ML16243A245

Integrated Inspection Report 05000247/2016002 and 05000286/2016002, April 1, 2016, Through June 30, 2016

ML16243A245
Person / Time
Site:	Indian Point
Issue date:	08/30/2016
From:	Glenn Dentel Reactor Projects Branch 2
To:	Vitale A Entergy Nuclear Operations
References
IR 2016002
Download: ML16243A245 (54)

See also: IR 05000247/2016002

Text

UNITED STATES

NUCLEAR REGULATORY COMMISSION

REGION I

2100 RENAISSANCE BLVD.

KING OF PRUSSIA, PA 19406-2713

August 30, 2016

Mr. Anthony J. Vitale

Site Vice President

Entergy Nuclear Operations, Inc.

Indian Point Energy Center

450 Broadway, GSB

P.O. Box 249

Buchanan, NY 10511-0249

SUBJECT:

INDIAN POINT NUCLEAR GENERATING - INTEGRATED INSPECTION

REPORT 05000247/2016002 AND 05000286/2016002

Dear Mr. Vitale:

On June 30, 2016, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at

your Indian Point Nuclear Generating (Indian Point), Units 2 and 3. The enclosed inspection

report documents the inspection results, which were discussed on August 4, 2016, with Larry

Coyle and other members of your staff. Based on additional information provided, the

inspectors conducted an updated exit meeting on August 30, 2016 with John Kirkpatrick, Plant

Operations General Manager and other members of your staff.

The inspection examined activities conducted under your license as they relate to safety and

compliance with the Commissions rules and regulations and with the conditions of your license.

The inspectors reviewed selected procedures and records, observed activities, and interviewed

personnel.

This report documents three NRC-identified findings of very low safety significance (Green).

These findings involved violations of NRC requirements. However, because of the very low

safety significance, and because they are entered into your corrective action program, the NRC

is treating these findings as non-cited violations, consistent with Section 2.3.2.a of the NRC

Enforcement Policy. If you contest any non-cited violation in this report, you should provide a

response within 30 days of the date of this inspection report, with the basis for your denial, to

the Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC

20555-0001; with copies to the Regional Administrator, Region I; the Director, Office of

Enforcement, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001; and the

NRC Senior Resident Inspector at Indian Point. In addition, if you disagree with the

cross-cutting aspect assigned to any finding in this report, you should provide a response within

30 days of the date of this inspection report, with the basis for your disagreement, to the

Regional Administrator, Region I, and the NRC Senior Resident Inspector at Indian Point.

A. Vitale

-2-

In accordance with Title 10 of the Code of Federal Regulations (10 CFR) 2.390 of the NRCs

Rules of Practice, a copy of this letter, its enclosure, and your response (if any) will be

available electronically for public inspection in the NRCs Public Document Room or from the

Publicly Available Records component of the NRCs Agencywide Documents Access and

Management System (ADAMS). ADAMS is accessible from the NRC website at

http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,

/RA/

Glenn T. Dentel, Chief

Reactor Projects Branch 2

Division of Reactor Projects

Docket Nos.

50-247 and 50-286

License Nos. DPR-26 and DPR-64

Enclosure:

Inspection Report 05000247/2016002 and 05000286/2016002

w/Attachment: Supplementary Information

cc w/encl: Distribution via ListServ

ML16243A245

SUNSI Review

Non-Sensitive

Sensitive

Publicly Available

Non-Publicly Available

OFFICE

RI/DRP

RI/DRP

RI/DRS

RI/DRP

RI/DRP

NAME

BHaagensen/bh

NFloyd/nf

MGray/mg

GDentel/gtd

MScott/dlp for

DATE

8/29/16

8/24/16

8/30/16

8/30/16

8/30/16

1

Enclosure

U.S. NUCLEAR REGULATORY COMMISSION

REGION I

Docket Nos.

50-247 and 50-286

License Nos.

DPR-26 and DPR-64

Report Nos.

05000247/2016002 and 05000286/2016002

Licensee:

Entergy Nuclear Northeast (Entergy)

Facility:

Indian Point Nuclear Generating Units 2 and 3

Location:

450 Broadway, GSB

Buchanan, NY 10511-0249

Dates:

April 1, 2016, through June 30, 2016

Inspectors:

B. Haagensen, Senior Resident Inspector

G. Newman, Resident Inspector

S. Rich, Resident Inspector

S. Galbreath, Reactor Inspector

J. Furia, Senior Health Physicist

N. Floyd, Senior Project Engineer

K. Mangan, Senior Reactor Inspector

J. Poehler, Senior Materials Engineer

Approved By:

Glenn T. Dentel, Chief

Reactor Projects Branch 2

Division of Reactor Projects

2

TABLE OF CONTENTS

SUMMARY .................................................................................................................................... 3

REPORT DETAILS ....................................................................................................................... 5

1.

REACTOR SAFETY .............................................................................................................. 5

1R04

Equipment Alignment .................................................................................................. 5

1R05

Fire Protection ............................................................................................................. 6

1R07

Heat Sink Performance ............................................................................................... 7

1R08

Inservice Inspection Activities ..................................................................................... 7

1R11

Licensed Operator Requalification Program ............................................................... 8

1R12

Maintenance Effectiveness ....................................................................................... 10

1R13

Maintenance Risk Assessments and Emergent Work Control .................................. 13

1R15

Operability Determinations and Functionality Assessments ..................................... 14

1R18

Plant Modifications .................................................................................................... 19

1R19

Post-Maintenance Testing ........................................................................................ 20

1R20

Refueling and Other Outage Activities ...................................................................... 21

1R22

Surveillance Testing .................................................................................................. 24

1EP6

Drill Evaluation .......................................................................................................... 25

2.

RADIATION SAFETY .......................................................................................................... 25

2RS1

Radiological Hazard Assessment and Exposure Controls ........................................ 25

2RS2

Occupational As Low As Is Reasonably Achievable (ALARA) Planning

and Controls .............................................................................................................. 26

2RS7

Radiological Environmental Monitoring Program (REMP) ........................................ 26

4.

OTHER ACTIVITIES ............................................................................................................ 27

4OA1

Performance Indicator Verification ............................................................................ 27

4OA2

Problem Identification and Resolution ....................................................................... 28

4OA3

Follow Up of Events and Notices of Enforcement Discretion .................................... 34

4OA5

Other Activities .......................................................................................................... 37

4OA6

Meetings, Including Exit ............................................................................................ 39

SUPPLEMENTARY INFORMATION ........................................................................................ A-1

KEY POINTS OF CONTACT .................................................................................................... A-1

LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED ..................................... A-2

LIST OF DOCUMENTS REVIEWED ........................................................................................ A-3

LIST OF ACRONYMS ............................................................................................................. A-12

3

SUMMARY

Inspection Report 05000247/2016002 and 05000286/2016002; 04/01/2016 - 06/30/2016; Indian

Point Nuclear Generating (Indian Point), Units 2 and 3; Operability Determinations and

Functionality Assessments, Refueling and Other Outage Activities, and Follow Up of Events and

Notices of Enforcement Discretion.

This report covered a three-month period of inspection by resident inspectors and announced

inspections performed by regional inspectors. The inspectors identified three findings of very

low safety significance (Green), which were non-cited violations (NCVs). The significance of

most findings is indicated by their color (i.e., greater than Green, or Green, White, Yellow, Red)

and determined using Inspection Manual Chapter (IMC) 0609, Significance Determination

Process, dated April 29, 2015. Cross-cutting aspects are determined using IMC 0310,

Aspects within the Cross-Cutting Areas, dated December 4, 2014. All violations of

U.S. Nuclear Regulatory Commission (NRC) requirements are dispositioned in accordance with

the NRCs Enforcement Policy, dated February 4, 2015. The NRCs program for overseeing the

safe operation of commercial nuclear power reactors is described in NUREG-1649, Reactor

Oversight Process, Revision 6.

Cornerstone: Mitigating Systems

Green. The inspectors identified a Green NCV of 10 CFR 50, Appendix B, Criterion V,

"Instructions, Procedures, and Drawings," because Entergy did not adequately accomplish

the actions prescribed by procedure EN-OP-104, Operability Determination Process, for a

degraded condition associated with the Unit 3 baffle-former bolts. Specifically, Entergy

incorrectly concluded that no degraded or non-conforming condition existed related to the

Unit 3 baffle-former bolts and exited the operability determination procedure. Entergy

subsequently performed the remaining steps in the procedure and provided appropriate

justification for their plans to examine the baffle-former bolts at the next Unit 3 refueling

outage (RFO). Entergys immediate corrective actions included entering the issue into its

corrective action program (CAP) as CR-IP3-2016-01961 and documenting an operability

evaluation to support the basis for operability of the baffle-former bolts and the emergency

core cooling system (ECCS).

This performance deficiency is more than minor because it was associated with the

equipment performance attribute of the Mitigating Systems cornerstone and affected the

cornerstone objective to ensure the availability, reliability, and capability of systems that

respond to initiating events to prevent undesirable consequences (i.e., core damage). In

accordance with IMC 0609.04, Initial Characterization of Findings, and Exhibit 2 of

IMC 0609, Appendix A, The Significance Determination Process for Findings At-Power,

issued June 19, 2012, the inspectors screened the finding for safety significance and

determined it to be of very low safety significance (Green), because the finding did not

represent an actual loss of system or function. After inspector questioning, Entergy

performed an operability evaluation, which provided sufficient bases to conclude the Unit 3

baffle assembly would support ECCS operability. This finding is related to the cross-cutting

aspect of Problem Identification and Resolution, Operating Experience, because Entergy did

not effectively evaluate relevant internal and external operating experience. Specifically,

Entergy did not adequately evaluate the impact of degraded baffle bolts at Unit 3 when

relevant operating experience was identified at Unit 2. [P.5 - Operating Experience]

(Section 1R15)

4

Green. The inspectors identified a Green NCV of Technical Specification (TS) 5.4.1,

Procedures, for Entergys failure to implement procedure OAP-007, Containment Entry

and Egress. Specifically, workers transiting the inner and outer crane wall sections of

containment failed to maintain at least one (of two) flow channeling gate closed to ensure

availability of the containment sumps to provide suction for the ECCS. Entergy immediately

coached the gate monitor and restored the gates to an acceptable position. Entergy

generated CR-IP2-2016-04036 to address this issue.

This performance deficiency is more than minor because it was associated with the

configuration control (shutdown equipment lineup) attribute of the Mitigating Systems

cornerstone and affected the cornerstone objective to ensure the availability, reliability, and

capability of systems that respond to initiating events to prevent undesirable consequences

(i.e., core damage). A detailed risk assessment was conducted and determined that the

change in core damage frequency was determined to be 7E-9, therefore, this issue

represents a Green finding. This finding had a cross-cutting aspect in the area of Human

Performance, Avoid Complacency, because Entergy did not consider potential undesired

consequences of actions before performing work and implement appropriate error-reduction

tools. Specifically, the work crew did not understand the requirements and potential

consequences prior to commencing work and the gate monitor did not enforce these

requirements to maintain at least one gate locked or pinned closed as required by OAP-007.

[H.12 - Avoid Complacency] (Section 1R20)

Cornerstone: Barrier Integrity

Green. The inspectors identified a Green NCV of 10 CFR 50.65(b)(1) for Entergys failure to

include a function of a safety-related system within the scope of the maintenance rule

program. Specifically, Entergy failed to include the feedwater isolation function performed

by the main boiler feedwater pumps (MBFPs) discharge valves, MBFPs, and feedwater

regulating valves, which are required to remain functional during and following a design

basis event to mitigate the consequence of the accident within the scope of the maintenance

rule monitoring program. Entergy initiated corrective actions to include the feedwater

isolation function performed by the MBFP discharge valves, MBFPs, and feedwater

regulating valves within the maintenance rule monitoring program. Entergy entered this

issue into the CAP as CR-IP2-2016-03963.

This performance deficiency is more than minor because it was associated with barrier

performance attribute of the Barrier Integrity cornerstone and adversely affected the

cornerstone objective to provide reasonable assurance that physical design barriers protect

the public from radionuclide releases caused by accidents or events. Specifically, the failure

to properly scope the feedwater isolation function prevented Entergy from identifying that

equipment reliability was no longer effectively controlled through preventive maintenance.

In accordance with IMC 0609.04, Initial Characterization of Findings, and Exhibit 2 of IMC 0609, Appendix A, The Significance Determination Process for Findings At-Power, issued

June 19, 2012, the inspectors determined that the finding was of very low safety significance

(Green) because the finding did not represent an actual open pathway in the physical

integrity of reactor containment, containment isolation system, and heat removal

components. This finding does not have a cross-cutting aspect since the failure to scope

this equipment into the maintenance rule program was not recognized when Entergy

combined the maintenance rule basis documents for Units 2 and 3 in 2012 and, as a result,

is not indicative of current licensee performance. (Section 4OA3)

5

REPORT DETAILS

Summary of Plant Status

Unit 2 began the inspection period during RFO 2R22 which lasted 102 days. Upon completion

of the outage, the operators restarted Unit 2 on June 14, 2016, and increased power slowly to

93 percent for fuel preconditioning. On June 23, 2016, the operators shutdown the reactor to

repair a service water leak on the 21 component cooling water (CCW) heat exchanger (Hx) inlet

line and replace switchyard breaker 9. Unit 2 returned to 100 percent power on June 29, 2016.

Unit 2 remained at or near 100 percent power for the remainder of the inspection period.

Unit 3 began the inspection period at 100 percent power. On April 26, 2016, a failed controller

caused both heater drain pumps to trip; and the operators reduced power rapidly, stabilizing the

unit at 48 percent power. Operators returned Unit 3 to 100 percent power on April 27, 2016,

and remained at or near 100 percent power for the remainder of the inspection period.

1.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity

1R04 Equipment Alignment

Partial System Walkdowns (71111.04Q - 5 samples)

a. Inspection Scope

The inspectors performed partial walkdowns of the following systems:

Unit 2

Spent fuel pool cooling system following core offload on May 19, 2016

Shutdown cooling system following core reload on June 6, 2016

CCW system following maintenance on June 28, 2016

Unit 3

32 emergency diesel generator (EDG) following maintenance on May 9, 2016 (this

sample was part of an in-depth review of the EDG system)

Residual heat removal pumps following CCW system testing on May 20, 2016

The inspectors selected these systems based on their risk-significance relative to the

reactor safety cornerstones at the time they were inspected. The inspectors reviewed

applicable operating procedures, system diagrams, the updated final safety analysis

report (UFSAR), TSs, work orders (WOs), condition reports (CRs), and the impact of

ongoing work activities on redundant trains of equipment in order to identify conditions

that could have impacted system performance of their intended safety functions. The

inspectors also performed field walkdowns of accessible portions of the systems to verify

system components and support equipment were aligned correctly and were operable.

The inspectors examined the material condition of the components and observed

operating parameters of equipment to verify that there were no deficiencies. The

6

inspectors also reviewed whether Entergy had properly identified equipment issues and

entered them into the CAP for resolution with the appropriate significance

characterization. Documents reviewed for each section of this inspection report are

listed in the Attachment.

b. Findings

No findings were identified.

