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NRC Integrated Inspection Report 05000254/2017001 and 05000265/2017001
	ML17124A163
Person / Time
Site:	Quad Cities
Issue date:	05/03/2017
From:	Karla Stoedter; NRC/RGN-III/DRP/B1
To:	Bryan Hanson; Exelon Generation Co, Exelon Nuclear
References
	IR 2017001
	Download: ML17124A163 (57)
	v • d • e

UNITED STATES

NUCLEAR REGULATORY COMMISSION REGION III 2443 WARRENVILLE RD. SUITE 210 LISLE, IL 60532-4352

May 3, 2017

Mr. Bryan C. Hanson

Senior VP, Exelon Generation Company, LLC

President and CNO, Exelon Nuclear

4300 Winfield Road

Warrenville, IL 60555 SUBJECT: QUAD CITIES NUCLEAR POWER STATION, UNITS 1 AND 2-NRC INTEGRATED INSPECTION REPORT 05000254/2017001 AND

05000265/2017001

Dear Mr. Hanson:

On March 31, 2017, the U.S. Nuclear Regulatory Commission (NRC) completed an integrated inspection at your Quad Cities Nuclear Power Station, Units 1 and 2. On April 11, 2017, the

NRC inspectors discussed the results of this inspection with Mr. S. Darin

and other members of your staff. The results of this inspection are documented in the enclosed report.

Based on the results of this inspection, the NRC has identified one issue that was evaluated under the risk significance determination process as having very low safety significance (Green). The NRC has also determined that one violation is associated with this issue. Because the licensee initiated condition reports to address this issue, this violation is being

treated as a Non-Cited Violation (NCV), consistent with Section 2.3.2a of the Enforcement

Policy. The NCV is described in the subject inspection report.

If you contest the violation or significance of the NCV, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the U.S. Nuclear

Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001; with

copies to the Regional Administrator, Region III; the Director, Office of Enforcement; and the

NRC Resident Inspector at the Quad Cities Nuclear Power Station. If you disagree with a cross-cutting aspect assignment or a finding not associated with a regulatory requirement 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 U.S. Nuclear Regulatory

Commission, ATTN: Document Control Desk, Washington, DC 20555-0001; with copies to the

Regional Administrator, Region III; and the NRC Resident Inspector at the Quad Cities Nuclear

Power Station.

B. Hanson - 2 - This letter, its enclosure, and your response (if any) will be made available for public inspection

and copying at

http://www.nrc.gov/reading-rm/adams.html

and at the NRC Public Document Room in accordance with 10 CFR 2.390, "Public Inspections, Exemptions, and Requests for Withholding."

Sincerely,

/RA/

Karla Stoedter, Chief

Branch 1

Division of Reactor Projects

Docket Nos. 50-254; 50-265 License Nos. DPR-29; DPR-30

Enclosure:

IR 05000254/2017001; 05000265/2017001

cc: Distribution via LISTSERV

B. Hanson - 3 - Letter to Bryan C. Hanson from Karla Stoedter dated May 3, 2017

SUBJECT: QUAD CITIES NUCLEAR POWER STATION, UNITS 1 AND 2-NRC INTEGRATED INSPECTION REPORT 05000254/2017001 AND

05000265/2017001

DISTRIBUTION: Jeremy Bowen

RidsNrrDorlLpl3

RidsNrrPMQuadCities Resource

RidsNrrDirsIrib Resource

Cynthia Pederson

DRPIII

DRSIII ROPreports.Resource@nrc.gov

ADAMS Accession Number: ML17124A163 OFFICE RIII NAME KStoedter:bw DATE 05/03/2017 OFFICIAL RECORD COPY

Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION III Docket Nos: 50-254; 50-265 License Nos: DPR-29, DPR-30 Report No: 05000254/2017001; 05000265/2017001 Licensee: Exelon Generation Company, LLC Facility: Quad Cities Nuclear Power Station, Units 1 and 2 Location: Cordova, IL Dates: January 1 through March 31, 2017 Inspectors: R. Murray, Senior Resident Inspector K. Carrington, Resident Inspector M. Garza, Emergency Preparedness Inspector

A. Dahbur, Fire Protection Inspector

J. Neurauter, Reactor Engineer

M. Domke, Reactor Engineer

J. Cassidy, Senior Health Physicist V. Meyers, Senior Health Physicist C. Mathews, Illinois Emergency Management Agency

Approved by: K. Stoedter, Chief

Branch 1 Division of Reactor Projects

2 TABLE OF CONTENTS SUMMARY ...............................................................................................................................

..... 2 REPORT DETAILS ................................................................................................................

....... 4 Summary of Plant Status .......................................................................................................

.... 4 1. REACTOR SAFETY ............................................................................................ 4

1R01 Adverse Weather Protection (71111.01) .............................................................. 4

1R04 Equipment Alignment (71111.04) ........................................................................ 5

1R05 Fire Protection (71111.05) ................................................................................... 6

1R06 Flooding (71111.06) ............................................................................................. 6

1R07 Annual Heat Sink Performance (71111.07) ......................................................... 7

1R08 Inservice Inspection Activities (71111.08) ............................................................ 7

1R11 Licensed Operator Requalification Program (71111.11) ...................................... 9

1R12 Maintenance Effectiveness (71111.12) .............................................................. 11

1R13 Maintenance Risk Assessments and Emergent Work Control (71111.13) ........ 11

1R15 Operability Determinations and Functional Assessments (71111.15) ............... 12

1R19 Post-Maintenance Testing (71111.19) ............................................................... 13

1R20 Outage Activities (71111.20) .............................................................................. 14

1R22 Surveillance Testing (71111.22) ........................................................................ 14

1EP2 Alert and Notification System Evaluation (71114.02) ......................................... 16

1EP3 Emergency Response Organization Staffing and Augmentation System

(71114.03)

.......................................................................................................... 16

1EP5 Maintenance of Emergency Preparedness (71114.05) ..................................... 17

1EP6 Drill Evaluation (71114.06)

................................................................................. 17

2. RADIATION SAFETY ........................................................................................ 18

2RS1 Radiological Hazard Assessment and Exposure Controls (71124.01) .............. 18

2RS2 Occupational As-Low-As-Reasonably-Achievable Planning and Controls

(71124.02)

.......................................................................................................... 22

2RS3 In-Plant Airborne Radioactivity Control and Mitigation (71124.03) .................... 23

2RS4 Occupational Dose Assessment (71124.04) ...................................................... 25

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

4OA1 Performance Indicator Verification (71151) ....................................................... 27

4OA2 Identification and Resolution of Problems (71152) ............................................ 30

4OA3 Follow-Up of Events and Notices of Enforcement Discretion (71153) ............... 33

4OA5 Other Activities ................................................................................................... 34

4OA6 Management Meetings ...................................................................................... 37

SUPPLEMENTAL INFORMATION

............................................................................................ 1

Key Points of Contact .........................................................................................................

....... 1 List of Items Opened, Closed, and Discussed

........................................................................... 2

List of Documents Reviewed ..................................................................................................... 3 List of Acronyms Used .........................................................................................................

... 15

2 SUMMARY Inspection Report 05000254/2017001, 05000265/2017001; 01/01/2017-03/31/2017; Quad Cities Nuclear Power Station, Units 1 and 2; Identification and Resolution of Problems. This report covers a 3-month period of inspection by resident inspectors and announced baseline inspections by regional inspectors. One Green finding was identified by the inspectors.

The finding involved a Non-Cited Violation (NCV) of the U.S. Nuclear Regulatory

Commission (NRC) requirements. The significance of inspection 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 NRC requirements are dispositioned in accordance with the NRC's Enforcement Policy, dated November 1, 2016. The NRC's 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. A finding of very low safety significance and an associated NCV of 10 CFR 50, Appendix B, Criterion V was self-revealed on January 27, 2017, when the Unit 1C residual heat removal service water (RHRSW) pump was started for a routine surveillance evolution and all expected annunciators and equipment failed to operate

properly, which led to the licensee declaring the Unit 1C RHRSW pump inoperable.

Specifically, the licensee failed to establish a procedure for the mechanism operated

contact (MOC) switch linkage arm that was appropriate to the circumstances to ensure the component would continue to perform its function. Immediate corrective actions included reconnecting the MOC switch linkage arm assembly and testing it by starting

the 1C RHRSW pump prior to declaring the pump operable. In addition, the licensee

planned procedure revisions to QCEPM 0200-11 that would specify a torque value to

ensure the MOC switch linkage arm was adequately secured and could perform its function. This issue was entered into the licensee's corrective action program as Issue

Report 3967424. The finding was determined to be more than minor because the finding was associated with the Mitigating Systems cornerstone attribute of equipment performance and

affected the cornerstone objective of ensuring the availability, reliability, and capability of

systems that respond to initiating events to prevent undesirable consequences.

Specifically, the failure to ensure the MOC switch linkage arm was adequately fastened

led to the failure of the component and its associated Unit 1C RHRSW pump during breaker operation on January 27, 2017. The finding was determined to be of very low safety significance (Green), because the inspectors answered "No" to all of the

questions in IMC 0609, Appendix A, "The Significance Determination Process for

Findings at Power," Exhibit 2, "Mitigati

ng Systems Screening Questions," Section A, "Mitigating SSCs and Functionality." The inspectors determined this finding affected the cross-cutting area of human performance, in the aspect of avoid complacency, which states, "Individuals recognize and plan for the possibility of mistakes, latent issues, and

inherent risk, even while expecting successful outcomes." Specifically, the licensee failed to recognize a potential risk and inherent latent issue for a condition identified in

2015 at Quad Cities, when a MOC switch failed to perform its function due to a missing

nut in a different breaker's linkage assembly. The licensee identified and corrected the

3 condition but failed to evaluate the cause of the missing nut because it did not impact the operability of the component. In the 2015 instance, the MOC switch issue only affected

indications for the component and had no adverse impact on the ability of the

component to perform its function [H.12]. (Section 4OA2)

4 REPORT DETAILS Summary of Plant Status

Unit 1 With the exception of planned power reductions for turbine testing, control rod pattern adjustments, and power changes as requested by the transmission system operator, the unit

remained at or near full power from January 1 to January 18, 2017. On January 18, the unit

began coasting down for Refueling Outage Q1R24. On March 27, 2017, the unit shut down for Q1R24 and remained shut down through the end of the inspection period.

Unit 2 The unit operated at or near full power for the entire inspection period with the exception of planned power reductions for turbine testing, control rod pattern adjustments, control rod drive maintenance, and power changes as requested by the transmission system operator.

1. REACTOR SAFETY Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity 1R01 Adverse Weather Protection (71111.01) .1 Winter Seasonal Readiness Preparations a. Inspection Scope The inspectors conducted a review of the licensee's preparations for winter conditions to verify that the plant's design features and implementation of procedures were sufficient to protect mitigating systems from the effects of adverse weather. Documentation for

selected risk-significant systems was reviewed to ensure that these systems would remain functional when challenged by inclement weather. During the inspection, the

inspectors focused on plant specific design features and the licensee's procedures used

to mitigate or respond to adverse weather conditions. Additionally, the inspectors

reviewed the Updated Final Safety Analysis Report (UFSAR) and performance requirements for systems selected for inspection, and verified that operator actions were appropriate as specified by plant specific procedures. Cold weather protection, such as

heat tracing and area heaters, was verified to be in operation where applicable. The

inspectors also reviewed corrective action program (CAP) items to verify that the licensee was identifying adverse weather issues at an appropriate threshold and entering them into their CAP in accordance with station corrective action procedures. Documents reviewed are listed in the Attachment to this report. The inspectors' reviews focused specifically on the following plant systems due to their risk significance or susceptibility to cold weather issues:

345 kilo-volt system; and

Units 1 and 2 standby liquid control systems. This inspection constituted one winter seasonal readiness preparation sample as defined in Inspection Procedure (IP) 71111.01-05.

