodology to Completed credit existing separation within the fire area/zone, thereby eliminating this OMA 4 Revise Appendix R safe-shutdown analysis and methodology to Completed credit existing separation within the fire area/zone, thereby eliminating this OMA 6 Revise Appendix R safe-shutdown analysis and methodology to Completed credit existing separation within the fire area/zone, thereby eliminating this OMA 7 Revise Appendix R safe-shutdown analysis and methodology to Completed credit existing separation within the fire area/zone, thereby eliminating this OMA 8 Revise Appendix R safe-shutdown analysis and methodology to Completed credit existing separation within the fire area/zone, thereby eliminatinq this OMA As identified in table on pages 5 and 6 in Exemption transmitted by NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 3 - Exemption from the Requirements of 10 CFR Part 50, Appendix R, Paragraph III.G.2 (TAC No. ME0799)"

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 3 Page 2 of 5 ETN-4{1 } / 12 Revise Appendix R safe-shutdown analysis and methodology to 042012 60A credit existing separation within and/or independent of the fire (continued) area/zone, thereby eliminating this OMA 13 Implement power/control circuit modification to ensure post-fire Q4 2012 functionality of the Service Water strainers for III.G.2 fire Completed scenarios. thereby eliminatina this OMA I PAB-2{3} / 6 18 Revise Appendix R safe-shutdown analysis and methodology to Q4 2012 credit equipment train independent of the fire area/zone, thereby I eliminatina this OMA PAB-25 / 1191 As described for OMA 19, Fire Area PAB-2{5), Fire Zone 1o7A I 4 2012 19A 20 As described for OMA 20. Fire Area PAB-2151. Fire Zone 17A Q4 2012 I PAB-2{5}/ 22 As described for OMA 22, Fire Area PAB-2{5}, Fire Zone 17A Q4 2012 1 27A

NL-1 2-179 Docket Nos. 50-247 & 50-286 Attachment 3 Page 3 of 5 I PAB-2{5} / 22 As described for OMA 22, Fire Area PAB-2{5} / 17A Q4 2012 1 30A 25 Implement power/control circuit modification to ensure post-fire 04-2012 ITBL-5 / 37A functionality of the Service Water strainers for III.G.2 fire Completed scenarios, thereby eliminating this OMA 25 As described for OMA 25, Fire Area TBL-5, Fire Zone 37A II TBL-5 /43A Completed TBL-5 / 52A 23 Implement modification to protect affected circuits in this zone, t1 thereby eliminating this OMA Com~pleted 4 -I 24 1 rimplement modification to protect affected circuits in this zone, thereby eliminatinci this OMA Completed I YARD-7 / 22 26 Reevaluate Appendix R safe-shutdown analysis, methodology, 042012 and fire protection licensing basis to validate whether the OMA may be eliminated 27 Implement power/control circuit modification to ensure post-fire 04 2012 functionality of the Service Water strainers for III.G.2 fire Completed scenarios, thereby eliminating this OMA

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 3 Page 4 of 5 Description of Unit 3 Unapproved OMAs

2. Swap 32 Component Cooling Water (CCW) pump to alternate power supply or align city water to charging pumps

3. Operate 480V Bus 3A breaker locally to start 31 AFW Pump

4. Locally operate the bypass valve for Flow Control Valve (FCV)-1 121 in support of use of 31 AFW pump

5. Operate HCV-1 118 manually to control 32 AFW pump

6. Align Appendix R Diesel Generator (ARDG) to 480V Buses 2A, 3A, 5A, and 312

7. Swap 31 or 32 charging pump to alternate power supply

8. Locally operate FCV-405B, FCV-405D, or FCV-406B to control AFW flow to Steam Generators (SGs)

9. Locally open valve 227 to establish charging [previously "CVCS"] makeup flowpath to Reactor Coolant System (RCS)

10. Locally close Level Control Valve (LCV)-1 12C and open valve 288 to align charging pump suction to the Refueling Water Storage Tank (RWST)

11. Locally operate Pressure Control Valve PCV-1 139 to ensure steam supply to 32 AFW Pump

12. Locally operate PCV-1310A and PCV-1310B to ensure steam supply to 32 AFW pump

13. Locally manually perform Service Water (SW) pump strainer backwash as required

14. Operate HCV- 1118 manually to control 32 AFW pump

15. Locally operate PCV-1 139 to ensure steam supply to 32 AFW pump

16. Locally operate 32 PCV-1310A, PCV-1310B to ensure steam supply to 32 AFW pump

17. Locally operate FCV-405C and FCV-405D to control AFW flow to SG

18. Locally close valve LCV-1 12C, and open valve 288 to align charging pump suction path to RWST

NL-12-179 Docket Nos. 50-247 & 50-286 Attachment 3 Page 5 of 5

19. Locally close supply breaker for 32 Charging Pump [previously "CVCS"] Pump

20. Locally control 32 charging [previously "CVCS"] pump using scoop tube positioner

21. Open bypass valve 227 to establish charging flowpath to RCS around potentially failed closed HCV-142

22. Locally close valve LCV-1 12C and open bypass valve 288 to establish flowpath from RWST to charging pump suction

23. Locally operate [bypass valve for] FCV-1 121 AFW pump recirculation valve during pump startup

24. Locally operate FCV-406A and FCV-406B to control AFW flow to SGs

25. Locally/manually backwash SW pump strainer as required if power to strainer associated with selected SW pump is lost (use one of STR PMP-31 through STR PMP-36)

26. Locally start ARDG to supply Motor Control Center (MCC) 312A in support of the use of SW pump 38

27. Locally/manually backwash SW pump strainer as required if power to strainer associated with selected SW pump is lost NOTE: The descriptions are copied from the table on pages 5 and 6 in Exemption transmitted by NRC letter dated February 1, 2012, "Indian Point Nuclear Generating Unit No. 3 - Exemption from the Requirements of 10 CFR Part 50, Appendix R, Paragraph III.G.2 (TAC No. ME0799)