1R05 Fire Protection

Resident Inspector Quarterly Walkdowns (71111.05Q - 6 samples)

a. Inspection Scope

The inspectors conducted tours of the areas listed below to assess the material

condition and operational status of fire protection features. The inspectors verified that

Entergy controlled combustible materials and ignition sources in accordance with

administrative procedures. The inspectors verified that fire protection and suppression

equipment were available for use as specified in the area pre-fire plan (PFP) and

passive fire barriers were maintained in good material condition. The inspectors also

verified that station personnel implemented compensatory measures for out-of-service

(OOS), degraded, or inoperable fire protection equipment, as applicable, in accordance

with procedures.

Unit 2

Containment, 95-foot elevation, during baffle bolt repair activities with hot work in

progress (PFP-203 was reviewed) on June 2, 2016

Residual heat removal pump rooms in primary auxiliary building (PAB), 15-foot

elevation (PFP-204 was reviewed), on June 6, 2016

CCW pump room, 68-foot elevation (PFP-209 was reviewed), on June 25, 2016

PAB, 80-foot elevation, CCW heat exchanger area with hot work in progress

(PFP-211 was reviewed) on June 25, 2016

Unit 3

32 EDG room, 10-foot elevation (PFP-354 was reviewed), on May 9, 2016

480V switchgear room, 15-foot elevation (PFP-351 was reviewed), on June 30, 2016

b. Findings

No findings were identified.

7

1R07 Heat Sink Performance (71111.07A - 1 sample)

a. Inspection Scope

The inspectors reviewed the 32 EDG jacket water and lube oil heat exchanger to

determine its readiness and availability to perform its safety functions. The inspectors

reviewed the design basis for the component and verified Entergys commitments to

NRC Generic Letter 89-13, Service Water System Requirements Affecting

Safety-Related Equipment. The inspectors observed the annual cleaning and

inspection of the heat exchangers and reviewed the results of previous inspections of

the Unit 3 EDG heat exchangers. The inspectors discussed the results of the most

recent inspection with engineering staff. The inspectors verified that Entergy initiated

appropriate corrective actions for identified deficiencies. The inspectors also verified

that the number of tubes plugged within the heat exchanger did not exceed the

maximum amount allowed.

b. Findings

No findings were identified.

1R08 Inservice Inspection Activities (71111.08P - 1 sample)

a. Inspection Scope

Inspectors from the NRC Region I Office, specializing in materials and inservice

examination activities, observed portions of Entergys activities involving baffle-former

bolt examinations and replacements during Unit 2 RFO 2R22. The inspectors reviewed

work documentation and examination procedures and results, and discussed these

activities with Entergy. The inspectors were on-site from April 27 to April 28, 2016, and

on May 23, 2016. The inspectors verified that Entergy completed baffle-former bolt

examinations in accordance with their approved procedures which implemented

activities described in the Materials Reliability Program (MRP)-227-A, Pressurized

Water Reactor Internals Inspection and Evaluation Guidelines, as they relate to this

component. Specifically, the inspectors reviewed the results of the visual and volumetric

examinations of the baffle-former bolts, including capabilities, limitations, and

acceptance criteria that were performed during the current RFO.

Non-Destructive Examination Activities

The inspectors reviewed the ultrasonic testing (UT) procedure used for the examination

of the Unit 2 baffle-former bolts to verify the procedure was in accordance with the

applicable guidance in MRP-227-A and MRP-228. The inspectors reviewed the UT data

records and the detailed UT channel analysis for a sample of baffle-former bolts to verify

the examinations and evaluations were performed in accordance with approved

procedures and applicable guidance. The inspectors reviewed video recordings of the

visual examinations of the baffle-former bolts during the current RFO. The inspectors

also reviewed recorded video of visual examinations performed in 2006 at Unit 2,

completed as part of the existing inservice inspection program for the 10-year reactor

vessel examinations, to independently assess the past conditions of the baffle-former

bolts and assembly.

8

The inspectors reviewed certifications of the UT technicians performing the ultrasonic

examinations to verify the examinations were performed by qualified individuals and to

verify the results were reviewed and evaluated by certified level III non-destructive

examination personnel.

Baffle-Former Bolt Replacement Activities

The inspectors reviewed the baffle-former bolt replacement activities performed as part

of a corrective action to resolve the degraded condition identified at Unit 2. The

inspectors observed a sample of in-process bolt removal activities, which included lock

bar milling and bolt hole machining. The inspectors reviewed the documentation for

in-process and completed bolt installation activities and verified that loose parts

generated as part of the bolt replacements were properly tracked. The inspectors

verified that bolt replacement activities were performed in accordance with approved

procedures. The inspectors also reviewed the Engineering Change (EC) package

associated with the new baffle-former bolt design. This review is documented in

Section 1R18 of this report. After completion of the bolt replacement activities, the

inspectors reviewed the video of the final visual examination of the baffle assembly to

verify that the baffle-former bolt work was accomplished as planned and that there were

no visual indications of deficiencies.

b. Findings

No findings were identified.

Update to URI 05000247/2016001-01, Baffle-Former Bolts with Identified Anomalies

This inspection was conducted to follow-up on NRC Unresolved Item (URI)05000247/2016001-01, Baffle-Former Bolts with Identified Anomalies, to determine

whether there was a performance deficiency associated with the degraded baffle-former

bolt condition discovered at Unit 2. The inspectors plan to review additional technical

information from Entergy as it becomes available, including any revisions to the root

cause evaluation. The URI remains open until review of this additional information is

completed. (URI 05000247/2016001-01, Baffle-Former Bolts with Identified

Anomalies)

1R11 Licensed Operator Requalification Program (71111.11Q - 5 samples)

Unit 2

.1

Quarterly Review of Unit 2 Licensed Operator Requalification Testing and Training

(71111.11Q - 1 sample)

a. Inspection Scope

The inspectors observed Unit 2 licensed operator simulator training on May 24, 2016,

which included reactor coolant pump seal failure with loss of normal heat sink requiring

implementation of feed and bleed cooling. The inspectors evaluated operator

performance during the simulated event and verified completion of risk significant

operator actions, including the use of abnormal and emergency operating procedures.

The inspectors assessed the clarity and effectiveness of communications,

9

implementation of actions in response to alarms and degrading plant conditions, and the

oversight and direction provided by the control room supervisor. The inspectors verified

the accuracy and timeliness of the emergency classification made by the shift manager

and the TS action statements entered by the shift technical advisor. Additionally, the

inspectors assessed the ability of the crew and training staff to identify and document

crew performance problems.

b. Findings

No findings were identified.

.2

Quarterly Review of Unit 3 Licensed Operator Requalification Testing and Training

(71111.11Q - 1 sample)

a. Inspection Scope

The inspectors observed a Unit 3 licensed operator simulator requalification training

evaluated scenario on May 24, 2016, which included failure of a pressurizer pressure

instrument, charging pump trip, loss of 480V safety bus 5A, a small break loss-of-coolant

accident (LOCA), and entry into FR-C.2 core cooling. The inspectors evaluated operator

performance during the simulated event and verified completion of risk significant

operator actions, including the use of abnormal and emergency operating procedures.

The inspectors assessed the clarity and effectiveness of communications,

implementation of actions in response to alarms and degrading plant conditions, and the

oversight and direction provided by the control room supervisor. The inspectors verified

the accuracy and timeliness of the emergency classification made by the shift manager

and the TS action statements entered by the shift technical advisor. Additionally, the

inspectors assessed the ability of the crew and training staff to identify and document

crew performance problems.

b. Findings

No findings were identified.

.3

Quarterly Review of Licensed Operator Performance (71111.11Q - 3 samples)

a. Inspection Scope

The inspectors conducted a focused observation of operator performance in the main

control room. The inspectors observed pre-job briefings and control room

communications to verify they met the criteria specified in Entergys administrative

procedure EN-OP-115, Conduct of Operations. Additionally, the inspectors observed

restoration activities to verify that procedure use, crew communications, and

coordination of activities between work groups similarly met established expectations

and standards.

10

Unit 2

Plant startup from RFO 2R22 on June 16, 2016 including response to a turbine trip

without a reactor trip and the subsequent turbine-generator synchronization and

transfer of plant electrical loads from offsite power to the unit auxiliary transformer.

Reactor startup and grid synchronization conducted on June 27, 2016.

Unit 3

Operator response to the feedwater transient which occurred on April 26, 2016

b. Findings

No findings were identified.

1R12 Maintenance Effectiveness (71111.12Q - 4 samples)

.1

Routine Maintenance Effectiveness

a. Inspection Scope

The inspectors reviewed the samples listed below to assess the effectiveness of

maintenance activities on SSCs performance and reliability. The inspectors reviewed

system health reports, CAP documents, maintenance WOs, and maintenance rule basis

documents to ensure that Entergy was identifying and properly evaluating performance

problems within the scope of the maintenance rule. For each SSC sample selected, the

inspectors verified that the SSC was properly scoped into the maintenance rule in

accordance with 10 CFR 50.65 and verified that the (a)(2) performance criteria

established by Entergy was reasonable. As applicable, for SSCs classified as (a)(1), the

inspectors assessed the adequacy of goals and corrective actions to return these SSCs

to (a)(2). Additionally, the inspectors ensured that Entergy was identifying and

addressing common cause failures that occurred within and across maintenance rule

system boundaries.

Unit 2 EDGs

Unit 3 EDGs (this sample was part of an in-depth review of the EDG system)

Units 2 and 3 CVCS

b. Findings

No findings were identified.

URI Opened, CVCS Goal Monitoring Under the Maintenance Rule

Introduction

The inspectors identified issues of potential concern with Entergys application of

10 CFR 50.65(a)(1), Requirements for Monitoring the Effectiveness of Maintenance at

Nuclear Plants, (the maintenance rule) in regards to the reliability of the Unit 2 CVCS

system. These concerns included the establishment of appropriate (a)(1) goals and

11

whether appropriate justification was established that the corrective actions to address

identified maintenance weaknesses were effective prior to removal from (a)(1) status.

Specifically, Entergy may have established restrictive goals without defensible

justification and may not have demonstrated their chosen goal before ending the goal

monitoring interval.

Description

The maintenance rule requires that licensees shall monitor the performance or condition

of structures, systems, or components, against licensee-established goals, in a manner

sufficient to provide reasonable assurance that these structures, systems, and

components are capable of fulfilling their intended functions. These goals shall be

established commensurate with safety and, where practical, take into account

industrywide operating experience. When the performance or condition of a structure,

system, or component does not meet established goals, appropriate corrective action

shall be taken. EN-DC-206, Maintenance Rule (a)(1) Process, provides the

requirements and processes for managing SSCs for which (a)(2) monitoring has not

demonstrated effective maintenance. EN-DC-206 specifies that (a)(1) action plans

should not be closed until effectiveness of all corrective actions has been demonstrated

by meeting performance goals through the monitoring period (or by other means

specified in the action plan).

Since 2013, there have been several repeat functional failures of equipment in the

CVCS resulting in a failure to meet the performance criterion for reliability. These

failures included:

A failure of the 23 charging pump on August 6, 2013, after the internal oil pump

discharge tubing broke causing the pump to trip on low oil pressure and a loss of

charging. The 21 charging pump had tripped for the same reason in 2010.

A failure of the 22 charging pump on January 14, 2014, due to cracked internal

check valves caused by an inadequate fill-and-vent that left air in the pump following

maintenance. The 21 charging pump had failed due to the same cause in 2013.

A failure of the Unit 2 valve FCV-110A, boric acid flow control valve, to fully open on

January 5, 2015. The valve had insufficient insulation; and as a result, boron

crystalized above the valve plug and blocked its movement. The Unit 3 FCV-110A

had failed in the same way in 2011, with earlier failures of other valves for the same

cause going back to 1997.

In each case, the CVCS for Unit 2 was already (a)(1), so Entergy either updated the

existing (a)(1) action plan or created another one to operate in parallel with the existing

one. Upon reviewing the associated (a)(1) action plans, the inspectors noted that in

each example Entergys goals may not have been in accordance with EN-DC-206(a)(1)

Process. It specifies that monitoring intervals should be at least six months for normally

operating SSCs, at least three surveillances for SSCs monitored by surveillance and

long enough to detect recurrence of the applicable failure mechanism. It also states that

performance goals that provide reasonable assurance that the SSC is capable of

performing its intended functions should be monitored throughout the time the SSC is

classified (a)(1). EN-DC-206 defines an SSC as any discreet component grouping that

has caused a monitoring failure, including any applicable extent of condition. In the

examples provided, NRC inspectors challenged whether Entergy either chose a shorter

12

monitoring interval or a goal that did not include the applicable extent of condition.

Specifically:

The (a)(1) action plan for the broken oil tubing had a goal of no noticeable decrease

in 23 charging pumps running oil pressure for the next three quarterly surveillances.

The chosen monitoring interval met the procedural expectation, but Entergy limited

the monitoring to the 23 charging pump without written justification, when the 21

charging pump had failed previously for the same reason and the other pumps were

susceptible to the same failure mechanism. During the monitoring interval, the 21

charging pump experienced low oil pressure. When Entergy performed repairs on

the 21 charging pump for an unrelated issue, they discovered that the oil tubing had

failed in the same way the 23 charging pump oil tubing had failed, although it had not

yet caused a pump trip.

The (a)(1) action plan for the cracked check valves had a goal of no check valve

failure for six months for the next charging pump that underwent maintenance. This

happened to be the 22 charging pump. Entergy chose a six-month monitoring

interval, even though only one of the three charging pumps is in service at any given

time, and the 22 charging pump only ran for four out of the six months it was

monitored. Additionally, the action plan did not justify why a single successful fill-

and-vent demonstrated adequate corrective actions. On November 19, 2014, during

the six month monitoring interval, the 21 charging pump underwent maintenance

requiring a fill-and-vent, and experienced check valve failure two weeks later on

December 4. Entergy documented this as a maintenance rule functional failure, and

discussed the possibility that it could be due to an inadequate fill-and-vent, but did

not change the (a)(1) action plan.

The (a)(1) action plan for FCV-110A specified a monitoring interval of six months to

include the winter because the previous valve failures had all occurred during the

winter months. However, the actual monitoring interval documented in the corrective

action was from April to October 2015, and therefore did not cover the winter months

as intended. In January 2016, Entergy performed maintenance on valve CH-297 on

Unit 3, which is a heat-traced boric acid valve, and did not properly restore the

insulation. The valve function was not impacted because it does not often contain

high concentrations of boric acid.

The (a)(1) action plans described above were all reviewed and approved by the

maintenance rule expert panel.

Further information regarding the performance of these SSCs is required to determine

whether these issues of concern represent performance deficiencies and whether they

are more than minor. (URI 05000247/2016002-01, CVCS Goal Monitoring Under the

Maintenance Rule)

.2

Quality Control

a. Inspection Scope

The inspectors reviewed the weld repair performed on the 21 CCW heat exchanger

service water inlet nozzle for Unit 2 to verify Entergy was properly applying quality

controls specified in their quality assurance program. The inspectors reviewed CAP

documents, maintenance WOs, ECs, and engineering procedures associated with the

weld repair. The inspectors verified Entergy specified quality control hold points in

13

accordance with their procedures, properly controlled the quality of materials used

during the repair, and adequately justified deviations from the existing design.