5 b. Findings No findings were identified. 1R04 Equipment Alignment (71111.04) .1 Quarterly Partial System Walkdowns a. Inspection Scope The inspectors performed partial system walkdowns of the following risk-significant systems: * Unit 1 and Unit 2 emergency diesel generator (EDG) systems during Unit 1/2 EDG surveillance testing;

Unit 2 reactor core isolation cooling (RCIC) system during Unit 2 high pressure coolant injection system planned maintenance;

Unit 2 'C' and 'D' residual heat removal service water (RHRSW) pump systems

during 'A' and 'B' RHRSW syst

ems planned maintenance; and

Unit 1 fuel pool cooling system during Unit 1 Q1R24 alternate decay heat removal

operations. The inspectors selected these systems based on their risk significance relative to the Reactor Safety Cornerstones at the time they were inspected. The inspectors attempted

to identify any discrepancies that could impact the function of the system and, therefore, potentially increase risk. The inspectors reviewed applicable operating procedures, system diagrams, UFSAR, Technical Specification (TS) requirements, outstanding work

orders (WOs), condition reports, and the impact of ongoing work activities on redundant

trains of equipment in order to identify conditions that could have rendered the systems

incapable of performing their intended functions. The inspectors also walked down

accessible portions of the systems to verify system components and support equipment were aligned correctly and operable. The inspectors examined the material condition of the components and observed operating parameter

s of equipment to verify that there were no obvious deficiencies. The inspectors also verified that the licensee had properly

identified and resolved equipment alignment problems that could cause initiating events or impact the capability of mitigating systems or barriers and entered them into the CAP with the appropriate significance characterization. Documents reviewed are listed in the Attachment to this report. These activities constituted four partial system walkdown samples as defined in

IP 71111.04-05. b. Findings No findings were identified.

6 1R05 Fire Protection (71111.05) .1 Routine Resident Inspector Tours (71111.05Q) a. Inspection Scope The inspectors conducted fire protection walkdowns which were focused on availability, accessibility and the condition of firefighting equipment in the following risk-significant plant areas:

Fire zone (FZ) 11.2.1, Unit 1 reactor building, elevation 554'-0", southwest corner

room, 1B core spray;

FZ 8.2.6.B, Unit 1 turbine building, elevation 595'-0", low pressure heater bay;

FZ 8.2.7.B, Unit 1 turbine building, elevation 615'-6", low Pressure and 'D' heater

bay; and * FZ 8.2.7.C, Unit 1/2 turbine building, elevation 611', mezzanine floor. The inspectors reviewed areas to assess if the licensee had implemented a fire protection program that adequately controlled combustibles and ignition sources within the plant, effectively maintained fire detection and suppression capability, maintained passive fire protection features in good material condition, and implemented adequate

compensatory measures for out-of-service, degraded or inoperable fire protection

equipment, systems, or features in accordance with the licensee's fire plan.

The inspectors selected fire areas based on their overall contribution to internal fire risk

as documented in the plant's Individual Plant Examination of External Events with later additional insights, their potential to impact equipment which could initiate or mitigate a plant transient, or their impact on the plant's ability to respond to a security event.

Using the documents listed in the Attachment to this report, the inspectors verified that

fire hoses and extinguishers were in their designated locations and available for

immediate use; that fire detectors and sprinklers were unobstructed; that transient material loading was within the analyzed limits; and fire doors, dampers, and penetration seals appeared to be in satisfactory condition. The inspectors also verified that minor

issues identified during the inspection were entered into the licensee's CAP. Documents reviewed are listed in the Attachment to this report. These activities constituted four quarterly fire protection inspection samples as defined in

IP 71111.05-05. b. Findings No findings were identified. 1R06 Flooding (71111.06) .1 Internal Flooding a. Inspection Scope The inspectors reviewed selected risk important plant design features and licensee procedures intended to protect the plant and its safety-related equipment from internal flooding events. The inspectors reviewed flood analyses and design documents, including the UFSAR, engineering calculations, and abnormal operating procedures to

7 identify licensee commitments. The specific documents reviewed are listed in the Attachment to this report. In addition, the inspectors reviewed licensee drawings to

identify areas and equipment that may be affected by internal flooding caused by the failure or misalignment of nearby sources of water, such as the fire suppression or the circulating water systems. The inspectors also reviewed the licensee's corrective action

documents with respect to past flood-related items identified in the corrective action

program to verify the adequacy of the corrective actions. The inspectors performed a

walkdown of the following plant area to assess the adequacy of watertight doors and

verify drains and sumps were clear of debris and were operable, and that the licensee

complied with its commitments:

Units 1 and 2 RHRSW vaults. Documents reviewed during this inspection are listed in the Attachment to this report. This inspection constituted one internal flooding sample as defined in IP 71111.06-05.

b. Findings No findings were identified. 1R07 Annual Heat Sink Performance (71111.07) .1 Heat Sink Performance a. Inspection Scope The inspectors reviewed the licensee's testing of the 'B' control room emergency ventilation system refrigeration condensing unit heat exchanger to verify that potential deficiencies did not mask the licensee's ability to detect degraded performance, to identify any common cause issues that had the potential to increase risk, and to ensure

that the licensee was adequately addressing problems that could result in initiating

events that would cause an increase in risk. The inspectors reviewed the licensee's

observations as compared against acceptance criteria, the correlation of scheduled testing and the frequency of testing, and the impact of instrument inaccuracies on test results. Inspectors also verified that test acceptance criteria considered differences

between test conditions, design conditions, and testing conditions. Documents reviewed for this inspection are listed in the Attachment to this document. This annual heat sink performance inspection constituted one sample as defined in

IP 71111.07-05. b. Findings No findings were identified. 1R08 Inservice Inspection Activities (71111.08) From March 27-31, 2017, the inspectors conducted a review of the implementation of the licensee's Inservice Inspection (ISI) Program for monitoring degradation of the Unit 1 reactor coolant system, risk-significant piping and components, and containment systems.

8 The inspections described in Sections 1R08.1 and 1R08.5 below constituted one sample

as defined in IP 71111.08-05. .1 Piping Systems Inservice Inspection a. Inspection Scope The inspectors either observed or reviewed the following Non-Destructive Examinations (NDE) mandated by the American Society of Mechanical

Engineers (ASME),Section XI Code to evaluate compliance with the ASME Code

Section XI and Section V requirements, and if any indications and defects were detected

to determine if these were dispositioned in accordance with the ASME Code or a NRC

approved alternative requirement:

Ultrasonic examination of elbow-to-pipe weld (component 30A-S11) in the main steam system (WO No. 01831310-01);

Ultrasonic examination of elbow-to-pipe weld (component 30B-S10) in the main steam system (WO No. 01831310-01);

Magnetic particle examination (MT) of collar-torus shell (component 1025-50) in emergency core cooling system (WO 01831310);

MT of welds-variable spring can with four lugs welded to pipe (component

1401-W-201A) in core spray system (WO 01831310);

MT of welds-eight guide lugs welded to pipe (component 2304-W-204A) in the high pressure coolant injection system (WO No. 01831310);

General visual examination of a sample of metallic containment surface area examinations: Penetrations X-016A, X-020, X-025, X-042, X-08, and X-109; X-025 MC piping at elevations 647, 623, and 595 (WO No. 01831711-02);

Visual examination (VT-1) of welds-four lugs welded to pipe (component 1005A-W-304.5A) in RHRSW system (WO 01831310);

VT-3 of pipe restraint-box guide (component 1005A-W-304.5) in RHRSW

system (WO 01831310);

VT-3 of pipe support-two variable spring cans (component 1401-W-201 A&B) in core spray system (WO 01831310); and

VT-3 of flued head anchor (component 1202-M-108.1) in the reactor water clean-up system (WO No. 01831310).

The inspectors reviewed one surface exami

nation from the previous outage with a relevant indication that was evaluated and accepted by the licensee for continued

service. The inspectors verified that the licensee's removal of the piping flange indications without a weld repair did not impact compliance with ASME Standard B16.5 for flange design and Standard B31.1 for piping design.

Reactor head vent line indications found during liquid penetrant examinations (WO 01636433-07). The inspectors reviewed records for the following pressure boundary weld repairs completed for risk-significant systems during the last outage to determine whether the licensee applied the pre-service NDE and acceptance criteria required by the Construction Code, and/or the NRC-approved Code relief request. Additionally, the

inspectors reviewed the welding procedure specifications and supporting weld

procedure qualification records to determine whether the weld procedures were

9 qualified in accordance with the requirements of the Construction Code and the ASME Code, Section IX:

installation of a 2-to-1 fillet weld at socket welds 1 through 23 on the Unit 1 reactor head vent line 1-0215-2"-B (WO No. 01636433-01); and

high pressure coolant injection piping reroute-weld map #1 fillet welds at socket welds 2, 3, 8, 9, 16, and 17 on line 1-2318-2"-LX (WO No. 1877257-11). b. Findings No findings were identified. .2 Reactor Pressure Vessel Upper Head Penetration Inspection Activities (Not Applicable) .3 Boric Acid Corrosion Control (Not Applicable) .4 Steam Generator Tube Inspection Activities (Not Applicable) .5 Identification and Resolution of Problems a. Inspection Scope The inspectors performed a review of ISI-related problems entered into the licensee's CAP, and conducted interviews with licensee staff to determine if:

the licensee had established an appropriate threshold for identifying ISI-related

problems;

the licensee had performed a root cause (if applicable), and taken appropriate corrective actions; and

the licensee had evaluated operating experience, and industry generic issues related to ISI and pressure boundary integrity. The inspectors performed these reviews to evaluate compliance with Title 10, Code of Federal Regulations (CFR), Part 50, Appendix B, Criterion XVI, "Corrective Action," requirements. The corrective action documents reviewed by the inspectors are listed in the Attachment to this report. b. Findings No findings were identified. 1R11 Licensed Operator Requalification Program (71111.11) .1 Resident Inspector Quarterly Review of Licensed Operator Requalification (71111.11Q) a. Inspection Scope On February 7, 2017, the inspectors observed a crew of licensed operators in the plant's simulator during licensed operator requalification training. The inspectors verified that

operator performance was adequate, evaluators were identifying and documenting crew performance problems, and that training was being conducted in accordance with licensee procedures. The inspectors evaluated the following areas:

10 * licensed operator performance;

crew's clarity and formality of communications;

ability to take timely actions in the conservative direction;

prioritization, interpretation, and verification of annunciator alarms;

correct use and implementation of abnormal and emergency procedures;

control board manipulations;

oversight and direction from supervisors; and

ability to identify and implement appropriate TS actions and Emergency Plan actions and notifications. The crew's performance in these areas was compared to pre-established operator action expectations and successful critical task completion requirements. Documents reviewed are listed in the Attachment to this report. This inspection constituted one quarterly licensed operator requalification program simulator sample as defined in IP 71111.11-05.

b. Findings No findings were identified. .2 Resident Inspector Quarterly Observation during Periods of Heightened Activity or Risk

(71111.11Q) a. Inspection Scope On March 26, 2017, the inspectors observed control room operators on Unit 1 perform a planned shutdown for refueling outage Q1R24. This was an activity that required

heightened awareness and was related to increased risk. The inspectors evaluated the following areas:

licensed operator performance;

crew's clarity and formality of communications;

ability to take timely actions in the conservative direction;

prioritization, interpretation, and verification of annunciator alarms;

correct use and implementation of abnormal and emergency procedures;

control board manipulations;

oversight and direction from supervisors; and

ability to identify and implement appropriate TS actions and Emergency Plan actions and notifications. The performance in these areas was compared to pre-established operator action expectations, procedural compliance and task completion requirements. Documents reviewed are listed in the Attachment to this report. This inspection constituted one quarterly licensed operator heightened activity/risk sample as defined in IP 71111.11-05. b. Findings No findings were identified.