Additionally, the inspectors reviewed the welding procedure specification qualification by

the vendor to ensure it was in accordance with American Society of Mechanical

Engineers code.

b. Findings

No findings were identified.

1R13 Maintenance Risk Assessments and Emergent Work Control (71111.13 - 7 samples)

a. Inspection Scope

The inspectors reviewed station evaluation and management of plant risk for the

maintenance and emergent work activities listed below to verify that Entergy performed

the appropriate risk assessments prior to removing equipment for work. The inspectors

selected these activities based on potential risk significance relative to the reactor safety

cornerstones. As applicable for each activity, the inspectors verified that Entergy

performed risk assessments as required by 10 CFR 50.65(a)(4) and that the

assessments were accurate and complete. When Entergy performed emergent work,

the inspectors verified that operations personnel promptly assessed and managed plant

risk. The inspectors reviewed the scope of maintenance work and discussed the results

of the assessment with the stations probabilistic risk analyst to verify plant conditions

were consistent with the risk assessment. The inspectors also reviewed the TS

requirements and inspected portions of redundant safety systems, when applicable, to

verify risk analysis assumptions were valid and applicable requirements were met.

Unit 2

Temporary loss of spent fuel pool cooling due to 345-kilovolt disturbance on

April 3, 2016

Equipment hatch closure plug seal demonstration for outage risk on April 5, 2016

Reduced inventory operations during vessel reassembly on June 7, 2016

21 CCW heat exchanger OOS during mode 4 on June 25, 2016

Unit 3

32 EDG OOS while Bus Tie BT 4-5 was OOS on May 4, 2016 (this sample was part

of an in-depth review of the EDG system)

33 EDG OOS while Bus Tie BT 4-5 was OOS on June 2, 2016

31 EDG OOS while Bus Tie BT 4-5 was OOS on June 21, 2016

b. Findings

No findings were identified.

14

1R15 Operability Determinations and Functionality Assessments (71111.15 - 7 samples)

a. Inspection Scope

The inspectors reviewed operability determinations for the following degraded or

non-conforming conditions:

Unit 2

23 EDG failure to run on March 7, 2016, and subsequent failure to pass the

surveillance test on March 10, 2016, as identified in CR-IP2-2016-01260

Operability determination for N33 gamma metrics wide range nuclear instrument

channel in CR-IP2-2016-03660 on June 13, 2016

Pressurizer level transmitter LT-461 reads high in CR-IP-2016-3806 on June 14,

2016

Through-wall leak in line 411, service water inlet to the 21 CCW heat exchanger, on

June 15, 2016

Unit 3

Immediate operability determination of the degraded condition of the baffle-former

bolts identified from Unit 2 operating experience in CR-IP3-2016-01035 on April 1,

2016

Anomalies noted during digital metal impact monitoring system self-test in

CR-IP3-2015-03468 on April 1, 2016

Prompt operability determination of the degraded condition of the baffle-former bolts

identified from Unit 2 operating experience in CR-IP2-2016-03660 on June 30, 2016

The inspectors selected these issues based on the risk significance of the associated

components and systems. The inspectors evaluated the technical adequacy of the

operability determinations to assess whether TS operability was properly justified and

the subject component or system remained available such that no unrecognized

increase in risk occurred. The inspectors compared the operability and design criteria in

the appropriate sections of the TSs and UFSAR to Entergys evaluations to determine

whether the components or systems were operable.

The inspectors confirmed, where appropriate, compliance with bounding limitations

associated with the evaluations. Where compensatory measures were required to

maintain operability, the inspectors determined whether the measures in place would

function as intended and were properly controlled by Entergy. The inspectors

determined, where appropriate, compliance with bounding limitations associated with the

evaluations.

b. Findings

Introduction. The inspectors identified a Green NCV of 10 CFR 50, Appendix B,

Criterion V, "Instructions, Procedures, and Drawings," because Entergy did not

adequately accomplish the actions prescribed by procedure EN-OP-104 for a degraded

condition associated with the Unit 3 baffle-former bolts. Specifically, Entergy incorrectly

concluded that no degraded or non-conforming condition existed related to the Unit 3

15

baffle-former bolts and exited the operability determination procedure. Entergy

subsequently performed the remaining steps in the procedure and provided appropriate

justification for their plans to examine the baffle-former bolts at the next Unit 3 RFO.

Description. On March 29, 2016, Entergy identified baffle-former (baffle) bolt

degradation at Indian Point Unit 2 that was determined to be unanalyzed because it did

not meet the minimum acceptable bolt pattern analysis developed to support plant

startup. Entergy staff identified a total of 227 baffle bolts out of a population of 832 that

were potentially degraded (182 bolts had UT indications; 31 had visual indications of

failure; and 14 were inaccessible for testing and conservatively assumed to be

degraded). Entergy staff entered this problem into the CAP as CR-IP2-2016-02081,

performed a root cause evaluation, and replaced the degraded bolts on Unit 2. Due to

the number of baffle bolt indications discovered on Unit 2, Entergy staff initiated CR-IP3-

2016-01035 on April 21, 2016, and performed an immediate operability determination

(IOD) in accordance with Entergy procedure EN-OP-104 Section 5.3, to evaluate the

baffle bolts and baffle-former assembly structure on Unit 3. Entergy staff planned further

corrective actions to move up the planned Unit 3 baffle bolt ultrasonic examinations to

the next RFO in spring 2017.

The inspectors reviewed the design basis and current licensing basis documents for

Indian Point Unit 3 to identify the specific safety functions of the baffle bolts. The baffle

bolts are part of the baffle former assembly structure located in the reactor pressure

vessel. The bolts secure a series of vertical metal plates called baffle plates, which help

direct water up through the nuclear fuel assemblies to ensure proper cooling of the fuel.

A sufficient number of baffle bolts are required to secure the plates to ensure proper

core flow during normal and postulated accident conditions, and also to ensure that

control rods can be inserted to shut down the reactor.

The inspectors reviewed Entergys IOD issued on April 21, 2016, and concluded the

immediate determination was completed in accordance with Section 5.3 of procedure

EN-OP-104. The IOD provided sufficient technical detail to support the initial conclusion,

based on limited information, that the Unit 3 baffle bolts would retain sufficient capability

to perform their intended functions. Specifically, the IOD stated that Unit 2 baffle bolt

failures were likely due to irradiation-assisted stress corrosion cracking (IASCC) and that

the Unit 3 baffle bolts were also susceptible because they both utilize a baffle bolt design

with similar geometry and material to other plants with bolt failures. The IOD concluded

that Unit 3 baffle bolt degradation would likely not be as significant as Unit 2, and that

the Unit 3 baffle former assembly was currently operable pending further evaluation

because of the following differences with Unit 2: (1) less effective full power years of

operation; (2) less neutron fluence levels (i.e., irradiation); (3) less pressure differential

across the baffle plates; and (4) less fatigue-induced loading cycles on the bolts over the

operating life of the plant. The inspectors concluded that there was no immediate safety

concern.

On May 5, 2016, Entergy staff revised the operability input for CR-IP3-2016-01035 under

corrective action #2. The inspectors noted that Entergy staff concluded an operability

evaluation was not needed, in part, because the baffle-former bolts are not required by

TS and are not described in the UFSAR. The inspectors noted that while the baffle

bolts are not described in these documents, their failure in sufficient numbers could have

consequential effects on the TS-controlled ECCS if the baffle plates were to become

detached or deformed. This was described in Entergys bolt pattern analysis report

16

documenting an acceptable bolt pattern prior to the spring 2016 RFO. The inspectors

reviewed Unit 3 TS 3.5.2, ECCS - Operating, which requires multiple trains of ECCS to

be operable. The inspectors concluded that since the baffle bolts support the ECCS,

which is subject to TS, Entergys decision to not perform further evaluation of the

operability determination was inconsistent with EN-OP-104. Specifically, Section 5.1(7)

of Entergys procedure EN-OP-104 requires that an operability determination be

performed whenever a condition exists in the supporting SCC that may affect the ability

of the TS-controlled SSC to perform its specified safety function.

Further, the inspectors noted that Entergy staff concluded a degraded condition did not

exist in Unit 3, and therefore, an operability evaluation was not required as a follow-up to

the immediate determination. The documented basis provided was the differences

between the two units, plant operating data, and fuel performance. The inspectors noted

that plant operating data and fuel performance from Unit 2 did not result in identification

of the bolt degradation; therefore, the absence of indications for these problems on Unit

3 was technically insufficient to support Entergys conclusion that there was no degraded

condition on Unit 3.

The inspectors review of procedure EN-OP-104, Section 3.0, identified that examples of

the effects of equipment aging and operating experience can be sources of information

considered to enter the operability or functionality process. The inspectors

acknowledged that licensees apply judgment in these decisions. In this particular

instance, the inspectors considered that operating experience was available that showed

the Unit 3 baffle bolts were subject to IASCC and that plants of similar design (4-loop

Westinghouse pressurized water reactors with a down-flow configuration and baffle bolts

of 347 material and similar dimensions) were subject to greater amounts of bolt

degradation compared to other reactor designs. Furthermore, the inspectors noted the

baffle bolts had experienced levels of neutron radiation exposure above the threshold for

IASCC initiation as referenced in NUREG/CR-7027, Degradation of LWR Core Internal

Materials due to Neutron Irradiation.

Based on the above information available to Entergy staff, the inspectors concluded that

Entergys basis for determining that a degraded condition did not exist on Unit 3 was not

technically supported. The inspectors noted that in completing an IOD in EN-OP-104,

Step 5.3.2 states determine if there is an ongoing degradation mechanism that may

impact future operability based on changing conditions, specifically consider the SSCs

specified safety function and mission time. On May 5, 2016, Entergys basis for

concluding an operability evaluation was not required and exiting the operability

determination procedure at Step 5.3.3 was inconsistent with this procedural requirement

because their IOD concluded Unit 3 was susceptible to baffle bolt degradation, which is

time based and subject to changing conditions including fatigue inducing loading cycles

and neutron fluence. As a result, the inspectors concluded Entergy staff did not

complete the additional actions prescribed by EN-OP-104 to perform an operability

evaluation. Specifically, Step 5.3.9 states in part if an Operability Evaluation is required

then perform the following: Proceed to Subsection 5.5, Operability Evaluation.

On July 11, 2016, Entergy staff subsequently completed the steps in EN-OP-104 and

performed an operability evaluation, which assumed an estimated number of baffle-

former bolt failures based on the degradation found in Unit 2, and adjusted to take credit

for the small number of inaccessible bolts and a sample of bolts extracted with high

removal torque that indicated residual structural capacity. The inspectors determined

17

this estimated number of bolt failures was conservative because the evaluation did not

credit the baffle-edge bolts or the differences in operational history between the two units

such as neutron fluence levels or fatigue from thermal cycles. The operability evaluation

concluded that the Unit 3 baffle bolts would perform as intended to secure the baffle

plates from being dislodged. The inspectors concluded that Entergys operability

evaluation provided appropriate basis to conclude that the Unit 3 baffle assembly would

support ECCS operability until the planned Unit 3 RFO in spring 2017.

Analysis. The inspectors determined that Entergys failure to adequately accomplish the

actions prescribed in EN-OP-104 for a degraded condition and perform an operability

evaluation associated with the Unit 3 baffle-former bolts was a performance deficiency.

Specifically, Entergy incorrectly concluded that no degraded or non-conforming condition

existed related to the Unit 3 baffle-former bolts and exited the operability determination

procedure. As a result, Entergys initial documentation did not provide sufficient basis

for operability and continued operation until questioned by NRC inspectors.

This finding is more than minor because it is associated with the equipment performance

attribute of the Mitigating Systems cornerstone and affected the cornerstone objective to

ensure the availability, reliability, and capability of systems that respond to initiating

events to prevent undesirable consequences (i.e., core damage). This issue was also

similar to example 3.j of IMC 0612, Appendix E, Examples of Minor Issues, because

the condition resulted in reasonable doubt of operability of the ECCS and additional

analysis was necessary to verify operability. In accordance with IMC 0609.04, Initial

Characterization of Findings, and Exhibit 2 of IMC 0609, Appendix A, The Significance

Determination Process for Findings At-Power, issued June 19, 2012, the inspectors

screened the finding for safety significance and determined it to be of very low safety

significance (Green), since the finding did not represent an actual loss of system or

function. After inspector questioning, Entergy performed an operability evaluation, which

provided sufficient bases to conclude the Unit 3 baffle assembly would support ECCS

operability. This finding is related to the cross-cutting aspect of Problem Identification

and Resolution, Operating Experience, because Entergy did not effectively evaluate

relevant internal and external operating experience. Specifically, Entergy did not

adequately evaluate the impact of degraded baffle bolts at Unit 3 when relevant

operating experience was identified at Unit 2. [P.5]

Enforcement. 10 CFR 50, Appendix B, Criterion V, Instructions, Procedures, and

Drawings, states, in part, that activities affecting quality shall be prescribed by

documented procedures of a type appropriate to the circumstances and shall be

accomplished in accordance with those procedures. The introduction to Appendix B

states that quality assurance comprises all those planned and systematic actions

necessary to provide adequate confidence that a structure, system, or component (SSC)

will perform satisfactorily in service. Procedure EN-OP-104, Step 5.3[2], related to

immediate operability, states Determine if there is an ongoing degradation mechanism

that may impact future operability based on changing conditions, specifically consider

the SSCs specified safety function and mission time. Step 5.3(3) follows with, in part If

no Degraded or Non-conforming Condition exists, then perform the following as the

Immediate Determination: Declare the SSC Operable and Exit this procedure.

Contrary to the above, from May 5, 2016 until July 11, 2016, Entergy did not adequately

accomplish actions as prescribed by EN-OP-104 for a degraded condition associated

with the Unit 3 baffle-former bolts. Specifically, Entergy incorrectly concluded that no

18

degraded or non-conforming condition existed related to the Unit 3 baffle-former bolts

and exited the operability determination procedure. The NRC determined this is contrary

to EN-OP-104 because a comparison of Unit 2 and 3 operational factors resulted in

Entergy concluding that the Unit 3 baffle bolts would likely be affected due to the same

degradation mechanism. Entergys corrective actions included entering the issue into

the CAP and documenting an operability evaluation to support the basis for operability of

the baffle bolts and ECCS. Because this issue is of very low safety significance (Green)

and Entergy entered this into their CAP as CR-IP3-2016-01961, this finding is being

treated as an NCV consistent with Section 2.3.2.a of the Enforcement Policy. (NCV 05000286/2016002-02, Failure to Follow Operability Determination Procedure for

Unit 3 Baffle-Former Bolts)

Update to URI 05000247/2016001-06, 23 Emergency Diesel Generator Automatic

Voltage Regulator Failure

Introduction. The NRC opened a URI in Inspection Report 05000247/2016001 related to

two failures of the 23 EDG to run and maintain bus voltage on March 7, 2016, and to

provide adequate control of bus voltage on March 10, 2016. This report provides an

update of the status of this URI.

Description. On March 7, 2016, approximately one hour after the trip of the 3A normal

feed breaker, the 23 EDG tripped on overcurrent while powering the 6A 480V safety bus.

The 6A bus remained de-energized for approximately one hour until the crew restored

the 6A bus via off-site power. The 23 EDG was declared inoperable. All four 480V

safety buses were restored to off-site power. Entergy replaced the overcurrent relays

and retested the 23 EDG satisfactorily on March 8, 2016. However, bench testing of the

overcurrent relays demonstrated that they were accurately calibrated.

Subsequently, on March 10, 2016, during performance of PT-R14, Automatic Safety

Injection System Electrical Load and Blackout Test, the 23 EDG exhibited anomalous

behavior during the train B load sequencing. During this test, the voltage on safety bus

6A dropped to approximately 200V when the 23 auxiliary feedwater pump was

sequenced onto the bus (CR-IP2-2016-01430) and the sequencer failed to complete the

first two sequences. The 23 EDG was again declared inoperable and the period of

inoperability was backdated to March 7, 2016, when it originally tripped. Further

troubleshooting and additional failure modes analysis by Entergy initially determined that

the cause of both events may have been a degraded resistor (R25) on the 23 EDG

automatic voltage regulator (AVR) card.

The 23 EDG AVR card was replaced, and the 23 EDG was again tested satisfactorily.

The voltage anomaly issues exhibited during the March 10, 2016, test were documented

in CR-IP2-2016-01430 which was closed in CR-IP2-2016-01260 to be included in the

causal assessment associated with the tripping of 23 EDG breaker on March 7, 2016.

Entergy assigned a vendor to perform laboratory bench testing and failure analysis of

the 23 EDG AVR card. The vendor report attributed the cause of the March 10, 2016,

loss of voltage control to a degraded solder joint on the AVR card. However, the vendor

report explicitly did not attribute the event on March 7, 2016, to the same cause.

Entergy assigned a corrective action in CR-IP2-2016-01260 to review the cause of the

19

23 EDG overcurrent trip on March 7, 2016, in light of the vendor report. The inspectors

determined that the issue of concern remains open as a URI until this causal

assessment has been completed by Entergy and assessed by NRC. (URI 05000247/2016001-06, 23 Emergency Diesel Generator Automatic Voltage

Regulator Failure)

1R18 Plant Modifications (71111.18 - 2 samples)

Permanent Modifications

.1

Control Rod Guide Tube Repairs in Location E-9

a. Inspection Scope

The inspectors evaluated a modification to the reactor vessel upper internals to swap

damaged control rod guide tube in location E-9 with abandoned guide tube in location

D-10. The inspectors verified that the design bases, licensing bases, and performance

capability of the affected systems were not degraded by the modification. In addition,

the inspectors reviewed modification documents associated with the design change,

including evaluation of equivalency and core flow changes, and post-modification

testing. The inspectors also reviewed revisions to the affected drawings and interviewed

refueling and engineering personnel.

b. Findings

No findings were identified.

.2

Core Baffle-Former Bolt EC 64038

a. Inspection Scope

The inspectors reviewed EC 64038, IP2 Reactor Vessel Equivalent Replacement

Baffle-to-Former Bolt. This modification was completed during RFO 2R22 and involved

the replacement of 278 baffle-former bolts out of a total of 832 located in the Unit 2

reactor vessel. Entergy replaced all of the bolts that were potentially degraded as

observed by visual indications of a protruding bolt head or lock bar problem, bolts that

did not pass UT, and bolts inaccessible for UT. Entergy staff also replaced 51 additional

bolts that passed ultrasonic and visual examinations to increase the structural margin of

the baffle-former assembly for future operating cycles.

The inspectors reviewed the equivalency evaluation completed by Entergy staff to install

baffle-former bolts of a different material and configuration than the original bolts. The

inspectors reviewed the associated EC package to determine whether the replacement

bolts form, fit, and function were maintained compared to the original bolts and whether

the change conformed to the design and licensing bases of the baffle-former assembly.

Specifically, this change involved replacing the original baffle-former bolts made of

type 347 stainless steel with bolts made of type 316 stainless steel. The baffle-former

bolt head configuration was also changed from an original internal hex and slot design

(secured with a welded lock bar) to an external hex configuration with an integral locking

cup design. The design change document further evaluated a more gradual fillet

20

geometry between the bolt head and shank intended to reduce the stress concentration

at that transition and provide for improved fatigue resistance.

b. Findings

No findings were identified.

1R19 Post-Maintenance Testing (71111.19 - 8 samples)

a. Inspection Scope

The inspectors reviewed the post-maintenance tests for the maintenance activities listed

below to verify that procedures and test activities ensured system operability and

functional capability. The inspectors reviewed the test procedure to verify that the

procedure adequately tested the safety functions that may have been affected by the

maintenance activity, that the acceptance criteria in the procedure was consistent with

the information in the applicable licensing basis and/or design basis documents, and that

the test results were properly reviewed and accepted and problems were appropriately

documented. The inspectors also walked down the affected job site, observed the

pre-job brief and post-job critique where possible, confirmed work site cleanliness was

maintained, witnessed the test or reviewed test data to verify quality control hold points

were performed and checked, and that results adequately demonstrated restoration of

the affected safety functions.

Unit 2

21 EDG fuel oil transfer pump after planned maintenance on May 5, 2016

Replacement of pressurizer level transmitters LT-459 and LT-460 on May 25, 2016

21 CCW heat exchanger service water outlet weld repair on June 26, 2016

Flux mapping system drive repairs following motor failures on June 28, 2016

Unit 3

Maintenance on service water components associated with the 32 EDG on May 5,

2016 (this sample was part of an in-depth review of the EDG system)

Modification of the 32 EDG space heaters on May 5, 2016 (this sample was part of

an in-depth review of the EDG system)

Maintenance on the 32 EDG air start system on May 6, 2016 (this sample was part

of an in-depth review of the EDG system)

Replacement of failed bistable LC-427K, steam generator 32 low level mismatch trip

interlock, on May 18, 2016

b. Findings

No findings were identified.

21

1R20 Refueling and Other Outage Activities (71111.20 - 2 samples)

.1

Unit 2 RFO 2R22

a. Inspection Scope

The inspectors reviewed the stations work schedule and outage risk plan for the Unit 2

maintenance during RFO 2R22, which was conducted from March 7, 2016, to June 16,

2016. The inspectors reviewed Entergys development and implementation of outage

plans and schedules to verify that risk, industry experience, previous site-specific

problems, and defense-in-depth were considered. During the outage, the inspectors

observed portions of the shutdown and cooldown processes and monitored controls

associated with the following outage activities:

Configuration management, including maintenance of defense-in-depth,

commensurate with the outage plan for the key safety functions and compliance with

the applicable TSs when taking equipment OOS

Implementation of clearance activities and confirmation that tags were properly hung

and that equipment was appropriately configured to safely support the associated

work or testing

Installation and configuration of reactor coolant pressure, level, and temperature

instruments to provide accurate indication and instrument error accounting

Status and configuration of electrical systems and switchyard activities to ensure that

TSs were met

Monitoring of decay heat removal operations

Impact of outage work on the ability of the operators to operate the spent fuel pool

cooling system

Reactor water inventory controls, including flow paths, configurations, alternative

means for inventory additions, and controls to prevent inventory loss

Activities that could affect reactivity

Maintenance of secondary containment as required by TSs

Refueling activities, including fuel handling and fuel receipt inspections

Fatigue management

Tracking of startup prerequisites, walkdown of the primary containment to verify that

debris had not been left which could block the ECCS suction strainers, and startup

and ascension to full power operation

Foreign Object Search and Retrieval for missing baffle bolts and locking tabs

Identification and resolution of problems related to RFO activities

During this outage, Entergy replaced 278 degraded baffle bolts in the Unit 2 reactor

vessel baffle assembly. This emergent project resulted in the extension of the outage

schedule from 30 days to 102 days.

b. Findings

Introduction. The inspectors identified a Green NCV of TS 5.4.1 for Entergys failure to

implement procedure OAP-007, Containment Entry and Egress. Specifically, workers

transiting the inner and outer crane wall sections of containment on June 11, 2016, failed

to maintain at least one (of two) flow channeling gate closed to ensure availability of the

containment sumps to provide suction for the ECCS.

22

Description. On June 11, 2016, in mode 4, in preparation for reactor startup, Entergy

was performing maintenance in containment required prior to mode 3, such as reactor

coolant pump motor balancing and steam flow transmitter troubleshooting. These

activities required scaffolds to be temporarily erected for workers to safely perform

maintenance. While transiting from the inner to outer section of containment, the

inspectors noted that both flow channeling gates were maintained open simultaneously

as workers carried scaffold poles and hardware out of the area.

In the event of a postulated LOCA, Unit 2 relies on two sumps to provide a suction

source for the internal recirculation pumps and residual heat removal pumps,

respectively, after the injection phase of the accident. The sumps have cylindrical

screens with large surface area and small holes to filter small debris and maintain

adequate net positive suction head for the associated pumps. The reactor cavity sump

and large intervening barriers prevent large debris generated from the accident, such as

insulation, from reaching and blocking the recirculation and containment sump screens.

Entergy procedure OAP-007, Containment Entry and Egress, precaution and limitation

step 2.30.2, states, In mode 1, 2, 3, or 4, entry inside the crane wall shall use the

double gate entry point via gates 17 and 23. One gate shall remain shut and secured at

all times to maintain flow channeling and sump operability. Securing gates requires a

padlock or nut and bolt closure from the outside. This will require posting a gate monitor

to allow exit. The inspectors noted, while a gate monitor was posted, both gates were

maintained open during passage and not secured with a padlock or nut and bolt closure.

Upon questioning by the inspectors, Entergy immediately coached the gate monitor and

restored the gates to an acceptable position. Entergy generated CR-IP2-2016-04036 to

address this issue.

Analysis. The inspectors determined that Energys failure to maintain either gate 17 or

gate 23 closed during passage in accordance with OAP-007 was a performance

deficiency. The performance deficiency was more than minor because it is associated

with the configuration control (shutdown equipment lineup) attribute and adversely

affected the Mitigating Systems cornerstone objective to ensure the availability,

reliability, and capability of systems that respond to initiating events to prevent

undesirable consequences (i.e., core damage). The inspectors evaluated the finding in

accordance with IMC 0609, Appendix G, Attachment 1, Exhibit 3, and determined that a

detailed risk evaluation was necessary because the finding represented a loss of system

safety function. A detailed risk assessment was conducted conservatively assuming

complete failure of the recirculation and containment sumps due to the performance

deficiency. Given that Unit 2 was in mode 4, in plant operating state 1, with a late time

window, the at-power simplified plant analysis risk model for large-break LOCAs was

determined to best model the degrade condition and plant response. An exposure time

of one day was assumed. No credit was assumed for the decrease in energy that would

be anticipated in a release during a LOCA in mode 4, nor the corresponding reduction in

debris generation. This was also considered conservative. Utilizing Systems Analysis

Program for Hands-On Integrated Reliability Evaluation, version 8.13, with Indian Point

Unit 2 Simplified Plant Analysis Risk Model, version 8.19, for the assumed conditions,

the change in core damage frequency was determined to be 7E-9. Therefore, this issue

represents a Green finding.

23

This finding had a cross-cutting aspect in the area of Human Performance, Avoid

Complacency, because Entergy did not consider potential undesired consequences of

actions before performing work and implement appropriate error-reduction tools.

Specifically, the work crew did not understand the requirements and potential

consequences prior to commencing work and the gate monitor did not enforce these

requirements to maintain at least one gate locked or pinned closed as required by

OAP-007. [H.12]

Enforcement. Unit 2 TS 5.4.1.a requires that the procedures listed in Attachment A to

Regulatory Guide 1.33, Quality Assurance Program Requirements, Revision 2, be

established and implemented. Attachment A states that instructions should be prepared,

as appropriate, for access to containment and changing modes of operation of the

ECCS. Entergy procedure OAP-007, Containment Entry and Egress, Step 2.30.2,

states, In mode 1, 2, 3, or 4, entry inside the crane wall shall use the double gate entry

point via gates 17 and 23. One gate shall remain shut and secured at all times to

maintain flow channeling and sump operability. Securing gates requires a padlock or nut

and bolt closure from the outside. Contrary to the above, on June 11, 2016, Entergy did

not maintain one gate secured at all times with a padlock or nut and bolt closure.

Entergy entered this issue into the CAP as CR-IP2-2016-04036. Because this violation

was of very low safety significance (Green), and Entergy entered this performance

deficiency into the CAP, the NRC is treating this as a NCV in accordance with

Section 2.3.2.a of the NRC Enforcement Policy. (NCV 05000247/2016002-03, Failure

to Maintain Flow Channeling Gates Closed in Accordance with the Containment

Procedure)

.2

Unit 2 Forced Outage

a. Inspection Scope

Unit 2 conducted a forced outage from June 24 to 27, 2016, in order to complete weld

repairs on a through-wall leak on the service water inlet line to the 21 CCW heat

exchanger. These repairs required shutting down to mode 4 in order to meet the

TS 3.7.7, Component Cooling Water (CCW) System, limiting condition for operations

for CCW operability. While these repairs were being completed, the grid operator

completed repairs to breaker 9 in the offsite switchyard. During the outage, the

inspectors observed portions of the shutdown and cooldown processes and monitored

controls associated with the following outage activities:

Configuration management, including maintenance of defense-in-depth,

commensurate with the outage plan for the key safety functions and compliance with

the applicable TSs when taking equipment OOS

Implementation of clearance activities and confirmation that tags were properly hung

and that equipment was appropriately configured to safely support the associated

work or testing

Status and configuration of electrical systems and switchyard activities to ensure that

TSs were met

Monitoring of decay heat removal operations

Reactor water inventory controls, including flow paths, configurations, alternative

means for inventory additions, and controls to prevent inventory loss

Activities that could affect reactivity

24

Tracking of startup prerequisites

Identification and resolution of problems related to RFO activities

When all repairs had been completed, Entergy restarted Unit 2 on June 27, 2016.

b. Findings

No findings were identified.

1R22 Surveillance Testing (71111.22 - 6 samples)

a. Inspection Scope

The inspectors observed performance of surveillance tests and/or reviewed test data of

selected risk-significant SSCs to assess whether test results satisfied TSs, the UFSAR,

and Entergys procedure requirements. The inspectors verified that test acceptance

criteria were clear, tests demonstrated operational readiness and were consistent with

design documentation, test instrumentation had current calibrations and the range and

accuracy for the application, tests were performed as written, and applicable test

prerequisites were satisfied. Upon test completion, the inspectors considered whether

the test results supported that equipment was capable of performing the required safety

functions. The inspectors reviewed the following surveillance tests:

Unit 2

WO 446385, 21 EDG AVR card inspection, on May 24, 2016

2-PT-Q013 for containment isolation valve 851B (22 safety injection (SI) pump tie to

23 SI pump discharge) on June 6, 2016

2-PT-Q029B quarterly in-service surveillance test for the 22 SI pump on June 6,

2016

Unit 3

3-PT-M079B 32 EDG monthly surveillance on May 30, 2016 (this sample was part of

an in-depth review of the EDG system)

34 steam generator pressure instrument channel check on June 21, 2016

0-SOP-LEAKRATE-001, RCS Leakrate Surveillance, Evaluation and Leak

Identification, beginning on June 28, 2016

b. Findings

No findings were identified.