11 1R12 Maintenance Effectiveness (71111.12) .1 Routine Quarterly Evaluations a. Inspection Scope The inspectors evaluated degraded performance issues involving the following risk-significant systems:

Z6600: emergency diesel generator systems; and

Z8300: 125 volt direct current (VDC) battery systems. The inspectors reviewed events such as where ineffective equipment maintenance had resulted in valid or invalid automatic actuations of engineered safeguards systems and

independently verified the licensee's actions to address system performance or condition problems in terms of the following:

implementing appropriate work practices;

identifying and addressing common cause failures;

scoping of systems in accordance with 10 CFR 50.65(b) of the maintenance rule;

characterizing system reliability issues for performance;

charging unavailability for performance;

trending key parameters for condition monitoring;

ensuring 10 CFR 50.65(a)(1) or (a)(2) classification or re-classification; and

verifying appropriate performance criteria for structures, systems, and components (SSCs)/functions classified as (a)(2), or appropriate and adequate goals and corrective actions for systems classified as (a)(1). The inspectors assessed performance issues with respect to the reliability, availability, and condition monitoring of the system. In addition, the inspectors verified maintenance

effectiveness issues were entered into the CAP with the appropriate significance characterization. Documents reviewed are listed in the Attachment to this report. This inspection constituted two quarterly maintenance effectiveness samples as defined in IP 71111.12-05. b. Findings No findings were identified. 1R13 Maintenance Risk Assessments and Emergent Work Control (71111.13) .1 Maintenance Risk Assessments and Emergent Work Control a. Inspection Scope The inspectors reviewed the licensee's evaluation and management of plant risk for the maintenance and emergent work activities affecting risk-significant and safety-related

equipment listed below to verify that the appropriate risk assessments were performed

prior to removing equipment for work:

12 * Work week 17-02-05: Unit 1 RCIC system planned maintenance and online risk change to yellow, 'B' train of control room emergency heating, ventilation, and air conditioning system heat exchanger planned maintenance, 1A core spray pump

planned maintenance and Unit 1 online risk change to yellow;

Emergent work on the Unit 2 3E automatic depressurization system electromatic relief valve light indication on February 3, 2017;

Work week 17-09-12: Unit 2 125 VDC planned maintenance and both units unplanned online risk change to yellow due to tornado warnings in Rock Island County; and

Work week 17-13-03: Unit 2 online risk change to yellow and Unit 1 shutdown safety risk yellow during refueling outage Q1R24-Week 1. These activities were selected based on their potential risk significance relative to the Reactor Safety cornerstones. As applicable for each activity, the inspectors verified that risk assessments were performed as required by 10 CFR 50.65(a)(4) and were accurate and complete. When emergent work was performed, the inspectors verified that the

plant risk was promptly reassessed and managed. The inspectors reviewed the scope

of maintenance work, discussed the results of the assessment with the licensee's

probabilistic risk analyst or shift technical advisor, and verified plant conditions were consistent with the risk assessment. The inspectors also reviewed TS requirements and walked down portions of redundant safety systems, when applicable, to verify risk analysis assumptions were valid and applicable requirements were met. Documents reviewed during this inspection are listed in the Attachment to this report. These maintenance risk assessments and emergent work control activities constituted four samples as defined in IP 71111.13-05. b. Findings No findings were identified. 1R15 Operability Determinations and Functional Assessments (71111.15) .1 Operability Evaluations a. Inspection Scope The inspectors reviewed the following issues:

Issue Report (IR) 2709786: DGCWP [diesel generator cooling water pump]/RHRSW Common Suction Piping Degradation;

IR 3968961: Residual Heat Removal (RHR) Thermal Performance Testing Using

Fluke Model 45;

IR 3967424: Unit 1C RHRSW Pump Abnormal Indications; and

IR 3971856: 1D RHRSW Trip Fuses Worked Out of Fuse Holder. The inspectors selected these potential operability issues based on the risk significance of the associated components and systems. The inspectors evaluated the technical

adequacy of the evaluations to ensure that 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

13 appropriate sections of the TS and UFSAR to the licensee's evaluations to determine

whether the components or systems were

operable. Where compensatory measures were required to maintain operability, the inspectors determined whether the measures in place would function as intended and were properly controlled. The inspectors determined, where appropriate, compliance with bounding limitations associated with the

evaluations. Additionally, the inspectors reviewed a sampling of corrective action

documents to verify that the licensee was identifying and correcting any deficiencies

associated with operability evaluations. Documents reviewed are listed in the Attachment to this report. This operability inspection constituted four samples as defined in IP 71111.15-05. b. Findings No findings were identified. 1R19 Post-Maintenance Testing (71111.19) .1 Post-Maintenance Testing a. Inspection Scope The inspectors reviewed the following post-maintenance testing (PMT) activities to verify that procedures and test activities were adequate to ensure system operability and functional capability:

WO 1961658 for the Unit 1 RCIC system following planned maintenance;

WO 1846331 for the Unit 2 125 VDC battery

system following battery terminal board and potentiometer installation under Engineering Change (EC) 402467; and

WO 4612395 for the Unit 1 EDG cooling water pump following emergent work and

unplanned maintenance. These activities were selected based upon the structure, system, or component's ability to impact risk. The inspectors evaluated these activities for the following (as applicable): the effect of testing on the plant had been adequately addressed; testing was adequate for the maintenance performed; acceptance criteria were clear and demonstrated

operational readiness; test instrumentation was appropriate; tests were performed as

written in accordance with properly reviewed and approved procedures; equipment was returned to its operational status following testing (temporary modifications or jumpers required for test performance were properly removed after test completion); and test

documentation was properly evaluated. The inspectors evaluated the activities against TSs, the UFSAR, 10 CFR Part 50 requirements, licensee procedures, and various

NRC generic communications to ensure that the test results adequately ensured that the

equipment met the licensing basis and design requirements. In addition, the inspectors

reviewed corrective action documents associated with post-maintenance tests to determine whether the licensee was identifying problems and entering them in the CAP and that the problems were being corrected commensurate with their importance to safety. Documents reviewed are listed in the Attachment to this report. This inspection constituted three PMT samples as defined in IP 71111.19-05.

14 b. Findings No findings were identified. 1R20 Outage Activities (71111.20) .1 Refueling Outage Activities a. Inspection Scope The inspectors reviewed the Outage Safety Plan (OSP) and contingency plans for the Unit 1 refueling outage (RFO), that began on March 27, 2017, and continued through the end of this inspection period, to confirm that the licensee had appropriately considered risk, industry experience, and previous site-specific problems in developing and

implementing a plan that assured maintenance of defense-in-depth. During the RFO,

the inspectors observed portions of the shutdown and cooldown processes and monitored licensee controls over the outage activities listed below:

licensee configuration management, including maintenance of defense-in-depth commensurate with the OSP for key safety functions and compliance with the applicable TS when taking equipment out of service;

installation and configuration of reactor coolant pressure, level, and temperature instruments to provide accurate indication, accounting for instrument error;

controls over the status and configuration of electrical systems to ensure that TS and OSP requirements were met, and controls over switchyard activities;

monitoring of decay heat removal processes, systems, and components;

controls to ensure that outage work was not impacting the ability of the operators to operate the spent fuel pool cooling system;

reactor water inventory controls including flow paths, configurations, and alternative means for inventory addition, and controls to prevent inventory loss;

controls over activities that could affect reactivity;

maintenance of secondary containment as required by TS;

refueling activities; and

licensee identification and resolution of problems related to RFO activities.

Documents reviewed are listed in the Attachment to this report. This inspection constituted a partial RFO sample and continued into the next inspection

period. b. Findings No findings were identified. 1R22 Surveillance Testing (71111.22) .1 Surveillance Testing a. Inspection Scope The inspectors reviewed the test results for the following activities to determine whether risk-significant systems and equipment were capable of performing their intended safety

15 function and to verify testing was conducted in accordance with applicable procedural

and TS requirements:

QCIS 1000-09: RHR Pump Discharge Pressure Calibration and Functional Test (Routine);

QCOS 6600-37(39): Unit 1(2) EDG Largest Load Reject Surveillance (Routine);

QCOS 6600-44: Unit 1 EDG Timed Start Test (Routine)

QCOS 1000-43: Unit 2 'A' Loop Low Pressure Coolant Injection (LPCI) and Containment Cooling Modes of RHRs Non-Outage Logic Test (Routine);

QCOS 1400-16: Unit 1 Division II Core Spray Logic Functional Test (Routine);

and * QCOS 1400-09: Core Spray Pressure Isolation Valve Seat Leakage Test (In-service Test). The inspectors observed in-plant activities and reviewed procedures and associated records to determine the following:

did preconditioning occur;

the effects of the testing were adequately addressed by control room personnel or engineers prior to the commencement of the testing;

acceptance criteria were clearly stated, demonstrated operational readiness, and were consistent with the system design basis;

plant equipment calibration was correct, accurate, and properly documented;

as-left setpoints were within required ranges; and the calibration frequency was in accordance with TSs, the USAR, procedures, and applicable commitments;

measuring and test equipment calibration was current;

test equipment was used within the required range and accuracy; applicable prerequisites described in the test procedures were satisfied;

test frequencies met TS requirements to demonstrate operability and reliability; tests were performed in accordance with the test procedures and other applicable procedures; jumpers and lifted leads were controlled and restored where used;

test data and results were accurate, complete, within limits, and valid;

test equipment was removed after testing;

where applicable for inservice testing activities, testing was performed in accordance with the applicable version of Section XI, American Society of Mechanical Engineers code, and reference values were consistent with the

system design basis;

where applicable, test results not meeting acceptance criteria were addressed

with an adequate operability evaluation or the system or component was declared

inoperable;

where applicable for safety-related instrument control surveillance tests, reference setting data were accurately incorporated in the test procedure;

where applicable, actual conditions encountering high resistance electrical contacts were such that the intended safety function could still be accomplished;

prior procedure changes had not provided an opportunity to identify problems encountered during the performance of the surveillance or calibration test;

equipment was returned to a position or status required to support the performance of its safety functions; and

all problems identified during the testing were appropriately documented and dispositioned in the CAP.

16 Documents reviewed are listed in the Attachment to this report. This inspection constituted five routine surveillance testing samples, and one in-service test sample as defined in IP 71111.22, Sections-02 and-05.

b. Findings No findings were identified. 1EP2 Alert and Notification System Evaluation (71114.02) .1 Alert and Notification System Evaluation a. Inspection Scope The inspectors reviewed documents and held discussions with Emergency Preparedness (EP) staff regarding the operation, maintenance, and periodic testing of the primary and backup Alert and Notification System (ANS) in the plume pathway

Emergency Planning Zone. The inspectors reviewed monthly trend reports and siren

test failure records from July 2015 to February 2017. Information gathered during

document reviews and interviews were used to determine whether the ANS equipment was maintained and tested in accordance with Emergency Plan commitments and procedures. Documents reviewed are listed in the Attachment to this report. This ANS evaluation inspection constituted one sample as defined in IP 71114.02-06. b. Findings No findings were identified. 1EP3 Emergency Response Organization Staffing and Augmentation System (71114.03) .1 Emergency Response Organization Staffing and Augmentation System a. Inspection Scope The inspectors reviewed and discussed with plant EP management and staff the Emergency Plan commitments and procedures that addressed the primary and alternate

methods of initiating an Emergency Response Organization (ERO) activation to augment

the on-shift staff as well as the provisions for maintaining the plant's ERO team and

qualification lists. The inspectors reviewed reports and a sample of CAP records of unannounced off-hour augmentation drills, which were conducted from July 2015 to February 2017, to determine the adequacy of the drill critiques and associated corrective

actions. The inspectors also reviewed a sample of the training records of approximately

six ERO personnel, who were assigned to key and support positions, to determine the

status of their training as it related to their assigned ERO positions. Documents

reviewed are listed in the Attachment to this report. This ERO augmentation testing inspection constituted one sample as defined in

IP 71114.03-06. b. Findings No findings were identified.