Cornerstone: Emergency Preparedness

25

1EP6 Drill Evaluation (71114.06 - 1 sample)

Training Observations

a. Inspection Scope

The inspectors evaluated the conduct of Entergys ingestion pathway emergency

preparedness drill on April 19, 2016, to identify any weaknesses and deficiencies in the

classification, notification, and protective action recommendation development activities.

The inspectors observed emergency response operations in the emergency operations

facility to determine whether the event classification, notifications, and protective action

recommendations were performed in accordance with procedures. The inspectors also

attended the facility drill critique to compare inspector observations with those identified

by Entergy staff in order to evaluate Entergys critique and to verify whether the staff was

properly identifying weaknesses and entering them into the CAP.

b. Findings

No findings were identified.

2.

RADIATION SAFETY

Cornerstone: Public Radiation Safety and Occupational Radiation Safety

2RS1 Radiological Hazard Assessment and Exposure Controls (71124.01)

a. Inspection Scope

During May 10-12 and June 13-17, 2016, the inspectors reviewed Entergys

performance in assessing the radiological hazards and exposure control in the

workplace. The inspectors used the requirements in 10 CFR 20, TSs, applicable

industry standards, and procedures required by TSs as criteria for determining

compliance.

Radiological Hazards Control and Work Coverage

The inspectors reviewed:

Ambient radiological conditions during tours of the radiological controlled area,

posted surveys, radiation work permits, adequacy of radiological controls, radiation

protection job coverage, and contamination controls

Controls for highly activated or contaminated materials stored within spent fuel pools

Posting and physical controls for high radiation areas and very high radiation areas

b. Findings

No findings were identified.

26

2RS2 Occupational As Low As Is Reasonably Achievable (ALARA) Planning and Controls

(71124.02)

a. Inspection Scope

During May 10-12 and June 13-17, 2016, the inspectors assessed performance with

respect to maintaining occupational individual and collective radiation exposures ALARA.

The inspectors used the requirements in 10 CFR 20, TSs, applicable industry standards,

and procedures required by TSs as criteria for determining compliance.

Radiological Work Planning

The inspectors reviewed:

ALARA work activity evaluations, exposure estimates, and exposure mitigation

requirements

ALARA work planning, use of dose mitigation features and dose goals

Work planning and the integration of ALARA requirements

b. Findings

No findings were identified.

2RS7 Radiological Environmental Monitoring Program (REMP) (71124.07 - 3 samples)

a. Inspection Scope

The inspectors reviewed the REMP to validate the effectiveness of the radioactive

gaseous and liquid effluent release program and implementation of the groundwater

protection initiative (GPI). The inspectors used the requirements in 10 CFR 20,

40 CFR 190, 10 CFR 50, Appendix I, TSs, offsite dose calculation manual (ODCM),

Nuclear Energy Institute 07-07, and procedures required by TSs as criteria for

determining compliance.

Inspection Planning

The inspectors reviewed Entergys 2014 and 2015 annual radiological environmental

and effluent monitoring reports, REMP program audits, ODCM changes, land use

census, the UFSAR, and inter-laboratory comparison program results.

Site Inspection

The inspectors walked down various thermoluminescent dosimeter and air and water

sampling locations and reviewed associated calibration and maintenance records. The

inspectors observed the sampling of various environmental media as specified in the

ODCM and reviewed any anomalous environmental sampling events including

assessment of any positive radioactivity results. The inspectors reviewed any changes

to the ODCM. The inspectors verified the operability and calibration of the

meteorological tower instruments and meteorological data readouts. The inspectors

reviewed environmental sample laboratory analysis results, laboratory instrument

measurement detection sensitivities, laboratory quality control program audit results, and

27

the inter- and intra-laboratory comparison program results. The inspectors reviewed the

groundwater monitoring program as it applies to selected potential leaking SSCs.

GPI Implementation

The inspectors reviewed groundwater monitoring results, changes to the GPI program

since the last inspection, anomalous results or missed groundwater samples, leakage or

spill events including entries made into the decommissioning files (10 CFR 50.75(g)),

evaluations of surface water discharges, and Entergys evaluation of any positive

groundwater sample results including appropriate stakeholder notifications and effluent

reporting requirements.

Identification and Resolution of Problems

The inspectors evaluated whether problems associated with the REMP were identified at

an appropriate threshold and properly addressed in Entergys CAP.

b. Findings

No findings were identified.

4.

OTHER ACTIVITIES

4OA1 Performance Indicator Verification (71151 - 6 samples)

Initiating Events Performance Indicators

a.

Inspection Scope

The inspectors reviewed Entergys submittals for the following Initiating Events

cornerstone performance indicators for the period April 1, 2015, to March 31, 2016:

Unit 2

Unplanned scrams per 7000 critical hours (IE01)

Unplanned power changes per 7000 critical hours (IE03)

Unplanned scrams with complications (IE04)

Unit 3

Unplanned scrams (IE01)

Unplanned power changes (IE03)

Unplanned scrams with complications (IE04)

To determine the accuracy of the performance indicator data reported during those

periods, inspectors used definitions and guidance contained in Nuclear Energy

Institute 99-02, Regulatory Assessment Performance Indicator Guideline, Revision 7.

The inspectors reviewed Entergys operator narrative logs, maintenance planning

schedules, CRs, event reports, and NRC integrated inspection reports to validate the

28

accuracy of the submittals. There were no unplanned power changes or scrams with

complications during the review period.

b. Findings

No findings were identified.

4OA2 Problem Identification and Resolution (71152 - 4 samples)

.1

Routine Review of Problem Identification and Resolution Activities

a. Inspection Scope

As required by Inspection Procedure 71152, Problem Identification and Resolution, the

inspectors routinely reviewed issues during baseline inspection activities and plant

status reviews to verify that Entergy entered issues into the CAP at an appropriate

threshold, gave adequate attention to timely corrective actions, and identified and

addressed adverse trends. In order to assist with the identification of repetitive

equipment failures and specific human performance issues for follow up, the inspectors

performed a daily screening of items entered into the CAP and periodically attended CR

screening meetings. The inspectors also confirmed, on a sampling basis, that, as

applicable, for identified defects and non-conformances, Entergy performed an

evaluation in accordance with 10 CFR 21.

b. Findings

No findings were identified.

.2

Semi-Annual Trend Review

a. Inspection Scope

The inspectors performed a semi-annual review of site issues, as required by Inspection

Procedure 71152, Problem Identification and Resolution, to identify trends that might

indicate the existence of more significant safety issues. In this review, the inspectors

included repetitive or closely-related issues that may have been documented by Entergy

outside of the CAP, such as trend reports, performance indicators, major equipment

problem lists, system health reports, maintenance rule assessments, and maintenance

or CAP backlogs. The inspectors also reviewed Entergys CAP database for the first

and second quarters of 2016 to assess CRs written in various subject areas (equipment

problems, human performance issues, etc.), as well as individual issues identified during

the NRCs daily CR review (Section 4OA2.1). The inspectors reviewed the Entergy

quarterly trend report for the first quarter of 2016 to verify that Entergy was appropriately

evaluating and trending adverse conditions in accordance with applicable procedures.

b. Findings and Observations

No findings were identified.

The inspectors identified a trend in work being performed that was contrary to written

work instructions and procedures, and work packages had been closed out without

29

documenting the deviation from the work order. While reviewing completed work order

WO 447966 Task 10, Internal Coating Repair for 21 CCW HX, the inspectors found a

note in the work order stating that the internal coating repair to the pipe had not been

done in accordance with the engineering change. The engineering change had been

written when the coating repair was expected to be small, but the actual area that was

recoated was much larger. A larger area of coating increases the impact on the heat

exchanger if the coating were to flake off and block the flow of service water. The work

package was closed and no condition report was written. This performance deficiency is

minor because the coating was applied with procedurally directed quality controls and

the likelihood that it would flake off is very small; and is the same as the original smaller

area specified in the work package. However, the work package was closed without

documenting the deviation and no CR was written.

In another example, the inspectors noted that WO 412920 Task 15 to perform a surge

test on 11 centrifugal air compressor (CENTAC) after overhaul was completed on

December 22, 2015. However, the completion notes and documentation for the task

showed that the test was unable to be performed due to a test equipment problem. The

work package was closed and no CR was written. Subsequently, after being returned to

service, the compressor failed in service due to multiple surging events on January 7,

2016. Troubleshooting under WO 433939 revealed that the motor high load limit had not

been adjusted to account for the increased load due to reduced compressor clearances

introduced by the overhaul. This performance deficiency is screened to minor because

the 11 CENTAC is not a safety-related piece of equipment and would not affect the MC 0609 cornerstone thresholds or other generic criteria. Unit 2 and Unit 3 have dedicated

instrument air compressors that are credited in the FSAR to respond to a loss of

instrument air event. If the 11 CENTAC (located in Unit 1) were to fail, the unit-specific

IACs would automatically start to prevent a loss of instrument air at both Units 2 and 3.

A third recent example of work being performed contrary to written instructions occurred

during 2RFO22 when the inspectors identified that the workers deviated from the

surveillance procedure by demonstrating the installation of the emergency containment

hatch plug without properly inflating the plug seals as directed by the procedure. This

performance deficiency was previously documented in a prior inspection report as non-

cited violation 05000247/05000286/2016001-02, Failure to Adequately Implement Risk

Management Actions for the Containment Key Safety Function.

In all cases, the deviations from written work instructions were directed by Entergy

supervision. In addition, the inspectors noted that Entergy had self-identified similar

observations where work packages or condition reports had been closed without fully

completing the specified actions including CR-IP2-2015-05833, CR-IP2-2016-00103,

CR-IP3-2015-04729, CR-IP3-2016-00072, CR-IP3-2016-00075, and CR-IP3-2015-

04019. These CRs are further examples of work orders that were closed with deviations

that were not documented or resolved. Nuclear Oversight had identified several of these

condition reports. Entergy has taking immediate corrective action in response to these

performance deficiencies.

30

.3

Annual Sample: Maintenance Rule Self-Assessment of Corrective Actions

a. Inspection Scope

The inspectors performed an in-depth review of Entergys corrective actions associated

with self-assessment LO-IP3LO-2015-72, Maintenance Rule (a)(3) Assessment. The

self-assessment was performed to satisfy both the self-assessment criteria in EN-LI-104,

Self-Assessment and Benchmark Process, and the maintenance rule periodic

assessment criteria in EN-DC-207.

The inspectors assessed Entergys problem identification threshold, extent of condition

reviews, and the prioritization and timeliness of Entergy corrective actions to determine

whether Entergy was appropriately identifying, characterizing, and correcting problems

associated with this issue and whether the planned or completed corrective actions were

appropriate. The inspectors compared the actions taken to the requirements of

Entergys CAP and 10 CFR 50, Appendix B. In addition, the inspectors interviewed

engineering personnel to assess the effectiveness of the implemented corrective

actions.

b. Findings and Observations

No findings were identified.

Entergy identified three standard deficiencies during their self-assessment and wrote

CRs to document each one. One of the standard deficiencies was that the maintenance

rule basis documents were not being reviewed at least once every two years as required

by procedure EN-DC-204, Maintenance Rule Scope and Basis. The purpose of this

review was to ensure that the documents were updated if the configuration of the system

changed or if the performance criteria needed to be adjusted. Entergy wrote CR-IP3-

2015-03628 and assigned a corrective action to create work trackers to perform the

basis document reviews. They chose to use work trackers instead of corrective actions

under the CAP because the work had historically been assigned using work trackers.

However, because work trackers do not receive the same priority as corrective actions,

some of the maintenance rule basis documents had still not been reviewed at the time of

this inspection, over a year after the completion of the self-assessment. The inspectors

determined that this was not a more than minor issue because the systems in question

did not show signs of inadequate maintenance.

.4

Annual Sample: Unit 2 Reactor Trip on December 5, 2015

a. Inspection Scope

The inspectors performed an in-depth review of Entergys evaluations and corrective

actions associated with CR-IP2-2015-05484 and the related apparent cause evaluation

for the December 5, 2015, manual reactor trip in response to indications of multiple

dropped control rods caused by the loss of control rod power due to a power supply

failure. Entergy performed an apparent cause evaluation and determined the direct

cause of the event was the loss of motor control center (MCC)-24 due to an internal fault

at the line side leads at cubicle 2H where they connect to the bucket stab assemblies.

The apparent cause was an unanticipated loss of power to the control rod system due to

the degradation of the primary control rod power supply (PS1) which failed to function for

31

more than 10 minutes when the operating alternate power supply (PS2) was

deenergized.

The inspectors assessed Entergys problem identification threshold, problem analysis,

extent of condition reviews, compensatory actions, and the prioritization and timeliness

of Entergy's corrective actions to determine whether Entergy was appropriately

identifying, characterizing, and correcting problems associated with this issue and

whether the planned or completed corrective actions were appropriate. The inspectors

compared the actions taken to the requirements of Entergy's CAP and 10 CFR 50,

Appendix B, Criterion XVI, Corrective Action.

b. Findings and Observations

No findings were identified.

The inspectors found that Entergy took appropriate actions to identify the direct and

apparent cause of the issue. The direct cause of the event was the loss of MCC-24 due

to an internal fault at the line side leads at cubicle 2H where they connect to the bucket

stab assemblies. The apparent cause was an unanticipated loss of power to the control

rod system due to the degradation of the primary control rod PS1, which failed to

function when PS2 was lost. Entergy replaced the degraded rod control PS1; and the

MCC-24 compartments were removed to facilitate inspection and testing of the MCC

bus, control wires, and MCC internal. PS2 was also restored to operation after the fault

was cleared.

The inspector determined that the internal electrical fault that deenergized PS2 and the

prior degradation in PS1 was not within Entergys ability to foresee and prevent.

Therefore, there was no performance deficiency identified. Entergys overall response to

the issue was commensurate with the safety significance, was timely, and the actions

taken and planned were reasonable to resolve the failure of the primary control rod PS1.

.5

Annual Sample: Unexpected Number of Degraded Baffle-Former Bolts Discovered in

the Unit 2 Reactor Pressure Vessel

a. Inspection Scope

The inspectors performed an in-depth review of Entergys root cause evaluation and

corrective actions associated with CR-IP2-2016-02348 for baffle-former (baffle) bolts

found with indications of degradation during the Indian Point Unit 2 RFO 2R22. Entergy

performed ultrasonic examinations of the baffle bolts in accordance with their procedures

as part of a planned activity. After an unexpected number of degraded baffle bolts were

discovered, Entergy staff reported the issue to the NRC as Event Notification 51829

on March 29, 2016, because the as-found number and location of degraded bolts

represented an unanalyzed condition. Entergy staff completed corrective actions to

replace all of the potentially degraded baffle bolts on Unit 2. Entergy staff further

replaced a population of additional bolts that exhibited no indications of degradation and

performed an evaluation to determine the potential for baffle bolt failures at Unit 3.

The baffle-former bolts help secure vertical plates (also referred to as baffle plates)

inside the reactor vessel, which then forms a structure surrounding the reactor fuel

assemblies to orient the fuel and to direct coolant flow through the core. A sufficient

32

number of baffle bolts are required to remain intact to secure the baffle plates in place so

as to not affect control rod insertion or impede emergency core cooling flow during

postulated accident conditions. Bolt heads that separate and are no longer held in place

by bolt lock-tabs can also become a loose parts concern.

The inspectors determined whether Entergys acceptable baffle bolt pattern analysis for

Unit 2 was completed in accordance with the NRC-approved methodology and provided

appropriate structural margin for the next cycle of operation to ensure the Unit 2 baffle

plates will remain in place during both normal operation and limiting postulated accident

conditions. The inspectors further determined whether Entergys evaluations of the

baffle bolts installed in Indian Point Unit 3 were technically sufficient to conclude the

Unit 3 baffle assembly will perform as intended until the next planned RFO, at which time

Entergy plans to examine the bolts. The inspectors reviewed Entergys procedures for

determining the functionality and operability of degraded SSC as they relate to Unit 3.

The inspectors further interviewed Entergy engineering personnel and contractor staff to

discuss the results of Entergys technical evaluations and to assess the effectiveness of

the implemented and planned corrective actions.

The inspectors assessed Entergys problem identification threshold, cause analyses,

extent of condition, compensatory actions, and the prioritization and timeliness of

Entergys corrective actions to determine whether Entergy staff were properly identifying,

characterizing, and correcting problems associated with this issue and whether the

planned or completed corrective actions were appropriate. The inspectors compared the

actions taken to Entergys CAP, operability determination process, and the requirements

of 10 CFR 50, Appendix B. The inspectors observed portions of baffle bolt replacement

activities at Unit 2 and reviewed the final visual examination of the baffle bolts and plates

once the work was completed.

b. Findings and Observations

One Green NCV was identified and documented in Section 1R15 of this report.

The NRC responded to the initial discovery of an unexpected number of baffle bolts

found degraded at Indian Point Unit 2 by implementing a comprehensive inspection plan

consisting of various baseline inspection samples to assess the extent of the issue and

to determine the necessary NRC actions. A follow-up inservice inspection sample

(Refer to Section 1R08) was conducted to review the capability of the non-destructive

examination techniques, evaluate the UT results, and observe a portion of bolt

replacement activities on-site. A permanent modification sample (Refer to Section

1R18) was conducted to review the design change package and evaluations associated

with the new, replacement baffle bolts. The NRC resident inspectors reviewed Entergys

foreign material controls and loose parts analysis (Refer to Section 1R20) to address the

potential for missing bolt heads and concluded it would not impact safe operation of the

plant.

NRC Region I based inspectors accompanied by an expert from the NRC Office of

Nuclear Reactor Regulation completed an annual problem identification and resolution

inspection, documented in this section of the report, to verify that Entergys evaluations

and corrective actions to replace Unit 2 baffle bolts were completed in accordance with

an NRC approved methodology to support a conclusion that the Unit 2 baffle assembly

meets the plant design basis. The inspectors also determined the adequacy of

Entergys evaluations completed to determine there is a reasonable expectation that the

33

Unit 3 baffle assembly will perform as intended during the current operating cycle. The

results of this review are discussed herein and in Section 1R15 of this report.

Entergy staff determined the cause of the degraded baffle bolts was primarily due to

IASCC in combination with increased fatigue loading on the baffle plates. This cause

determination was based on industry operating experience related to baffle-former bolt

failure in both foreign and domestic plants. IASCC is a cracking mechanism that occurs

over a long period of time when susceptible metals are exposed to neutron radiation

from the reactor core and stresses as part of normal design and operation. Entergy staff

concluded that failure of a critical number of bolts in a localized area subsequently

imposed increased loading on adjacent bolts, which propagated failures and generated

the moderate clustered pattern observed in the examination results. No other

contributing causes were identified.

The inspectors reviewed Entergys root cause evaluation and the supporting operating

experience related to baffle bolt failures at other plants. The inspectors determined that

there is documented evidence in the existing technical literature (including materials

testing of bolts from other plants) and operating experience to conclude that the likely

cause is IASCC; however, the inspectors found that Entergy staff did not define the

cause of the fatigue failure mechanism. The inspectors noted that Entergy staff sent a

sample of baffle bolts removed from the reactor pressure vessel to a metallurgical

laboratory for detailed failure analysis and materials property testing. Entergy indicated

their plans to use the results of the laboratory testing to confirm the likely root cause.

The inspectors concluded that Entergy staff conducted an appropriate review to identify

the likely causes of the degraded baffle bolts and noted that further test results will be

used to confirm these causes.

Following identification of the degraded baffle bolts on Unit 2, Entergys immediate

corrective action was to analyze the as-found condition and begin replacing bolts that

either had visual indications of bolt failure (protruding bolt head for example), did not

pass UT examination, or were not accessible for UT examination. The as-found number

and pattern of these bolts exceeded the acceptance criteria in the plants analysis that

was prepared in advance of the baffle bolt examinations; therefore, Entergy reported this

discovery to the NRC as an unanalyzed condition. Entergy staff completed corrective

actions to replace all of the 227 potentially degraded baffle bolts, plus an additional 51

bolts for increased structural integrity, for a total of 278 bolts. The inspectors noted the

51 additional bolts were installed in strategic locations to prevent clustering of potential

bolt failures during the next operating cycle.

The inspectors determined that Entergy staff performed an acceptable bolt pattern

analysis that evaluated the replacement bolt pattern for Unit 2 and modeled the potential

for future bolt failures. The inspectors found the results of the analysis accounted for a

conservative failure rate of bolts and provided appropriate margin for one cycle of

operation. The inspectors verified that Entergys methodology for its acceptable bolt

pattern analyses, including its determination of margin, was consistent with the NRC-

approved methodology in topical report WCAP-15029-NP-A (ML15222A882). The

inspectors determined that Entergy staff tracked corrective actions to re-examine the

Unit 2 baffle bolts during the next planned RFO. The inspectors noted the new baffle

bolts were made of a material with improved resistance to IASCC and included an

improved design to reduce the stresses at the head to shank transition, both of which

are enhancements compared to the original bolts.

34

As part of an extent of condition assessment, Entergy entered CR-IP3-2016-01035 in its

CAP to evaluate the potential for degraded baffle bolts on Unit 3. Entergy operators

performed an IOD and concluded that the baffle assembly was operable. Entergy staff

performed a subsequent extent of condition review that concluded Unit 3 would

experience less baffle bolt degradation than Unit 2 based on several plant factors.

Entergy also conducted sensitivity analyses to show acceptable bounding conditions in

the event of bolt failures. The inspectors reviewed Entergys evaluations and noted that

Entergy staff concluded there was not a degraded condition at Unit 3. In consideration

of the guidance in their operability procedure and operating experience from Unit 2 and

other plants, the NRC issued an NCV in this report because Entergy did not perform an

operability evaluation for Unit 3 as a follow-up to the immediate determination for the

potential impact on supported systems controlled by the TS (Refer to Section 1R15).

As a corrective action, Entergy staff performed an operability evaluation and

demonstrated that the Unit 3 baffle former assembly remained operable. The inspectors

concluded that this supplemental evaluation provided appropriate technical justification

for the continued operation of Unit 3 until the next RFO in spring 2017, at which time

Entergy plans to examine the baffle bolts. Entergy also implemented a corrective action

as part of an enhancement to plant operations to monitor the RCS for any signs of fuel

leakage, which could be an indicator of baffle bolt failures.

The inspectors reviewed Westinghouse Nuclear Safety Advisory Letter NSAL-16-1,

which discussed the results of recent baffle-former bolt inspections and provided

Westinghouses recommendations on this issue. The letter described the plants as most

susceptible (i.e. Tier 1a) to this degradation as Westinghouse 4-loop reactors limited to

those with a down-flow configuration and using Type 347 stainless steel bolts. The

inspectors noted the recommendation was to complete UT volumetric examination of the

baffle bolts at the next scheduled RFO, and that Entergy had already planned this action

for Unit 3. Entergy also planned a long-term corrective action to convert Units 2 and 3

from a down-flow baffle configuration to an up-flow configuration, which would

significantly reduce the load on baffle-former bolts and provide for increased structural

margin of the baffle-former assembly. The inspectors determined Entergys overall

response to the issue was commensurate with the safety significance, was timely, and

included appropriate compensatory actions. The inspectors concluded that the actions

completed and planned were reasonable to address the ongoing aging management of

baffle bolts.

4OA3 Follow Up of Events and Notices of Enforcement Discretion (71153 - 5 samples)

.1

Plant Events

a. Inspection Scope

For the plant events listed below, the inspectors reviewed and/or observed plant

parameters, reviewed personnel performance, and evaluated performance of mitigating

systems. The inspectors communicated the plant events to appropriate regional

personnel, and compared the event details with criteria contained in IMC 0309, Reactive

Inspection Decision Basis for Reactors, for consideration of potential reactive inspection

activities. As applicable, the inspectors verified that Entergy made appropriate

emergency classification assessments and properly reported the event in accordance

with 10 CFR 50.72 and 50.73. The inspectors reviewed Entergys follow-up actions

35

related to the events to assure that Entergy implemented appropriate corrective actions

commensurate with their safety significance.

Unit 2

Turbine trip occurred while synchronizing Unit 2 to the grid on June 15, 2016

Shutdown required by TS for repairs to a leak on the 21 CCW heat exchanger

service water inlet on June 23, 2016

Unit 3

Rapid power reduction from 100 percent to 45 percent power in response to a loss of

both heater drain pumps on May 26, 2016

b. Findings

No findings were identified.

.2

(Closed) Licensee Event Report (LER) 05000247/2015-003-00: Manual Reactor Trip

Due to Indications of Multiple Dropped Control Rods Caused by Loss of Control Rod

Power Due to a Power Supply Failure

The inspectors reviewed Entergys actions and reportability criteria associated with LER 05000247/2015-003-00, which was submitted to the NRC on February 3, 2016. On

December 5, 2015, control room operators initiated a manual reactor trip after observing

indications consistent with multiple dropped control rods following an alarm for the trip of

MCC-24/24A. No control rod indication was available due to MCC-24 being faulted and

de-energized. The direct cause of the event was the loss of MCC-24 due to an internal

fault at the line sides leads at cubicle 2H where they connect to the bucket stab

assemblies. The apparent cause was an unanticipated loss of power to the control rod

system due to the degradation of the primary control rod PS1 which failed to function

when the operating PS2 was lost. The inspectors determined that both the unexpected

failure of PS2 and the internal fault in PS1 was not within Entergys ability to foresee and

prevent and was not a performance deficiency. The inspectors reviewed the LER, the

associated apparent cause evaluation analysis, and interviewed Entergy staff. This LER

is closed.

.3

(Closed) LER 05000247/2016-003-00: TS Prohibited Condition Due to an Inoperable 21

MBFP Discharge Valve for Greater Than the TS Allowed Outage Time

The inspectors reviewed Entergys actions and reportability criteria associated with LER 05000247/2016-003-00, which was submitted to the NRC on May 6, 2016. On March 7,

2016, during the shutdown to enter 2RFO22, the control switch for the 21 MBFP was

tripped from the control room but the MBFP discharge valve BFD-2-21 failed to fully

close as designed. The MBFP discharge valve was declared inoperable and TS 3.7.3

Condition C was entered. The MFD-2-21 isolation valve was then manually closed. The

direct cause of the failure to close the MBFP discharge valve BFD-2-21 was the motor

operated valves (MOVs) close torque switch contact finger out of position. The

apparent cause was that the MOV preventative maintenance procedure lacked the level

of detail and direction due to an unrecognized susceptibility associated with the

orientation of the close torque switch contact finger bracket opening and spreading of

36

the U shape bracket. The downward arrangement made it easier for the torque switch

contact finger to move out with spreading of the U shaped contact holder. The

inspectors reviewed the LER, the associated apparent cause evaluation analysis, and

interviewed Entergy staff. This LER is closed.

Introduction. The inspectors identified a Green NCV of 10 CFR 50.65(b)(1) for Entergys

failure to include a function of a safety-related system within the scope of the

maintenance rule program. Specifically, Entergy failed to include the feedwater isolation

function performed by the MBFP discharge valves, MBFPs, and feedwater regulating

valves and feedwater isolation valves which are required to remain functional during and

following a design basis event to mitigate the consequences of an accident, within the

scope of the maintenance rule monitoring program.

Description. On March 7, 2016, during an RFO, the control switch for the 21 MBFP was

positioned to trip and the 21 MBFP tripped as designed, but the MBFP discharge valve

BFD-2-21 failed to fully close. Entergy declared MBFP discharge valve BFD-2-21

inoperable and entered TS 3.7.3 Condition C. After troubleshooting, Entergy determined

the MOV close torque switch contact finger was out of position within the contact holder.

The misalignment allowed the contact finger to move out of the proper position causing

the MOV BFD-2-21 to fail to close. This is the same failure mechanism which caused

MOV BFD-2-21 to fail to close in 2010 which is referenced in CR-IP2-2010-07013. On

December 5, 2015, the 21 MBFP failed to trip and required closure of the steam

admission valves to secure it. This failure occurred because of contaminated control oil

that prevented the solenoid valves from operating.

The inspectors reviewed Entergys maintenance rule basis documents and identified the

feedwater isolation function was not properly included in the maintenance rule

monitoring program as required by 10 CFR 50.65(b)(1). The basis document for the

feedwater system did identify the need to monitor the feedwater isolation function under

the maintenance rule and stated that it would be monitored as a part of the vapor

containment supersystem. However, the basis document for the vapor containment

supersystem does not include the feedwater isolation components within the system

boundaries. As a result, when component failures occurred which affected the

feedwater isolation function, they were not reviewed to determine if they were

maintenance rule functional failures; and Entergy was unable to identify that the

performance of the main feedwater isolation equipment was not effectively controlled

through preventative maintenance. Entergy entered this issue into the CAP as

CR-IP2-2016-03963 and initiated actions to include the MBFP discharge valves into the

maintenance rule program.

Analysis. The failure to appropriately scope the safety-related feedwater isolation

function within the maintenance rule program was a performance deficiency. This

finding is more than minor because it is associated with the SSC and barrier

performance attribute of the Barrier Integrity cornerstone and affected the cornerstone

objective to provide reasonable assurance that physical design barriers protect the

public from radionuclide releases caused by accidents or events. Specifically, the failure

to properly scope the feedwater isolation function prevented Entergy from identifying that

equipment reliability was no longer effectively controlled through preventative

maintenance. Additionally, this issue is similar to example 7.d described in IMC 0612,

Appendix E, Examples of Minor Issues, dated August 11, 2009. In accordance with

IMC 0609.04, Initial Characterization of Findings, and Exhibit 2 of IMC 0609, Appendix

37

A, The Significance Determination Process for Findings At-Power, issued June 19,

2012, the inspectors determined that the finding was of very low safety significance

(Green) because the finding did not represent an actual open pathway in the physical

integrity of reactor containment, containment isolation system, and heat removal

components. There are redundant methods of feedwater isolation. They include

tripping the MBFPs and closing the MBFP discharge valves, closing the main feedwater

regulating valves and low flow bypass valves, and closing the main feedwater isolation

valves. On both December 5, 2015, and March 7, 2016, the main feedwater regulating

valves and isolation valves were functional; so there was no loss of the ability to isolate

feedwater to mitigate accident and transient conditions.