17 1EP5 Maintenance of Emergency Preparedness (71114.05) .1 Maintenance of Emergency Preparedness a. Inspection Scope The inspectors reviewed the nuclear oversight staff's April 2016 audit of the Quad Cities Nuclear Power Station's Emergency Preparedness Program to determine that the

independent assessments met the requirements of 10 CFR 50.54(t). The inspectors

reviewed samples of CAP records associated with the 2016 biennial exercise, as well as

various EP drills conducted in 2016, in order to determine whether the licensee fulfilled

drill commitments and to evaluate the licensee's efforts to identify and resolve identified issues. The inspectors reviewed a sample of EP items and corrective actions related to the station's EP program, and activities to determine whether corrective actions were

completed in accordance with the site's CAP. Documents reviewed are listed in the Attachment to this report. This maintenance of EP inspection constituted one sample as defined in

IP 71114.05-06. b. Findings No findings were identified. 1EP6 Drill Evaluation (71114.06) .1 Emergency Preparedness Drill Observation a. Inspection Scope The inspectors evaluated the conduct of a routine licensee emergency drill on February 15, 2017, to identify any weaknesses and deficiencies in classification, notification, and protective action recommendation development activities. The

inspectors observed emergency response operations in the technical support center and

operations support center to determine whether the event classification, notifications,

and protective action recommendations were performed in accordance with procedures.

The inspectors also attended the licensee drill critique to compare any inspector-observed weakness with those identified by the licensee staff in order to evaluate the critique and to verify whether the licensee staff was properly identifying

weaknesses and entering them into the corrective action program. As part of the

inspection, the inspectors reviewed the drill package and other documents listed in the Attachment to this report. This EP drill inspection constituted one sample as defined in IP 71114.06-06. b. Findings No findings were identified.

18 2. RADIATION SAFETY 2RS1 Radiological Hazard Assessment and Exposure Controls (71124.01) .1 Radiological Hazard Assessment (02.02) a. Inspection Scope The inspectors assessed the licensee's current and historic isotopic mix, including alpha emitters and other hard-to-detect radionuclides. The inspectors evaluated whether survey protocols were reasonable to identify the magnitude and extent of the radiological

hazards. The inspectors determined if there have been changes to plant operations since the last inspection that may have resulted in a significant new radiological hazard for onsite

individuals. The inspectors evaluated whether the licensee assessed the potential

impact of these changes and implemented periodic monitoring, as appropriate, to detect and quantify the radiological hazard. The inspectors reviewed the last two radiological surveys from selected plant areas

and evaluated whether the thoroughness and frequency of the surveys were appropriate for the given radiological hazard. The inspectors conducted walkdowns of the facility, including radioactive waste processing, storage, and handling areas to evaluate material conditions and performed

independent radiation measurements as needed to verify conditions were consistent

with documented radiation surveys. The inspectors assessed the adequacy of pre-work surveys for select radiologically risk-significant work activities. The inspectors evaluated the radiological survey program to determine if hazards were properly identified. The inspectors discussed procedures, equipment, and performance of surveys with radiation protection staff and assessed whether technicians were knowledgeable about when and how to survey areas for various types of radiological

hazards. The inspectors reviewed work in potential airborne areas to assess whether air samples were being taken appropriately for their intended purpose and reviewed various survey

records to assess whether the samples were collected and analyzed appropriately. The

inspectors also reviewed the licensee's program for monitoring contamination which has

the potential to become airborne. These inspection activities constituted one complete sample as defined in

IP 71124.01-05. b. Findings No findings were identified.

19 .2 Instructions to Workers (02.03) a. Inspection Scope The inspectors reviewed select radiation work permits used to access high radiation areas and evaluated the specified work control instructions or control barriers. The

inspectors also assessed whether workers where made aware of the work instructions and area dose rates. The inspectors reviewed electronic alarming dosimeter dose and dose rate alarm setpoint methodology. For selected electronic alarming dosimeter occurrences, the

inspectors assessed the worker's response to the alarm, the licensee's evaluation of the

alarm, and any follow-up investigations. The inspectors reviewed the licensee's methods for informing workers of changes in plant operations or radiological conditions that could significantly impact their occupational dose. The inspectors reviewed the labeling of select containers of licensed radioactive material that could cause unplanned or inadvertent exposure to workers. These inspection activities constituted one complete sample as defined in

IP 71124.01-05. b. Findings No findings were identified. .3 Contamination and Radioactive Material Control (02.04) a. Inspection Scope The inspectors observed locations where the licensee monitors material leaving the radiologically controlled area and assessed the methods used for control, survey, and release of material from these areas. As available, the inspectors observed health

physics personnel surveying and releasing material for unrestricted use. The inspectors observed workers leaving the radiologically controlled area and assessed their use of tool and personal contamination monitors and reviewed the licensee's criterial for use of the monitors. The inspectors assessed whether instrumentation was used at its typical sensitivity levels based on appropriate counting parameters or whether the licensee had established a de facto release limit. The inspectors selected several sealed sources from the licensee's inventory records and assessed whether the sources were accounted for and verified to be intact. The

inspectors also evaluated whether any transactions, since the last inspection, involving nationally tracked sources were reported in accordance with 10 CFR 20.2207. These inspection activities constituted one complete sample as defined in

IP 71124.01-05.

20 b. Findings No findings were identified. .4 Radiological Hazards Control and Work Coverage (02.05) a. Inspection Scope The inspectors evaluated ambient radiological conditions during tours of the facility. The inspectors assessed whether the conditions were consistent with applicable posted surveys, radiation work permits, and worker briefings. The inspectors evaluated the adequacy of radiological controls, such as required surveys, radiation protection job coverage, and contamination controls. The inspectors evaluated the licensee's use of electronic alarming dosimeters in high noise areas as high radiation area monitoring devices. The inspectors assessed whether radiation monitoring devices were placed on the individual's body consistent with licensee procedures. The inspectors assessed whether

the dosimeter was placed in the location of highest expected dose or that the licensee properly employed a U.S. Nuclear Regulatory Commission approved method of determining effective dose equivalent. The inspectors reviewed the application of dosimetry to effectively monitor exposure to personnel in work areas with significant dose rate gradients. For select airborne area radiation work permits, the inspectors reviewed airborne radioactivity controls and monitoring, the potential for significant airborne levels, containment barrier integrity, and temporary filtered ventilation system operation. The inspectors examined the licensee's physical and programmatic controls for highly activated or contaminated materials stored within pools and assessed whether

appropriate controls were in place to preclude inadvertent removal of these materials

from the pool. These inspection activities constituted one complete sample as defined in

IP 71124.01-05. b. Findings No findings were identified. .5 High Radiation Area and Very High Radiation Area Controls (02.06) a. Inspection Scope The inspectors observed posting and physical controls for high radiation areas and very high radiation areas to assess adequacy. The inspectors conducted a selective inspection of posting and physical controls for high radiation areas and very high radiation areas to assess conformance with performance

indicators.

21 The inspectors reviewed procedural changes to assess the adequacy of access controls for high and very high radiation areas to determine whether procedural changes substantially reduced the effectiveness and level of worker protection. The inspectors assessed the controls the high radiation areas greater than 1 rem/hour and areas with the potential to become high radiation areas greater than 1 rem/hour for

compliance with TS and procedures. The inspectors assessed the controls for very high radiation areas and areas with the potential to become very high radiation areas. The inspectors also assessed whether individuals were unable to gain unauthorized access to these areas. These inspection activities constituted one complete sample as defined in

IP 71124.01-05. b. Findings No findings were identified. .6 Radiation Worker Performance and Radiation Protection Technician Proficiency (02.07) a. Inspection Scope The inspectors observed radiation worker performance and assessed their performance with respect to radiation protection work requirements, the level of radiological hazards present and radiation work permit controls. The inspectors assessed worker awareness of electronic alarming dosimeter set points, stay times or permissible dose for radiologically significant work as well as expected response to alarms. The inspectors observed radiation protection technician performance and assessed whether the technicians were aware of the radiological conditions and radiation work

permit controls and whether their performance was consistent with training and qualifications for the given radiological hazards. The inspectors observed radiation protection technician performance of radiation surveys and assessed the appropriateness of the instruments being used, including calibration and source checks. These inspection activities constituted one complete sample as defined in

IP 71124.01-05. b. Findings No findings were identified. .7 Problem Identification and Resolution (02.08) a. Inspection Scope The inspectors assessed whether problems associated with radiological hazard assessment and exposure controls were being identified at an appropriate threshold and

22 were properly addressed for resolution. For select problems, the inspectors assessed the appropriateness of the corrective actions. The inspectors also assessed the licensee's program for reviewing and incorporating operating experience. The inspectors reviewed select problems related to human performance errors and assessed whether there was a similar cause and whether corrective actions taken

resolve the problems. The inspectors reviewed select problems related to radiation protection technician error

and assessed whether there was a similar cause and whether corrective actions taken

resolve the problems. These inspection activities constituted one complete sample as defined in

IP 71124.01-05. b. Findings No findings were identified. 2RS2 Occupational As-Low-As-Reasonably-Achievable Planning and Controls (71124.02) .1 Implementation of As-Low-As-Reasonably-Achievable and Radiological Work Controls

(02.04) a. Inspection Scope The inspectors conducted observations of in-plant work activities and assessed whether the licensee had effectively integrated the planned administrative, operational, and engineering controls into the actual field work to maintain occupational exposure As-Low-As-Reasonably-Achievable (ALARA). The inspectors observed pre-job briefings and determined if the planned controls were discussed with workers. The inspectors

evaluated the placement and use of shielding, contamination controls, airborne controls,

radiation work permit controls and other engineering work controls against the ALARA

plans. These inspection activities supplemented those documented in NRC Integrated Inspection Report 05000254/2016002 and 05000265/2016002 and constituted a partial

sample as defined in IP 71124.02-05. b. Findings No findings were identified. .2 Radiation Worker Performance (02.05) a. Inspection Scope The inspectors observed radiation worker and radiation protection technician performance during work activities being performed in radiation areas, airborne

radioactivity areas, or high radiation areas to assess whether workers demonstrated

the ALARA philosophy in practice and followed procedures. The inspectors observed radiation worker performance to evaluate whether the training and skill level was sufficient with respect to the radiological hazards and the work involved.

23 The inspectors interviewed individuals from selected work groups to assess their knowledge and awareness of planned and/or implemented radiological and ALARA work controls. These inspection activities supplemented those documented in NRC Integrated Inspection Report 05000254/2016002 and 05000265/2016002 and constituted a partial

complete sample as defined in IP 71124.02-05. b. Findings No findings were identified. 2RS3 In-Plant Airborne Radioactivity Control and Mitigation (71124.03) .1 Engineering Controls (02.02) a. Inspection Scope The inspectors reviewed procedural guidance for use of ventilation systems and assessed whether the systems were used, to the extent practicable, during high-risk

activities to control airborne radioactivity and minimize the use of respiratory protection.