This finding does not have a cross-cutting aspect, since the failure to scope this

equipment into the maintenance rule program was not recognized when Entergy

combined the maintenance rule basis documents for Units 2 and 3 in 2012 and as a

result, is not indicative of current licensee performance.

Enforcement. 10 CFR 50.65(b)(1) requires, in part, that the holders of an operating

license shall include within the scope of the monitoring program, specified in

10 CFR 50.65(a)(1), SSCs that are relied upon to remain functional during and following

design basis events. Contrary to the above, since the combined maintenance rule

scoping for Units 2 and 3 in 2012, Entergy failed to include within the scope of the

monitoring program specified in 10 CFR 50.65(a)(1), the safety-related MBFP discharge

valves. These SSCs are relied upon during and after design basis events to mitigate the

consequences of a feedwater line break accident inside containment. Entergys

corrective action included entering this issue into the corrective action program.

Because the violation was of very low safety significance (Green) and Entergy entered

this issue into their CAP as CR-IP2-2016-03963, this violation is being treated as an

NCV, consistent with Section 2.3.2.a of the NRC Enforcement Policy.

(NCV 05000247/2016002-04, Failure to Scope Safety-Related Main Boiler Feedwater

Pump Discharge Valves into the Maintenance Rule Program)

4OA5 Other Activities

.1

Groundwater Contamination

a. Inspection Scope

On February 5, 2016, Entergy notified the NRC of a significant increase in groundwater

tritium levels measured at three monitoring wells (MWs) (MW-30, MW-31, and MW-32)

located near the Unit 2 fuel storage building. These samples were drawn on

January 26 to 27, 2016, and analyzed and confirmed on February 2 to 4, 2016. The

highest concentration was detected at MW-32, which increased from 12,000 pCi/l on

January 11, 2016, to 8,100,000 pCi/l on January 26, 2016, and subsequently up to

14,800,000 pCi/l on February 4, 2016. This increased tritium concentration event was

documented by Entergy in CR-IP2-2016-00564 which documents its investigation of this

event including a root cause evaluation. The inspectors reviewed Entergys root cause

evaluation for this event during this inspection period as well as recent groundwater

monitoring results.

38

b. Findings and Observations

No findings were identified.

Update to URI 05000247/2016001-07, January 2016 Groundwater Contamination

Entergy continues to conduct weekly, biweekly, and monthly groundwater sampling of

MWs at the initial site of groundwater contamination and at downstream wells towards

the Hudson River. For the initial three MWs (MW-30, MW-31, and MW-32), the general

trend in tritium activity has been downward, with periodic increases seen in some weekly

samples. The downstream MWs located in the Unit 2 switchyard (especially MW-55)

showed an initial increase in activity up to 117,000 pCi/l, but the activity at that location

has plateaued at the end of the reporting period.

Entergy documented its investigation of this event as root cause evaluation for

CR-IP2-2016-00564. The inspectors reviewed Entergys root cause evaluation for this

event. Entergy concluded that the source of the groundwater contamination was from

the reject water of a temporary reverse osmosis unit used to process water from the

refueling water storage tank at Unit 2 in preparation for RFO 2R22. Although this

analysis documents a number of issues identified during the operation of the contractor

reverse osmosis unit, which is believed to be the source of the groundwater

contamination, one of two leakage paths to groundwater have still not been established.

The established pathway involves leakage from two cut drain lines located above the

floor on the 35-foot elevation of the PAB. Further investigation by Entergy following the

conclusion of the Unit 2 RFO 2R22 must be conducted to verify the second pathway to

groundwater via the floor of the fuel storage building truck bay.

Entergys long-term corrective action for reducing tritium levels in the groundwater is the

same as previously identified for the March 2014 tritium spike (CR-IP2-2015-03806), the

start-up and operation of recovery well (RW)-1. Following installation of equipment and

system testing, full operation of the RW system is expected later this year. This system

will allow for the collection of tritiated groundwater in the vicinity of Unit 2 to be returned

inside the Unit 2 PAB for processing. The NRC will be conducting an inspection in

August 2016 to review the testing plan and results of the RW-1 tests. This inspection

will include a specialist region-based inspector, and a staff hydrogeologist.

The NRCs continuing assessment of the safety significance of this event focused on

validating the safety impact of dose to the public from the release of tritium to the site

groundwater, and ultimately to the Hudson River. The NRC verified that Entergys

bounding public dose calculations on the groundwater contamination leak was

sufficiently conservative and a maximum worst case scenario would result in a dose of

0.000112 millirem per year, which represents a very small fraction of the allowable dose

(liquid effluent dose objective of 3 millirem per year). This low value is due to

groundwater at Indian Point not being a source of any drinking water. There are no

drinking water wells on the Indian Point site, groundwater flow from the site is to the

Hudson River and not to any near site drinking water wells, and the Hudson River has

no downstream drinking water intakes as it is brackish water. Pathways to the public are

therefore limited to the consumption of fish and river invertebrates. The inspection

determined that there is no safety impact to the public as a result of this groundwater

contamination event. (URI 05000247/2016001-07, January 2016 Groundwater

Contamination)

39

.2

Institute of Nuclear Power Operations (INPO) Report Review

a. Inspection Scope

The inspectors also reviewed the final report for the INPO equipment reliability scram

review visit that was conducted to review the scrams that occurred over the past two

years, conducted in June 2016. The inspectors reviewed the report to ensure that any

issues identified were consistent with NRC perspectives of Entergy performance and to

determine if INPO identified any significant safety issues that required further NRC

follow-up.

b. Findings

No findings were identified.

4OA6 Meetings, Including Exit

On August 4, 2016, the inspectors presented the inspection results to Mr. Larry Coyle,

Site Vice President, and other members of Entergy. Based on additional information

provided, the inspectors conducted an updated exit meeting on August 30, 2016 with

John Kirkpatrick, Plant Operations General Manager and other members of Entergy.

The inspectors verified that no proprietary information was retained by the inspectors or

documented in this report.

ATTACHMENT: SUPPLEMENTARY INFORMATION

A-1

Attachment

SUPPLEMENTARY INFORMATION

KEY POINTS OF CONTACT

Entergy Personnel

A. Vitale, Site Vice President

J. Kirkpatrick, Plant Operations General Manager

R. Alexander, Unit 2 Shift Manager

R. Andersen, Maintenance Instrumentation and Controls Superintendent

N. Azevedo, Engineering Supervisor

J. Baker, Shift Manager

S. Bianco, Operations Fire Marshal

K. Brooks, Assistant Operations Manager

R. Burroni, Engineering Director

T. Chan, Engineering Supervisor

C. Chapin, Training Superintendent

D. Dewey, Assistant Operations Manager

J. Dignam, Unit 3 Control Room Supervisor

R. Dolansky, Inservice Inspection Program Manager

W. Durr, Outage Control Center Manager

R. Drake, Engineering Supervisor

K. Elliott, Fire Protection Engineer

J. Ferrick, Regulatory and Performance Improvement Director

L. Frink, Radiation Protection Supervisor

D. Gagnon, Security Manager

L. Glander, Emergency Preparedness Manager

D. Gray, Radiological Environmental Manager

J. Johnson, Unit 2 Control Room Supervisor

M. Johnson, Unit 3 Shift Manager

M. Khadabux, Instrumentation and Controls Supervisor

F. Kich, Performance Improvement Manager

M. Lewis, Unit 3 Assistant Operations Manager

N. Lizzo, Training Manager

S. McAllister, Baffle Bolt Replacement Project Manager

M. McCarthy, Unit 3 Control Room Supervisor

B. McCarthy, Operations Manager

F. Mitchell, Radiation Protection Manager

E. Mullek, Maintenance Manager

S. Stevens, Radiation Protection Operations Superintendent

B. Sullivan, Training Superintendent

J. Taylor, Unit 3 Shift Manager

M. Tesoriero, Outage Control Center Manager

M. Troy, Nuclear Oversight Manager

R. Walpole, Regulatory Assurance Manager

A. Zastrow, Assistant Operations Manager

A-2

LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED

Opened 05000247/2016002-01

URI

CVCS Goal Monitoring Under the Maintenance

Rule (Section 1R12)

Opened/Closed 05000286/2016002-02

NCV

Failure to Follow Operability Determination

Procedure for Unit 3 Baffle-Former Bolts

(Section 1R15)05000247/2016002-03

NCV

Failure to Maintain Flow Channeling Gates Closed

in Accordance with the Containment Procedure

(Section 1R20)05000247/2016002-04

NCV

Failure to Scope Safety-Related Main Boiler

Feedwater Pump Discharge Valves into the

Maintenance Rule Program (Section 4OA3)

Closed

05000247/2015-003-00

LER

Manual Reactor Trip due to Indications of Multiple

Dropped Control Rods Caused by Loss of Control

Rod Power Due to a Power Supply Failure

(Section 4OA3)

05000247/2016-003-00

LER

Technical Specification Prohibited Condition

Due to an Inoperable 21 Main Boiler Feedwater

Pump Discharge Valve for Greater Than the TS

Allowed Outage Time (Section 4OA3)

Discussed 05000247/2016001-01

URI

Baffle-Former Bolts with Identified Anomalies

(Section 1R08)05000247/2016001-06

URI

Emergency Diesel Generator Automatic Voltage

Regulator Failure (Section 1R15)05000247/2016001-07

URI

January 2016 Groundwater Contamination

Section (Section 4OA5)

A-3

LIST OF DOCUMENTS REVIEWED

Common Documents Used

Indian Point Unit 2 and Unit 3, UFSARs

Indian Point Unit 2 and Unit 3, Individual Plant Examinations

Indian Point Unit 2 and Unit 3, Individual Plant Examination of External Events

Indian Point Unit 2 and Unit 3, TSs and Bases

Indian Point Unit 2 and Unit 3, Technical Requirements Manuals

Indian Point Unit 2 and Unit 3, Control Room Narrative Logs

Indian Point Unit 2 and Unit 3, Plans of the Day

Section 1R04: Equipment Alignment

Procedures

2-COL-4.2.1, Residual Heat Removal System, Revision 30

2-COL-4.3.1, Spent Fuel Pit Cooling, Revision 10

2-COL-24.1.1, Service Water System, Revision 50

3-COL-EL-005, Diesel Generators, Revision 37

OAP-019, Component Verification and System Status Control, Revision 7

OAP-044, Plant Labeling Program, Revision 3

Condition Reports (CR-IP2)

2016-01311

2016-01505

2016-01761

2016-02330

2016-02428

2016-02470

Condition Reports (CR-IP3)

2016-01382

2016-01810

Drawings

209762, Flow Diagram Service Water System Nuclear Steam Supply Plant, Revision 75

227781, Flow Diagram Auxiliary Coolant System, Revision 22

9321-2720, Auxiliary Coolant System, Sheet 2, Revision 22

Miscellaneous

IP3-DBD-308, CCW System, Revision 3

Section 1R05: Fire Protection

Procedures

EN-MA-133, Control of Scaffolding, Revision 12

Condition Reports (CR-IP2)

2016-04148

Condition Reports (CR-IP3)

2016-01272

Miscellaneous

PFP-203, Containment Building, 95-Foot Elevation (Fire Zone 86A), Revision 15

PFP-204, General Floor Plan, PAB, 15-Foot Elevation, Revision 0

PFP-209, Component Cooling Pump Room, PAB, 68-Foot Elevation, Revision 0

PFP-211, General Floor Plan, PAB, 80-Foot Elevation, Revision 14

PFP-351, 480V Switchgear Room, Revision 15

A-4

Section 1R07: Heat Sink Performance

Procedures

0-HTX-405-EDG, EDG Lube Oil and Jacket Water Heat Exchanger Maintenance, Revision 4

Condition Reports (CR-IP3)

2010-02900

2011-03594

2011-03596

2011-03961

2012-02071

2012-03912

2013-02338

2013-02695

2013-03009

2014-00957

2014-01239

2014-03158

2014-03175

2015-00031

2015-00599

2015-02848

2015-05209

2015-05526

2016-00886

2016-00895

2016-00899

Maintenance Orders/Work Orders

WO 52489888

WO 52626563

Miscellaneous

SEP-SW-IPC-001, Indian Point Energy Center NRC Generic Letter 89-13 Service Water

Program, Revision 0

Section 1R08: Inservice Inspection Activities

Procedures

GBRA-104-659, Collection of Protocols for Baffle Bolt Replacement, Revision C

GBRA-175-115, Field Service Procedure for Baffle Bolt Replacement, Revision 3

WDI-STD-088, Underwater Remote Visual Examination of Reactor Vessel Internals,

Revision 13

WDI-STD-1073, Ultrasonic Test Procedure for the Inspection of Internal Hex Head

Baffle-Former Bolts with Welded Lock Bars, Revision 4

Condition Reports (CR-IP2)

2016-02081

Maintenance Orders/Work Orders

442412-13

Miscellaneous

Indian Point Unit 2 Baffle Bolt Ultrasonic Examination Expanded Analysis Report, dated

April 28, 2016

IP2 Reactor Vessel Visual Examination Report, dated May 2006

Loose Parts Inventory Log for Baffle Bolt Replacements, dated May 24, 2016

MRP-227-A, Materials Reliability Program: Pressurized Water Reactor Internals Inspection and

Evaluation Guidelines (ML120170453)

MRP-228, Materials Reliability Program: Inspection Standard for PWR Internals - 2012 Update,

Revision 1

SEP-ISI-IP2-001, IP2 Fourth Ten-Year Interval Inservice Inspection (ISI)/Containment Inservice

Inspection (CISI) Program Plan, Revision 2

WDI-PJF-1315504-EPP-001, Indian Point Nuclear Power Plant MRP-227-A Reactor Vessel

Internals Examination Program Plan, Revision 0

WDI-PJF-1315505-FSR-001, Indian Point Unit 2 2R22 MRP-227-A Baffle-Former Bolt

Ultrasonic Inspections Field Service Report, dated March 29, 2016

WDI-TJ-1100, Technical Justification for the Ultrasonic Inspection of Baffle-Former Bolts for

Indian Point Units 2 and 3, Revision 1

A-5

Section 1R11: Licensed Operator Requalification Program

Procedures

2-AOP-480V-1, Loss of Normal Power to Any 480V Vital Bus, Revision 8

2-AOP-RCP-1, Reactor Coolant Pump Malfunction, Revision 14

2-AOP-TURB-1, Main Turbine Trip without a Reactor Trip, Revision 5

2-E-0, Reactor Trip or Safety Injection, Revision 7

2-FR-H.1, Response to Loss of Secondary Heat Sink, Revision 11

2-POP-1.2, Reactor Startup, Revision 59

2-SOP-26.4, Turbine Generator Startup, Synchronizing, Voltage Control and Shutdown,

Revision 62

3-AOP-480V-1, Loss of Normal Power to Any Safeguards Bus, Revision 7

3-AOP-CVCS-1, Chemical and Volume Control System Malfunction, Revision 8

3-AOP-FW-1, Loss of Feedwater, Revision 8

3-AOP-INST-1, Instrument/Controller Failures, Revision 11

3-E-0, Reactor Trip or Safety Injection, Revision 6

3-E-1, Loss of Reactor or Secondary Coolant, Revision 4

3-FR-C.2, Response to Degraded Core Cooling, Revision 3

Condition Reports (CR-IP2)