The inspectors assessed whether installed ventilation airflow capacity, flow path, and

filter/charcoal unit efficiencies for selected systems were consistent with maintaining concentrations of airborne radioactivity in work areas below the concentrations of an airborne area to the extent practicable. The inspectors also evaluated whether selected

temporary ventilation systems used to support work in contaminated areas were consistent with licensee procedural guidance and ALARA. These inspection activities supplemented those documented in NRC Integrated Inspection Report 05000254/2016002 and 05000265/2016002 and constituted one complete sample as defined in IP 71124.03-05. b. Findings No findings were identified. .2 Use of Respiratory Protection Devices (02.03) a. Inspection Scope The inspectors reviewed records of air testing for supplied-air devices and self-contained breathing apparatus (SCBA) bottles to assess whether the air used met or exceeded

Grade D quality. The inspectors evaluated whether plant breathing air supply systems satisfied the minimum pressure and airflow requirements for the devices. The inspectors reviewed training curricula for use of respiratory protection devices to assess whether individuals are adequately trained on donning, doffing, function checks, and how to respond to a malfunction.

24 The inspectors observed the physical condition of respiratory protection devices ready for issuance and reviewed records of routine inspection for selected devices. The

inspectors reviewed records of maintenance on the vital components for selected devices and assessed whether onsite personnel assigned to repair vital components received vendor-provided training. These inspection activities supplemented those documented in NRC Integrated Inspection Report 05000254/2016002 and 05000265/2016002 and constituted one complete sample as defined in IP 71124.03-05. b. Findings No findings were identified. .3 Self-Contained Breathing Apparatus for Emergency Use (02.04) a. Inspection Scope The inspectors reviewed the status and surveillance records for select SCBAs. The inspectors evaluated the licensee's capability for refilling and transporting SCBA air bottles to and from the control room and operations support center during emergency

conditions. The inspectors assessed whether control room operators and other emergency response and radiation protection personnel were trained and qualified in the use of

SCBAs and evaluated whether personnel assigned to refill bottles were trained and qualified for that task. The inspectors assessed whether appropriate mask sizes and types were available for use. The inspectors evaluated whether on-shift operators had no facial hair that would

interfere with the sealing of the mask and that appropriate vision correction was

available. The inspectors reviewed the past two years of maintenance records for selected in service SCBA units used to support operator activities during accident conditions. The inspectors assessed whether maintenance or repairs on an SCBA unit's vital

components were performed by an individual cert

ified by the manufacturer of the device to perform the work. The inspectors evaluated the onsite maintenance procedures

governing vital component work to determine whether there was any inconsistencies with the SCBA manufacturer's recommended practices. The inspectors evaluated whether SCBA cylinders satisfied the hydrostatic testing required by the U.S. Department of Transportation. These inspection activities constituted one complete sample as defined in

IP 71124.03-05. b. Findings No findings were identified.

25 .4 Problem Identification and Resolution (02.05) a. Inspection Scope The inspectors assessed whether problems associated with the control and mitigation of in-plant airborne radioactivity were being identified by the licensee at an appropriate threshold and were properly addressed for resolution. Additionally, the inspectors

evaluated the appropriateness of the corrective actions for selected problems involving airborne radioactivity documented by the licensee. These inspection activities constituted one complete sample as defined in

IP 71124.03-05. b. Findings No findings were identified. 2RS4 Occupational Dose Assessment (71124.04) .1 External Dosimetry (02.03) a. Inspection Scope The inspectors evaluated the calibration of active dosimeters. The inspectors assessed the bias of the active dosimeters compared to passive dosimeters and the correction

factor used. The inspectors also assessed the licensee's program for comparing active

and passive dosimeter results, investigations for substantial differences, and recording

of dose. The inspectors assessed whether there were adverse trends for active

dosimeters. These inspection activities supplemented those documented in NRC Integrated Inspection Report 05000254/2016003 and 05000265/2016003 and constituted one complete sample as defined in IP 71124.04-05. b. Findings No findings were identified. .2 Internal Dosimetry (02.04) a. Inspection Scope The inspectors reviewed procedures used to determine internal dose using in vitro analysis to assess the adequacy of sample collection, determination of entry route and assignment of dose. The inspectors reviewed the licensee's program for dose assessment based on air sampling, as applicable, and calculations of derived air concentration. The inspectors determined whether flow rates and collection times for air sampling equipment were adequate to allow lower limits of detection to be obtained. The inspectors also reviewed

the adequacy of procedural guidance to assess internal dose if respiratory protection

was used.

26 These inspection supplemented those documented in NRC Integrated Inspection Report 05000254/2016003 and 05000265/2016003 and constituted one complete sample as defined in IP 71124.04-05. b. Findings No findings were identified. .3 Special Dosimetric Situations (02.05) a. Inspection Scope The inspectors assessed whether the licensee informs workers of the risks of radiation exposure to the embryo/fetus, the regulatory aspects of declaring a pregnancy, and the

specific process to be used for declaring a pregnancy. The inspectors selected

individuals who had declared pregnancy during the current assessment period and

evaluated whether the monitoring program for declared pregnant workers was technically adequate to assess the dose to the embryo/fetus. The inspectors assessed results and/or monitoring controls for compliance with regulatory requirements. The inspectors reviewed the licensee's methodology for monitoring external dose in nonuniform radiation fields or where large dose gradients exist. The inspectors

evaluated the licensee's criteria for determining when alternate monitoring was to

be implemented. The inspectors reviewed dose assessments performed using

multibadging to evaluate whether the assess

ment was performed consistently with licensee procedures and dosimetric standards. The inspectors evaluated the licensee's methods for calculating shallow dose equivalent from distributed skin contamination or discrete radioactive particles. The inspectors evaluated the licensee's program for neutron dosimetry, including dosimeter types and/or survey instrumentation. The inspectors reviewed select neutron exposure situations and assessed whether dosimetry and/or instrumentation was

appropriate for the expected neutron spectra, there was sufficient sensitivity, and

neutron dosimetry was properly calibrated. The inspectors also assessed whether

interference by gamma radiation had been accounted for in the calibration and whether

time and motion evaluations were representative of actual neutron exposure events. For the special dosimetric situations reviewed in this section, the inspectors assessed how the licensee assigned dose of record. This included an assessment of external and internal monitoring results, supplementa

ry information on individual exposures, and radiation surveys and/or air monitoring results when dosimetry was based on these techniques. These inspection activities constituted one complete sample as defined in

IP 71124.04-05. b. Findings No findings were identified.

27 .4 Problem Identification and Resolution (02.06) a. Inspection Scope The inspectors assessed whether problems associated with occupational dose assessment were being identified by the licensee at an appropriate threshold and were

properly addressed for resolution. The inspectors assessed the appropriateness of the

corrective actions for a selected sample of problems documented by the licensee involving occupational dose assessment. These inspection constituted one complete sample as defined in IP 71124.04-05. b. Findings No findings were identified. 4. OTHER ACTIVITIES Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity, Emergency Preparedness, Public Radiation Safety, Occupational Radiation Safety, and Security 4OA1 Performance Indicator Verification (71151) .1 Unplanned Scrams per 7000 Critical Hours a. Inspection Scope The inspectors sampled licensee submittals for the Unplanned Scrams per 7000 Critical Hours performance indicator (PI) for Quad Cities Nuclear Power Station, Units 1 and 2, for the period from the first quarter 2016 through the fourth quarter 2016. To determine

the accuracy of the PI data reported during those periods, PI definitions and guidance

contained in the Nuclear Energy Institute (NEI) Document 99-02, "Regulatory

Assessment Performance Indicator Guideline," Revision 7, dated August 31, 2013, were used. The inspectors reviewed the licensee's operator narrative logs, IRs, event reports, and NRC integrated inspection reports for the period of January 1, 2016, through

December 31, 2016, to validate the accuracy of the submittals. The inspectors also

reviewed the licensee's IR database to determine if any problems had been identified

with the PI data collected or transmitted for this indicator, and none were identified. Documents reviewed are listed in the Attachment to this report.

This inspection constituted two unplanned scrams per 7000 critical hours samples as defined in IP 71151-05. b. Findings No findings were identified.

28 .2 Unplanned Scrams with Complications a. Inspection Scope The inspectors sampled licensee submittals for the Unplanned Scrams with Complications PI for Quad Cities Nuclear Power Station, Units 1 and 2, for the period

from the first quarter 2016 through the fourth quarter 2016. To determine the accuracy of the PI data reported during those periods, PI definitions and guidance contained in the

NEI Document 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 7, dated August 31, 2013, were used. The inspectors reviewed the licensee's operator narrative logs, IRs, event reports, and NRC integrated inspection reports for the

period of January 1, 2016 through December 31, 2016, to validate the accuracy of the

submittals. The inspectors also reviewed the licensee's IR database to determine if any problems had been identified with the PI data collected or transmitted for this indicator, and none were identified. Documents reviewed are listed in the Attachment to this

report. This inspection constituted two unplanned scrams with complications samples as defined in IP 71151-05. b. Findings No findings were identified. .3 Unplanned Power Changes per 7000 Critical Hours a. Inspection Scope The inspectors sampled licensee submittals for the Unplanned Transients per 7000 Critical Hours PI for Quad Cities Nuclear Power Station, Units 1 and 2, for the

period from the first quarter 2016 through the fourth quarter 2016. To determine the accuracy of the PI data reported during those periods, PI definitions and guidance contained in the NEI Document 99-02, "Regulatory Assessment Performance Indicator

Guideline," Revision 7, dated August 31, 2013, were used. The inspectors reviewed the

licensee's operator narrative logs, IRs, maintenance rule records, event reports, and

NRC integrated inspection reports for the period of January 1, 2016 through December 31, 2016 to validate the accuracy of the submittals. The inspectors also reviewed the licensee's issue report database to determine if any problems had been

identified with the PI data collected or transmitted for this indicator, and none were identified. Documents reviewed are listed in the Attachment to this report. This inspection constituted two unplanned transients per 7000 critical hours samples as defined in IP 71151-05. b. Findings No findings were identified.

29 .4 Drill and Exercise Performance a. Inspection Scope The inspectors sampled licensee submittals for the Drill and Exercise Performance (DEP) Indicator for the fourth quarter 2016. To determine the accuracy

of the PI data reported during that period, PI definitions and guidance contained in the

NEI Document 99-02, "Regulatory Assessment PI Guideline," Revision 7, were used.

The inspectors reviewed the licensee's records associated with the PI to verify that the licensee accurately reported the DEP indicator, in accordance with relevant procedures and NEI guidance. Specifically, the inspectors reviewed licensee records and

processes, including procedural guidance on assessing opportunities for the PI;

assessments of PI opportunities during pre-designated control room simulator training

sessions; performance during the 2016 biennial exercise; and performance during other

drills. Documents reviewed are listed in the Attachment to this report. This inspection constitutes one DEP sample as defined in IP 71151-05. b. Findings No findings were identified. .5 Emergency Response Organization Drill Participation a. Inspection Scope The inspectors sampled licensee submittals for the ERO Drill Participation PI for the fourth quarter of 2016. To determine the accuracy of the PI data reported during that

period, PI definitions and guidance contained in NEI Document 99-02, "Regulatory

Assessment PI Guideline," Revision 7, were used. The inspectors reviewed the

licensee's records associated with the PI to verify that the licensee accurately reported the indicator, in accordance with relevant procedures and NEI guidance. Specifically, the inspectors reviewed licensee records and processes, including procedural guidance

on assessing opportunities for the PI; participation during the 2016 biennial exercise and

other drills; and revisions of the roster of personnel assigned to key ERO positions. Documents reviewed are listed in the Attachment to this report. This inspection constitutes one ERO drill participation sample as defined in

IP 71151-05. b. Findings No findings were identified. .6 Alert and Notification System Reliability a. Inspection Scope The inspectors sampled licensee submittals for the ANS PI for the fourth quarter of 2016. To determine the accuracy of the PI data reported during that period, PI

definitions and guidance contained in NEI Document 99-02, "Regulatory Assessment

PI Guideline," Revision 7, were used. The inspectors reviewed the licensee's records

associated with the PI to verify that the licensee accurately reported the indicator, in

30 accordance with relevant procedures and NEI guidance. Specifically, the inspectors reviewed licensee records and processes, including procedural guidance on

assessing opportunities for the PI and results of periodic ANS operability tests.

Documents reviewed are listed in the Attachment to this report. This inspection constitutes one ANS sample as defined in IP 71151-05. b. Findings No findings were identified. 4OA2 Identification and Resolution of Problems (71152) .1 Routine Review of Items Entered into the Corrective Action Program a. Inspection Scope As discussed in previous sections of this report, the inspectors routinely reviewed issues during baseline inspection activities and plant status reviews to verify they were being entered into the licensee's CAP at an appropriate threshold, adequate attention was

being given to timely corrective actions, and adverse trends were identified and addressed. Some minor issues were entered into the licensee's CAP as a result of the inspectors' observations; however, they are not discussed in this report. These routine reviews for the identification and resolution of problems did not constitute any additional inspection samples. Instead, by procedure they were considered an

integral part of the inspections performed during the quarter. b. Findings No findings were identified. .2 Annual Follow-up of Selected Issues a. Inspection Scope The inspectors selected the following issues and condition reports for in-depth review:

IR 3967424, "Unit 1C RHRSW Pump Abnormal Indications;"

Aggregate review of operator burdens; and

IR 3985153, "Core Spray Keep Fill Valve 1-1402-64B, Stuck." As appropriate, the inspectors verified the following attributes during their review of the licensee's corrective actions for the above condition reports and other related condition

reports: * complete and accurate identification

of the problem in a timely manner commensurate with its safety significance and ease of discovery;

consideration of the extent of condition, generic implications, common cause, and previous occurrences;

evaluation and disposition of operability/functionality/reportability issues;

31 * classification and prioritization of the resolution of the problem commensurate with safety significance;

identification of the root and contributing causes of the problem; and

identification of corrective actions, which were appropriately focused to correct the

problem; * completion of corrective actions in a timely manner commensurate with the safety significance of the issue;

effectiveness of corrective actions taken to preclude repetition;

evaluate applicability for operating experience and communicate applicable lessons learned to appropriate organizations. The inspectors discussed the corrective actions and associated evaluations with licensee personnel. This review constituted three in-depth problem identification and resolution inspection samples as defined in IP 71152. b. Findings (1) Failure to Ensure Hardware Secure for Breaker Mechanism Operated Contact Switch

Linkage Introduction: A finding of very low safety significance and an associated NCV of 10 CFR 50, Appendix B, Criterion V, was self-revealed on January 27, 2017, when the Unit 1C RHRSW pump was started for a routine surveillance evolution and all expected annunciators and equipment failed to operate properly. This led to the licensee

declaring the Unit 1C RHRSW pump inoperable. Specifically, the licensee failed to

establish a procedure for the mechanism operated contact (MOC) switch linkage arm

that was appropriate to the circumstances (i.e. ensure the component would continue to

perform its function). Description: On January 27, 2017, the licens

ee started the Unit 1C RHRSW pump to support a RHR pump surveillance. Upon starting the pump, the control room received an RHRSW pump trip alarm. Equipment operators in the field reported that the 1C

RHRSW pump was running; however, room cooler fans for the pump were not operating

and the breaker light indication for the pump at Bus 14 was not lit. The licensee then

verified the breakers for the pump room cool

er fans were closed. Consequently, the licensee secured the RHR and RHRSW pumps, declared the Unit 1C RHRSW pump inoperable, and began troubleshooting the issue. The licensee's troubleshooting revealed that the linkage for the Unit 1C RHRSW pump breaker MOC switch had become disconnected. This prevented the MOC switch, which

controls other component functions (e.g. alarms and room cooler fan operation) through the use of auxiliary contacts, from functioning as expected. The licensee's equipment CAP evaluation identified that the licensee's procedure for periodic inspection of the breaker cubicle lacked specific guidance to ensure the MOC

switch linkage assembly hardware was adequately fastened. Specifically, the licensee's procedures for performing maintenance and inspections of 4 kilo-volt (kV) breakers lacked appropriate acceptance criteria or instructions that would ensure the linkage arm

for the MOC switch would not come loose during repeated breaker cycling. The

32 procedure, QCEPM 0200-11, "Inspection and Maintenance of Horizontal 4kV Cubicles," Section 4.5.9.1, directed the user to "Verify MOC switch linkage hardware is in place and

tight." The procedure did not specify a method for ensuring the hardware was tight. The licensee implemented corrective actions to establish appropriate instructions (i.e. mechanically verify tightness by using a tool, etc.) to ensure the MOC switch linkage would remain properly secured. Analysis: The inspectors determined that the licensee's failure to establish a procedure for the MOC switch linkage arm that was appropriate to the circumstances (i.e. ensure the component would continue to perform its function) was contrary to 10 CFR 50,

Appendix B, Criterion V, "Instructions, Procedures, and Drawings," and was a

performance deficiency. The performance deficiency was determined to be more than minor because the finding was associated with the Mitigating Syst

ems cornerstone attribute of equipment performance and affected the cornerstone objective of ensuring the availability,

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

undesirable consequences. Specifically, the failure to ensure the MOC switch linkage

arm was adequately fastened led to the failure of the component and its associated 1C RHRSW pump during breaker operation on January 27, 2017. Using Inspection Manual Chapter (IMC) 0609, Attachment 4, "Initial Characterization of Findings," and IMC 0609, Appendix A, "The Significance Determination Process for Findings at Power," issued June 19, 2012, the finding was screened against the

Mitigating Systems cornerstone and determined to be of very low safety significance (Green), because the inspectors answered "No" to all of the questions in Exhibit 2,

"Mitigating Systems Screening Questions," Section A, "Mitigating SSCs and Functionality."

The inspectors determined this finding affected the cross-cutting area of human

performance, in the aspect of avoid complacency, which states, "Individuals recognize

and plan for the possibility of mistakes, latent issues, and inherent risk, even while

expecting successful outcomes." Specifically, the licensee failed to recognize a potential risk and inherent latent issue for a condition identified in 2015 at Quad Cities, when a MOC switch failed to perform its function due to a missing nut in a different breaker's

linkage assembly. The licensee identified and corrected the condition, but failed to

evaluate the cause of the missing nut because it did not impact the operability of the

component. In the 2015 instance, the MOC switch issue only affected indications for the

component and had no adverse impact on the ability of the component to perform its

function [H.12]. Enforcement: Title 10 CFR Part 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," requires, in part, that activities affecting quality be prescribed by documented procedures of a type appropriate to the circumstances and be

accomplished in accordance with these procedures. The licensee established

QCEPM 0200-11, "Inspection and Maintenance of Horizontal 4kV Cubicles,"

Revision 37, as the implementing procedure for performing inspections and maintenance

on 4kV safety-related breaker cubicles, an activity affecting quality. Contrary to the above, prior to January 27, 2017, licensee procedure QCEPM 0200-11 failed to be of a type appropriate to the circumstances. Specifically, procedure

33 QCEPM 0200-11 did not contain instruction to ensure that the MOC switch linkage arm was adequately fastened and would continue to perform its function. On

January 27, 2017, during operation of the 1C RHRSW pump breaker, the MOC switch linkage arm became disconnected, preventing the MOC switch from performing its function, and led the licensee to declare the 1C RHRSW pump inoperable. The licensee's corrective actions included reconnecting the MOC switch linkage arm assembly and testing it by starting the

1C RHRSW pump prior to declaring the pump operable. In addition, the licensee planned procedure revisions to QCEPM 0200-11 that

would specify a torque value to ensure the MOC switch linkage arm was adequately

secured and could perform its function. Because the violation was of very low safety significance and was entered into the licensee's CAP as IR 3967424, this violation is being treated as a NCV, consistent with Section 2.3.2 of the Enforcement Policy. (NCV 05000254/2017001-01; 05000265/2017001-01; Failure to Ensure Hardware Secure for Breaker MOC Switch Linkage)

4OA3 Follow-Up of Events and Notices of Enforcement Discretion (71153) .1 Unit 2 Alert Declared Following a Fire that Caused Damage to 'E' Automatic Depressurization System Indication and Control Circuitry a. Inspection Scope The inspectors reviewed the plant's response to a small fire in the Unit 2 control room panel that caused damage to the 'E' automatic depressurization system (ADS) electromatic relief valve (ERV) indication and control circuitry. At approximately 7:29 p.m. on February 1, 2017, a reactor operator was changing the closed-light indication light bulb on Unit 2 'E' ADS valve, 2-0203-3E. After inserting the new bulb with a bulb tool (a rubber sleeve that holds the small bulb), the operator

noticed sparking, and attempted to remove the bulb. When he removed the light, the

bulb had separated from the base, leaving the base in the light socket. The reactor

operator noticed arcing continued and went to the back of the control panel and identified a flame in the underside of the panel. Another operator in the control room

retrieved a fire extinguisher and discharged a short burst to extinguish the flame, the flame was out at 7:32 p.m. No equipment operated and no annunciators were received.

The Unit 2 supervisor declared the 'E' ADS valve inoperable and the licensee entered

Limiting Conditions for Operation (LCOs) 3.4.3, "RCS Safety and Relief Valves," Condition A, for one relief valve inoperable and LCO 3.5.1, "ECCS [Emergency Core Cooling Systems]-Operating," Condition H, for one ADS valve inoperable. The

licensee subsequently declared an ALERT at 7:38 p.m. for Emergency Action

Level MA5, "Hazardous event affecting a SAFETY SYSTEM required for the current

operating mode." Specifically, the Emergency Action Level conditions present were: a "FIRE AND the event caused VISIBLE DAMAGE to a SAFETY SYSTEM component or structure required by TS for the current operating mode."

Following visual inspections of the control panel and verifications that there were no

other equipment issues impacting plant operations, the licensee terminated from the

event at 11:36 p.m on February 1, 2017.

34 Licensee corrective actions included replacing the light sockets and wiring for the open and closed indications for the 'E' ADS valve, in addition to replacing the fuses for both

the normal and alternate power supplies for the control circuitry. The licensee declared the 'E' ADS valve operable on February 2, 2017. Both units remained at full power throughout the event.

The licensee entered this issue into their CAP as IR 3969324, "Light Socket for 2-203-3E

Damaged during Bulb Change," and their root cause evaluation was in-progress at the

end of this inspection period. This event follow-up review, including inspection of the licensee's evaluation of the event and planned corrective actions was in-progress at the end of this inspection period and continued into the next inspection period.

Documents reviewed are listed in the Attachment to this report.

This event follow-up review constituted a partial sample and continued into the next inspection period. b. Findings No findings were identified. .2 (Closed) Licensee Event Report 05000254/2017-001-00: Secondary Containment Interlock Doors Opened Simultaneously On January 24, 2017, the licensee identified that both doors in the secondary containment interlock on the 595' elevation between the reactor building and the Unit 2 reactor feed pump room were opened simultaneously for approximately 3 seconds. This

resulted in the licensee making an unplanned entry into LCO 3.6.4.1, Condition A, for an

inoperable secondary containment. The licensee immediately closed the interlock doors

to reestablish secondary containment and adm

inistratively controlled personnel entry and egress through the doors thereafter. The inspectors determined this issue was minor because secondary containment pressure remained negative throughout the condition, although the event resulted in an unplanned entry into the licensee's TS. The

cause of the event was a dirty contact that caused the interlock relay to stick. Corrective

actions taken by the licensee included inspecting and cleaning of the interlock relay

contacts. The inspectors reviewed the licensee event report (LER). No findings or violations of NRC requirements were identified. This LER is closed. This event follow-up review constituted one sample as defined in IP 71153-05. 4OA5 Other Activities .1 (Closed) NRC Temporary Instruction 2515/192, "Inspection of the Licensee's Interim Compensatory Measures Associated with the Open Phase Condition Design Vulnerabilities in Electric Power Systems" a. Inspection Scope The objective of this performance based Temporary Instruction is to verify implementation of interim compensatory measures associated with an open phase

35 condition (OPC) design vulnerability in electric power system for operating reactors. The inspectors conducted an inspection to determine if the licensee had implemented the following interim compensatory measures. These compensatory measures are to remain in place until permanent automatic detection and protection schemes are installed and declared operable for OPC design vulnerability. The inspectors verified

the following:

The licensee had identified and discussed with plant staff the lessons-learned from the OPC events at the US operating plants, including the Byron station OPC event and its consequences. This included conducting operator training for

promptly diagnosing, recognizing consequences, and responding to an OPC

event. * The licensee had updated plant operating procedures to help operators promptly diagnose and respond to OPC events on off-site power sources credited for safe shutdown of the plant.