2016-03946

2016-04162

2016-04164

2016-04165

2016-04169

2016-04178

Condition Reports (CR-IP3)

2016-01087

2016-01092

2016-01098

2016-01336

Miscellaneous

13SX-LOR-SES026, Licensed Operator Requalification Program Scenario

Emergency Action Level Table, Revision 15.2

LRQ-SES-04, IPEC Simulator Evaluated Scenario, Revision 6

Section 1R12: Maintenance Effectiveness

Procedures

CEP-NDE-0640, Non-Section XI Liquid Penetrant Examination, Revision 9

CEP-WP-WIIR-1, Attachment 5.1, Inprocess Inspections for Installation and Replacement

Welds Located Inside the ASME Section XI Boundary, Revision 3

EN-DC-206, Maintenance Rule (a)(1) Process, Revision 3

Condition Reports (CR-IP2)

2010-00864

2013-03130

2014-00162

2014-00185

2014-01144

2014-02184

2015-00278

2016-01260

2016-01430

2016-01500

Condition Reports (CR-IP3)

2012-03836

2013-04758

2015-01396

2015-03404

2015-03653

2015-04053

2015-04162

2015-04184

2015-04539

2015-05316

2015-05384

2015-05729

A-6

2016-00098

2016-00653

2016-00723

2016-01189

2016-01227

2016-01274

2016-01313

2016-01531

2016-01536

2016-01543

2016-02432

Maintenance Orders/Work Orders

WO 00397793

WO 00408019

WO 00414886

WO 00416091

WO 00421841

WO 00429532

WO 00429532

WO 00431497

WO 00446165

WO 00447042

WO 00447966

WO 52602429

WO 52621178

Miscellaneous

EC 65389, 21 CCW HX Leak Repair: Service Water Inlet Nozzle - Elbow Weld Configuration

Change

IPEC Maintenance Rule Basis Document - Chemical and Volume Control System, Revision 0

PQR 913, 134 F42 MN-GTAW ASME IX Welding Procedure Qualification Record, Revision 0

System Health Report, Unit 3, EDG, Q1-2016

Weld Map Number 447966-20-01, Revision 0

WPS 134 F42, MN-GTAW, ASME Section IX Welding Procedure Specification, Revision 0

Section 1R13: Maintenance Risk Assessments and Emergent Work Control

Procedures

EN-OP-119, Protected Equipment, Revision 8

IP-SMM-OU-104, Attachment 9.1, Shiftly Outage Shutdown Safety Assessments, Revision 15

IP-SMM-OU-104, Attachment 9.2, Shiftly Outage Shutdown Safety Assessment Guidelines,

Revision 15

Condition Reports (CR-IP2)

2016-04141

Condition Reports (CR-IP3)

2016-01545

Miscellaneous

EOOS Risk Assessment Software Tool

Section 1R15: Operability Determinations and Functionality Assessments

Procedures

2-PC-R3-1, Pressurizer Level Transmitters, Revision 10

3-ARP-010, Metal Impact Monitoring System, Page 10, Revision 32

3-SOP-RCS-016, Operation of the Metal Impact Monitoring System, Revision 8

EN-OP-104, Operability Determination Process, Revision 10

Condition Reports (CR-IP2)

2016-2221

2016-2356

2016-2961

2016-3345

2016-3418

2016-3660

2016-3636

2016-3784

2016-3806

2016-3818

2016-4085

Condition Reports (CR-IP3)

2014-01670

2015-03468

A-7

Maintenance Orders/Work Orders

WO 00327574

WO 00425980

WO 52571030

Miscellaneous

EN-LI-100, Attachment 9.1, Change Channel Check Comparison Criteria/2-PT-M100,

2-PT-D001, Revision 0

Section 1R18: Plant Modifications

Drawings

10073E87-001, Indian Point Unit 2 Baffle Bolt Replacement - Core Barrel and Baffle Assembly

Elevation, Revision 0

10111D06, Indian Point Unit 2 Baffle Bolt Replacement - Replacement Baffle Bolt .625

and .750, Revision 0

Miscellaneous

EC 64308, IP2 Reactor Vessel Equivalent Replacement Baffle-to-Former Bolt, Revision 0

Process Applicability Determination Form for EC 64308, dated April 21, 2016

WCAP-18136-P, Replacement Type 316 Cold-Worked Baffle-Former Bolt Qualification for

Indian Point Unit 2, Revision 0

Section 1R19: Post-Maintenance Testing

Procedures

3-PT-M079B, 32 EDG Functional Test, Revision 52

2-PC-Q109-4, Recalibration of NIS and OT/OP Delta-T Parameters - Channel IV, Revision 44

Condition Reports (CR-IP2)

2016-03961

2016-04266

Condition Reports (CR-IP3)

2016-01189

2016-01199

2016-01218

Maintenance Orders/Work Orders

WO 00414886

WO 00420649

WO 00446094

WO 00447966

WO 52545181

WO 52626563

WO 52626564

WO 52630619

WO 52630620

WO 52658943

WO 00236158

WO 00277374

WO 52571030

Drawings

5651D72, Logic Diagrams Steam Generator Trip Signals, Revision 7

Miscellaneous

EC 64545, Emergency Temporary Modification to Disconnect 32 EDG Generator Space Heater

Adjacent to End Plate on Outboard End of Generator

FIX00091, Pressurizer Level Uncertainty - Indication, Trip Setpoints, and Annunciation

Setpoints, Revision 1

E-mail from J. Michetti to G. Newman, dated July 19, 2016, Subject: Westinghouse Report

on E9

A-8

Section 1R20: Refueling and Other Outage Activities

Procedures

2-POP-1.1, Plant Heatup from Cold Shutdown, Revision 90

2-POP-1.2, Reactor Startup, Revision 59

2-POP-1.3, Plant Startup from Zero to 45 Percent Power, Revision 89

2-POP-3.1, Plant Shutdown from 45 Percent Power, Revision 58

2-POP-3.3, Plant Cooldown, Hot to Cold Shutdown, Revision 81

2-POP-3.4, Secondary Plant Shutdown, Revision 10

2-POP-4.1, Operation at Cold Shutdown, Revision 5

2-POP-4.2, Operation Below 20 Percent Pressurizer Level with Fuel in the Reactor, Revision 8

2-POP-4.3, Operation without Fuel in the Reactor, Revision 1

Condition Reports (CR-IP2-)

2016-04118

2016-04119

2016-04123

2016-03124

2016-04126

2016-04129

2016-04130

2016-04131

2016-04132

2016-04139

2016-04141* 2016-04142*

2016-04144

2016-04145

2016-04146

2016-04148* 2016-04151

2016-04152

2016-04155

2016-04161

2016-04162

2016-04165

2016-04169

• NRC identified

Maintenance Orders/Work Orders

52681465

Miscellaneous

2R22 Performance Indicator Curves Daily from March 7 to June 14, 2016

Outage Schedules and Plans of the Day from March 7 to June 14, 2016

Westinghouse LTR-PL-16-16, Operability Assessment for Primary Side Loose Parts at Indian

Point Unit 2, Revision 0, dated March 27, 2016

Section 1R22: Surveillance Testing

Procedures

0-SOP-LEAKRATE-001, RCS Leakrate Surveillance Evaluation and Leak Identification,

Revision 6

2-PT-D001, Control Room Operations Surveillance Requirements, Revision 16

2-PT-M029B, 22 Safety Injection Pump, Revision 20

2-PT-Q013, Inservice Valve Tests, Revision 51

2-PT-Q013-DS040, Valve 887B Inservice Test Data Sheet, Revision 22

3-PT-M079B, 32 EDG Functional Test, Revision 52

Condition Reports (CR-IP2)

2016-03360

2016-03363

Condition Reports (CR-IP3)

2016-01716

2016-01752

Maintenance Orders/Work Orders

WO 00443040

WO 00446385

WO 00446867

WO 52681652-01

WO 52681646-01

A-9

Miscellaneous

EC 64855, EC Reply to Provide Input Regarding MPR Maintenance Bulletin MB-2007-01 for

Auto Voltage Regulator Solder Joints

MB-2007-01, Potential for Solder Joint Cracks on Basler SBSR Auto Voltage Regulator Cards

and Technical Manual Addendum TM-2007-01, November 5, 2007

Unit 3 RCS Routine Activity Sample, 28-June-16-10006

Section 1EP6: Drill Evaluation

Procedures

IP-EP-120, Emergency Classification, Revision 10

IP-EP-410, Protective Action Recommendations, Revision 11

Section 2RS7: Radiological Environmental Monitoring Program

Procedures

0-CY-1920, REMP Land Use Census, Revision 1

0-CY-1980, Preparation, Placement and Collection of Site Environmental Thermoluminescent

Dosimeters, Revision 2

Condition Reports (CR-IP2)

2014-05319

2015-00948

2015-01300

2015-02687

2015-02800

2015-02987

2015-03271

2015-03396

2016-02313

Condition Reports (CR-IP3)

2016-00514

Miscellaneous

2014 Annual Radiological Environmental Operating Report, Indian Point Nos. 1, 2, and 3

2015 Annual Radiological Environmental Operating Report, Indian Point Nos. 1, 2, and 3

Environmental Dosimetry Company, Annual Quality Assurance Status Report,

January to December 2015

Indian Point Energy Center ODCM, Revision 4

June 2015 to May 2016 Meteorological Data Recovery

Met One Instruments, Inc. Certificates of Calibration for Temperature, Wind Direction, and Wind

Speed

Teledyne Brown Engineering Environmental Services Annual 2015 Quality Assurance Report

Exelon PowerLabs Certificates of Calibration for Gas Meters

3471875

3482909

3471871

3471867

3482920

3471873

3482910

3482916

3471877

3482914

3482918

3482921

3471881

3471879

3471872

3471869

3471880

3482908

Quality Assurance

Quality Assurance Audit Report QA-2-6-2015-IP-1, Chemistry, Effluents, and Environmental

Monitoring Snapshot Self-Assessment, LO-IP3LO-2015-00126, Chemistry-REMP

Section 4OA2: Problem Identification and Resolution

Procedures

EN-DC-204, Maintenance Rule Scope and Basis, Revision 3

EN-DC-204, Maintenance Rule Scope and Basis, Revision 3

EN-DC-207, Maintenance Rule Periodic Assessment, Revision 3

A-10

EN-LI-102, Corrective Action Program, Revision 26

EN-LI-104, Self-Assessment and Benchmark Process, Revision 11

EN-LI-110-01, Equipment Failure Evaluation, Revision 0

EN-LI-119, Apparent Cause Evaluation Process, Revision 11

EN-OP-104, Operability Determination Process, Revision 10

Condition Reports (CR-IP2)

2010-07013

2015-04574

2015-05458

2015-05460

2015-05461

2015-05464

2015-05466

2015-05467

2016-01374

2016-02348

Condition Reports (CR-IP3)

2015-3628

2016-01035

2016-01961

Maintenance Orders/Work Orders

WO 00442412

Apparent Cause Evaluations

IP2-2015-05458

Drawings

504405, Sheet 1 of 2, Replacement Baffle Bolt Location Matrix, Revision 0

504405, Sheet 2 of 2, Replacement Baffle Bolt Location Matrix, Revision 0

Miscellaneous

61265, Temporary Modification Control Form-Install Additional Temporary Spare Power Supply

Inside Rod Control Cabinet 2BD to Restore Margin, Revision 0

Appendix A to Facility Operating License DPR-64, Technical Specifications and Basis For The

Indian Point 3 Nuclear Generating Station Unit No.3, Through Amendment 260

CN-RIDA-15-43, Indian Point Units 2 and 3 Acceptable Baffle-Former Bolting LOCA and

Seismic Analysis, Revision 2

Engineering Change 63938, As-left condition of the baffle-former plate assembly following the

replacement of degraded bolts, Revision 0

EPRI TR-112209, Analysis of Baffle Former Bolt Cracking in EDF CPO Plants (PWRMRP-03),

dated June 1999

Indian Point Entergy Center (IPEC) Unit 3, Updated Final Safety Analysis Report, dated May

2013

IP-RPT-16-00025, Evaluation of Indian Point Unit 3 Reactor Core Baffle Bolting Following MRP-

227-A Inspection Findings at Indian Point Unit 2 during 2R22, Revision 0

LO-IP3LO-2015-72

LTR-PL-16-21, Transmittal of Indian Point Unit 3 Final Engineering Evaluations Supporting

Extent of Condition Review, Revision 0

LTR-RIDA-16-103, Indian Point Unit 2 Baffle Bolting Anti-Clustering Pattern and Margin

Assessment, Revision 0

LTR-RIDA-16-152, Indian Point Unit 3 Baffle Bolt Leak Before Break Operability Assessment,

Revision 0

LTR-RIDA-16-60, Indian Point Unit 2 Baffle Bolting One Cycle Replacement Pattern Summary

Letter, Revision 0

MRP-227-A, Materials Reliability Program: Pressurized Water Reactor Internals Inspection and

Evaluation Guidelines (ML120170453)

Operation Decision Making Issue Action Plan for IP3 Baffle Bolt Monitoring, dated May 19, 2016

WCAP-15029-NP-A, Westinghouse Methodology for Evaluating the Acceptability of Baffle-

Former-Barrel Bolting Distributions Under Faulted Load Conditions, Revision 0

(ML15222A882)

A-11

WCAP-17949-P, Background and Technical Basis Supporting Engineering Flaw Acceptance

Criteria for Indian Point Unit 2 Reactor Vessel Internals MRP-227-A Primary and

Expansion Components, Revision 1

WCAP-18048-P, Determination of Acceptable Baffle-Former Bolting for Indian Point Units 2 and

3, Revision 0

Section 4OA5: Other Activities

Miscellaneous

INPO Letter, INPO Equipment Reliability Scram Review Visit, May 31, 2016

Root Cause Evaluation for CR-IP2-2016-00564

A-12

LIST OF ACRONYMS

10 CFR

Title 10 of the Code of Federal Regulations

ADAMS

Agencywide Document Access and Management System

ALARA

as low as is reasonably achievable

AVR

automatic voltage regulator

CAP

corrective action program

CCW

component cooling water

CR

condition report

CVCS

chemical and volume control system

EC

engineering change

ECCS

emergency core cooling system

EDG

emergency diesel generator

GPI

groundwater protection initiative

IASCC

irradiation-assisted stress-corrosion cracking

IMC

Inspection Manual Chapter

INPO

Institute of Nuclear Power Operations

LER

licensee event report

LOCA

loss-of-coolant accident

MBFP

main boiler feedwater pump

MCC

motor control center

MOV

motor operated valve

MRP

materials reliability program

MW

monitoring well

NCV

non-cited violation

NRC

Nuclear Regulatory Commission, U.S.

ODCM

offsite dose calculation manual

OOS

out of service

PAB

primary auxiliary building

PFP

pre-fire plan

RCS

reactor coolant system

REMP

radiological environmental monitoring program

RFO

refueling outage

RW

recovery well

SI

safety injection

SSC

structure, system, and component

TS

technical specification

UFSAR

updated final safety evaluation report

URI

unresolved item

UT

ultrasonic testing

WO

work order