The licensee had established and continues to implement periodic walkdown activities to inspect switchyard equipment such as insulators, disconnect switches, and transmission line and transformer connections associated with the

offsite power circuits to detect a visible OPC.

The licensee had ensured that routine maintenance and testing activities on switchyard components have been implemented and maintained. As a part of the maintenance and testing activities, the licensee assessed and managed plant

risk in accordance with 10 CFR 50.65(a)(4) requirements. a. Findings and Observations No findings of significance were identified. The inspectors verified the criteria were met. .2 (Closed) Unresolved Item 05000254/2013003-02; 05000265/2013003-02: Question Concerning Licensing Bases of the Ultimate Heat Sink a. Inspection Scope During the 2013 Triennial Heat Sink Inspection, the inspectors identified an unresolved item (URI) concerning the current licensing bases with respect to failure of Lock and

Dam No. 14 on the Mississippi River. Specifically, the inspectors were concerned that

the licensee had revised its licensing basis as a result of a 1998 UFSAR change without

NRC approval. The licensee's historical documents stated the loss of river event was from a loss of Dam No. 14, whereas the current UFSAR discusses the loss of river event as damage to the lock. However, there was no discussion in the historical documents as

to what caused Dam No. 14 failure or the extent of the failure. Although both causes

result in the river being disconnected from the plant, there would be a significant time

difference as to how long it would be before the river was no longer available to cool plant equipment and the amount of time available for the plant staff to identify and take appropriate actions to address the failure at the dam. The licensee revised the UFSAR to clarify the loss of river event based on the Ashton Study, "Study of Mississippi River Water Stage at Quad Cities Nuclear Power Plant,"

dated April 24, 1998, which was performed to resolve a previous NRC URI with the loss

of dam event. This issue concerned the effects of the ultimate heat sink (UHS)

temperature being above the design temperature limit for several plant components

36 cooled by the service water systems. This issue was documented in NRC Inspection Report 05000254/1998201; 05000265/1998201 (ML9805180380) and subsequently

closed in NRC Inspection Report 05000254/1998019; 05000265/1998019 (ML9812290041). The closure of the 1998 URI was based on the results of the Ashton study, which concluded that the most likely failure of the dam was a navigation event

that would result in the loss of the dam lock. The study concluded that it would take 48

hours for the river level to lower to the point it disconnected from the UHS. In addition,

the study concluded based on the assumed low seismic region where the dam was located, a seismic event would not cause a failure of the dam, but result in the inability to operate the dam's rolling and miter gates. In addition, subsequent to the UFSAR change, the NRC granted Quad Cities an amendment for an extended power uprate,

dated December 21, 2001. The Safety Evaluation Report associated with this

amendment (ML013540222) discussed the loss of dam event using the clarified UFSAR wording of the lock failure as a basis for its approval. Based on the review of historical records and discussions with the Office of Nuclear Reactor Regulation, the inspectors did not identify a concern with the current licensing basis with respect to the failure of Mississippi River Lock and Dam No. 14. As a result, this URI is closed. b. Findings No findings were identified. .3 (Closed) Unresolved Item 05000254/2013003-04; 05000265/2013003-04: Question

Concerning Availability of Dam Following a Seismic Event a. Inspection Scope During the 2013 Triennial Heat Sink Inspection, the inspectors identified a URI concerning the assumed availability of Mississippi River Lock and Dam No.14 following a design bases earthquake event. Discussion in the UFSAR implied the river was considered available during a Design Basis Event (DBE) even though the downstream

dam was not designed or constructed to remain functional during the assumed DBE.

Although the site appeared to be within their licensing bases (assume availability of the

river during a DBE), the inspectors questioned whether this assumption considered actual potential consequences, i.e., the need to assume a loss of dam during a seismic

event. The NRC issued Order EA-12-049, "Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond Design-Basis External Events,"

dated March 12, 2012, which is being addressed by licensees based on the guidance of

NEI 12-06, "Diverse and Flexible Coping Strategies (FLEX) Implementation Guide." Per

Section 5 of the guidance document, the licensee was to address impact on the

availability of the UHS that relies on a non-seismically robust downstream dam to contain water used as the source of water for the UHS. The licensee submitted their response in a letter, "Overall Integrated Plan in Response to March 12, 2012,

Commission Order Modifying Licenses with Regard to Requirements for Mitigation

Strategies for Beyond-Design-Basis Exte

rnal Events (Order Number EA-12-049)," dated February 28, 2013. The NRC reviewed the licensee plan and issued "Quad Cities Nuclear Power Station, Units 1 and 2-Interim Staff Evaluation Relating to Overall

37 Integrated Plan in Response to Order EA-12-049 (Mitigation Strategies)," dated November 22, 2013. The evaluation stated the integrated plan to address the order did

not provide sufficient information to evaluate conformance with NEI 12-06, Consideration 3. As a result, the NRC established Open Item 3.1.1.2.B for licensees to assess a postulated downstream dam failure from a seismic event. In a letter, "Fifth

Six-Month Status Report in Response to March 12, 2012 Commission Order Modifying

Licenses with Regard to Requirements for Mitigation Strategies for Beyond Design-Basis

External Events (Order Number EA-12-049)," dated August 28, 2015, the licensee

documented its proposed actions to address this scenario from a FLEX standpoint. This included designing and installing a single deep well as a seismically qualified source of water for the FLEX mitigation strategy. This single deep well would be fully capable of

supplying both Unit 1 and Unit 2 FLEX requirements simultaneously. The alternate

approach discussed in the letter consisted of a FLEX pump and portable submersible

pump that would take suction from the discharge canal. The discharge canal would supply the necessary backup water supply. Although the discharge canal has not been seismically evaluated, there is reasonable assurance that this water supply will remain available as a source of water following a seismic event effecting the downstream dam

due to the size of the two diffuser pipes which connect to the main channel of the Mississippi River. These actions will be reviewed by the NRC in a safety evaluation to assess the

licensee's response to the order. Since this URI is being addressed by NRC Order EA-12-049, this URI is closed. b. Findings No findings were identified. 4OA6 Management Meetings .1 Exit Meeting Summary On April 11, 2017, the inspectors presented the inspection results to Mr. S. Darin, and other members of the licensee staff. The licensee acknowledged the issues presented. The inspectors confirmed that none of the potential report input discussed was

considered proprietary. .2 Interim Exit Meetings Interim exits were conducted for:

The results of the ultimate heat sink URI inspection was conducted by phone with Mr. T. Petersen, Regulatory Assurance Lead, on February 27, 2017.

The results of the Emergency Preparedness Program inspection were presented to Mr. K. Ohr, Plant Manager, on March 9, 2017.

The results of the Radiation Safety Program review were presented to Mr. S. Darin, Site Vice President, on March 31, 2017.

The results of the ISI inspection were presented to Mr. S. Darin, Site Vice President, and other members of the licensee staff on March 31, 2017.

38 The inspectors confirmed that none of the potential report input discussed was considered proprietary. Proprietary material received during the inspection was returned to the licensee. ATTACHMENT: SUPPLEMENTAL INFORMATION

Attachment SUPPLEMENTAL INFORMATION KEY POINTS OF CONTACT

Licensee S. Darin, Site Vice President

W. Beck, Regulatory Assurance Manager

J. Bries, Operations Support and Services Senior Manager

J. Colgan, Chemistry Supervisor

D. Collins, Radiation Protection Manager

R. Craddick, Performance Improvement Manager H. Dodd, Operations Director G. Harris, Fleet Assessment

R. Hight, Maintenance Director

D. Luebbe, Work Control Manager

T. Petersen, Regulatory Assurance Lead R. Sieprawski, Training Support Manager T. Wojcik, Engineering Manager U.S. Nuclear Regulatory Commission K. Stoedter, Chief, Reactor Projects Branch 1 R. Murray, Senior Resident Inspector K. Carrington, Resident Inspector

Illinois Emergency Management Agency

C. Mathews, IEMA

C. Settles, IEMA

2 LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED

Opened 05000254/2017001-01; 05000265/2017001-01 NCV Failure to Ensure Hardware Secure for Breaker MOC Switch Linkage (Section 4OA2.3)

Closed 05000254/2017001-01; 05000265/2017001-01 NCV Failure to Ensure Hardware Secure for Breaker MOC Switch Linkage (Section 4OA2.3)05000254/2017001-00

LER Secondary Containment Interlock Doors Opened Simultaneously (Section 4OA3.2)

2515/192 05000254/2013003-02; 05000265/2013003-02

TI

URI Inspection of the Licensee Interim Compensatory Measures Associated with the Open Phase Condition Design Vulnerabilities in Electric Power Systems (Section 4OA5.1)

Question Concerning Licensing Bases of the Ultimate

Heat Sink (Section 4OA5.2)05000254/2013003-04; 05000264/2013003-04

URI Question Concerning Availability of Dam Following a

Seismic Event (Section 4OA5.3)

Discussed

None.

3 LIST OF DOCUMENTS REVIEWED The following is a partial list of documents reviewed during the inspection. Inclusion on this list does not imply that the NRC inspector reviewed the documents in their entirety, but rather that

selected sections or portions of the documents were evaluated as part of the overall inspection effort. Inclusion of a document on this list does not imply NRC acceptance of the document or

any part of it, unless this is stated in the body of the inspection report.

Section Number Document Number Description or Title

Revision or

Date Section 1R01

1R01 WC-A-107: Seasonal Readiness-Revision 18 Summary of Changes

1R01 2016 Site Winter Readiness Challenge Meeting 1R01 SVP 16-072 2016-2017 Quad Cities Certification Letter for

Winter Readiness

11/18/2016 1R01 WC-AA-107 Seasonal Readiness 17

Section 1R04

1R04 QCOP 6600-23 Unit 1 Diesel Generator Preparation for Standby

Operation

2 1R04 QCOP 6600-24 Unit 2 Diesel Generator Preparation for Standby

Operation

2 1R04 QOM 2-1300-01 RCIC Valves on Rack 2202-58 Checklist (RCIC

Room) 4 1R04 QOM 2-1300-02 Unit 2 RCIC Valve Checklist 11 1R04 GEK-9597 Chapter 27 1R04 QOM 2-6900-12 250 Vdc Reactor Building MCC 2B Breaker Checklist

7 1R04 QCOS 1000-26 RHR Valve Position Verification 23 1R04 QCOP 1900-23 Unit 1 Fuel Pool Cooling System Startup and

Shutdown 13 Section 1R051R05 FZ 11.2.1 Quad Cites Generating Station Pre-Fire Plan: Unit 1 RB 554'-0" Elev. SW Corner Room-1B

Core Spray

July 2009 1R05 Fire Hazards Analysis Methodology and Assumptions

Revision 21 1R05 FZ 8.2.6.B Unit 1 Turbine Bldg, El. 595'-0" L.P. Heater Bay October

2013 1R05 FZ 8.2.7.B Unit 1 Turbine Bldg. El. 615'-6" LP Heater Bay (East)/D Heater Bay

October 2013 1R05 FZ 8.2.7.C Unit 1/2 Turbine Bldg Mezzanine Floor

Section 1R061R06 IR 2207744 Pan 125 1D RHRSW Vault Penetration LLRT

Exceeds 50 SCFH

09/11/2014 1R06 IR 2386350 High Leakage Rate on 2D RHRSW Vault

Penetration

09/25/2014 1R06 IR 2386366 High Leakage Rate on 2D RHRSW Vault

Penetration

09/25/2014 1R06 IR 2711786 Water in Cable Vaults 09/02/2016

4 1R06 IR 3943664 MK-504 1D RHRSW Vault Penetration Exceeds

50 SCFH 11/21/2016 1R06 IR 3953663 MK-478 1D RHRSW Vault Penetration Exceeds

50 SCFH 11/21/2016 1R06 IR 3974107 NRC ID: Corroded Piping Penetration 02/14/2017 1R06 IR 3974108 NRC ID: Mounting Plate Corroded 02/14/2017 1R06 IR 3974132 NRC ID: 2D RHR SW Pump Oil Bubbler Darker

Than Others

02/14/2017 1R06 IR 3974143 NRC ID: 1B/C RHRSW Vault Door Seal Worn 02/14/2017 1R06 Drawing FL-1 Flood Barriers Basement Floor D 1R06 QCOS 0100-01 Unit 1 RHR Service Water Vault Flood Seal Leakage Testing

1 1R06 QCOS 0100-02 Unit 2 RHR Service Water Vault Flood Seal Leakage Testing

1 1R06 QCTP 0130-14 Evaluation of RHRSW Vault Flood Protection Leakage Test Results

1R06 QCTP 0130-14, Attachment A 1A RHRSW Vault-Evaluation for Condensate Pump Room

08/07/2015 1R06 QCTP 0130-14, Attachment B

1B/C RHRSW Vault-Evaluation for Condensate Pump Room Flood

06/06/2016 1R06 QCTP 0130-14, Attachment D

Evaluation of Flood Barriers Between 1A and

1B/C RHRSW Vaults

08/07/2015 1R06 QCOS 0100-01, Attachment E 1D and 1B/C RHR Service Water Vault Wall 11/18/2016 1R06 QCOS 0100-01, Attachment C 1D RHR Service Water Vault Condensate Pump

Room Wall

11/18/2016 1R06 QCTP 0130-14, Attachment F 2A RHRSW Vault-Evaluation for Condensate Pump Room Flood

06/08/2016 1R06 QCOS 0100-02, Attachment B 2B/C RHR Service Water Vault Condensate Pump Room Wall

09/24/2016 1R06 QCOS 0100-02, Attachment I

Evaluation of Flood Barriers Between 2A and

2B/C RHRSW Vaults

06/07/2016 1R06 QCOS 0100-02, Attachment E 2D and 2B/C RHR Service Water Vault Wall 11/18/2016 1R06 QDC-0030-M-

0772 Determination of Allowable Leakage Rates for RHRSW Vaults Flood Protection

12/01/1998

Section 1R07

1R07 ER-AA-340-

1002 Service Water Heat Exchanger Inspection

Guide 6 1R07 WO 1757717 Clean/Inspect Heat Exchanger Control Room HVAC Train B RCU Condenser

01/11/2017 1R07 EC 39054 Request Torque on End Caps for RCU 0-9400-

102 00 1R07 IR 3962368 'B' Control Room HVAC Inspection Results 01/12/2017

Section 1R08 1R08 IR 2464920 Indications Found during NDE on Reactor Head Vent Piping

03/07/2015 1R08 IR 2465233 PSU-IVVI New Indication on Core Spray Weld

2P4D 03/08/2015

5 1R08 IR 2465734 FME-1" x 1/2" Diameter Round Stock Found in RPV Annulus

03/09/2015 1R08 IR 2466464 FME Historical 3/8" Steel Flat Washer on Top of Tie Rod 03/10/2015 1R08 IR 2267257 FME PSU Ball Bearing Case Found in RPV 03/12/2015 1R08 IR 2467669 PSU Q1R23 IVI Jet Pump 2 & 7 AD-3 Weld Indications

03/12/2015 1R08 IR 2467887 Flange on Piping Is Damaged and Needs

Repair 03/13/2015 1R08 IR 2468353 FME Q1R23 Manual Core Spray Injection Tool Failure 03/13/2016 1R08 IR 2545901 Unit 1 Shroud Weld IVVI Exams Not in Compliance with BRWVIP

08/25/2015 1R08 IR 2682384 Foreign Material Identified in Spent Fuel Pool 06/16/2016 1R08 EC 400050 Evaluation of Q1R23 IVVI Inspection Findings 0 1R08 ER-AA-335-003 Magnetic Particle Examination 7 1R08 ER-AA-335-010 Guidelines for ASME Code Allowable Flaw Evaluation and ASME Code Coverage

Calculations

6 1R08 ER-AA-335-

014-2008 VT-1 Visual Examination in Accordance with ASME 2007 Edition, 2008 Addenda

0 1R08 ER-AA-335-016 VT-3 Visual Examination of Component Supports, Attachments and Interiors of Reactor

Vessels 10 1R08 ER-AA-335-018 Visual Examination of ASME IWE Class MC and Metallic Liners of IWL Class CC Components

12 1R08 ER-AA-335-

1008 Code Acceptance & Recording Criteria for Nondestructive (NDE) Surface Examination

4 1R08 ER-AA-335-F-

02 PDI Generic Procedure for the Ultrasonic Examination of Ferritic Pipe Welds

1 1R08 GEH-PDI-UT-1 PDI Generic Procedure for the Ultrasonic Examination of Ferritic Pipe Welds

10 1R08 NDE Report Q1R24-UT-016 Elbow-Pipe Weld 30A-S11 03/30/2017 1R08 NDE Report Q1R24-UT-017 Elbow-Pipe Weld 30B-S10 03/30/2017 1R08 NDE Report Q1R24-MT-001 Guide with 8 Lugs Welded to Pipe 03/29/2017 1R08 NDE Report Q1R24-MT-004 Variable Spring Can with 4 Lugs Welded to Pipe 03/29/2017 1R08 NDE Report Q1R24-MT-005 Collar-Torus Shell 03/28/2017 1R08 NDE Report 17-

VT3-024 General Visual Examination: ASME IWE (Class MC) Containment and IWL (Class CC) Metallic

Liners 04/10/2017 1R08 NDE Report Q1R24-VT-001 Flued Head Anchor 03/29/2017 1R08 NDE Report Q1R24-VT-015 Box Guide 03/28/2017

6 1R08 NDE Report Q1R24-VT-016 4 Lugs Welded to Pipe 03/29/2017 1R08 NDE Report Q1R24-VT-022 2 Variable Spring Cans 03/29/2017 1R08 PQR 1-50C 01/03/1984 1R08 PQR A-001 10/19/1998 1R08 PQR A-002 03/09/1999 1R08 WO 1636433-01 MM Upgrade U1 Head Vent Line Socket Welds to EPRI 2: 1 Welds

03/12/2015 1R08 WO 1636433-07 MM Contingent-Repair Indication(s) Found During PT Exams

03/11/2015 1R08 WO 1877257-01 MM Re-route Piping as Required to Support New Motor Install

11/20/2015 1R08 WPQ ID No.

V9896 Record No. WPQ22427 11/12/2013 1R08 WPQ ID No. 50 Record No. WPQ12116 07/30/2003 1R08 WPQ ID No.

N1206 Record No. WPQ14848 01/23/2007 1R08 WPQ ID No.

T2733 Record No. WPQ22292 03/15/2012 1R08 WPQ ID No.

T2733 Record No. WPQ21376 03/07/2012 1R08 WPS 1-1-GTSM-PWHT 2 1R08 IR 3990603 NRC Identified-Documentation Issue in Q1R23 90-Day Report

03/28/2017 1R08 IR 3991149 LL Q1R24-NRC In-Office Preparation Week Document Request

03/29/2017 1R08 IR 3991531 Q1R24 ISI Inspection: Issue with ECR 418116 on Material Removed

03/30/2017 1R08 IR 3991743 Q1R24 ISI Inspection: Observation on Procedure CC-AA-407

03/30/2017

Section 1R11 1R11 QCGP 2-1 Normal Unit Shutdown 87 1R11 QCOP 1000-05 Shutdown Cooling Operation 53 1R11 Reactor Shutdown JITT March 2017 1R11 Reactor Start-up JITT March 2017

Section 1R12

1R12 Maintenance Rule Criteria Exceeded

Spreadsheet for DC 8300-01 and DC 8300-02

1R12 System Report Details (Units 1 and 2)-125

Vdc 1R12 Unit 1, DC8300, System Health Report 01/01/2016-

03/31/2016 1R12 Unit 2, DC8300, System Health Report 01/01/2016-

03/31/2016 1R12 EACE 2736223 1A 125 Vdc Charger Ripple Voltage Step

Change During the 4 Hour Load Test

1R12 IR 1646354 901-8 A9 125 Vdc Battery Charger Trip Alarm. 1A Charger On

04/11/2014

7 1R12 IR 1653585 U1 125 Vdc Charger 1A Failed to Meet 125 Vdc & 200 Amps

04/30/2014 1R12 IR 2732501 1A Charger Has a Step Change in AC Ripple

Volts 10/25/2016 1R12 IR 2736593 1A 125 Vdc Battery Would Not Load up to 200 Amps 11/03/2016 1R12 IR 2511446 Received Unexpected Alarm 901-8 A-7, Diesel

Gen 1 Trouble

06/07/2015 1R12 IR 2516072 NRC Question Posed on U-2 EDG Operability 06/17/2015 1R12 IR 2532957 U1 EDG Trouble Alarm Received 07/26/2015 1R12 IR 2591780 Unit 2 EDG Oil Pump Issue 11/24/2015 1R12 IR 2594097 IST Unfavorable Trend: U0 EDG Fuel Oil

Transfer Pump Flow

12/01/2015 1R12 IR 2646558 Spurious 1/2 EDG Engine High Temp Alarm After

S/D 03/28/2016 1R12 IR 2654576 Replace Engine Protective Relays on Unit 1/2

EDG 04/12/2016 1R12 IR 2655056 Replace Field Flash Cutout Relay on Unit 1

EDG 04/13/2016 1R12 IR 2655063 Replace Field Flash Cutout Relay on Unit 1/2

EDG 04/13/2016 1R12 IR 2713622 Re-Evaluate DGCW Operability/EDG HX Flow

Rate Requirements

09/08/2016 1R12 IR 3965676 Received Momentary 1/2 EDG High Temperature 01/23/2017

Section 1R131R13 Work Week 17-02-05 Safety Profile 1R13 Work Week 17-09-12 Safety Profile 1R13 OU-QC-104, Attachment 1 Q1R24 Risk Factor Chart-Mode 4, 5 and

Defueled 03/27-03/31/2017 1R13 Q1R24 Shutdown Safety Report 03/26-

03/31-2017

Section 1R15

1R15 IR 3968961 QCOS 1000-29 Not Completed as Scheduled due to M&TE Issue

02/01/2017 1R15 IR 469542 IM Shop Unaware of Inaccuracies Associated with Fluke 45 Use

03/22/2006 1R15 OE 180293 Calibration Methods Result in Non-Linearity of

Rosemount 1154H Transmitters

05/29/1999 1R15 OE 11896 Test Instrument High Input Impedance Causes

Non-Linearity In Transmitter Calibration at

Arkansas Nuclear One Unit 1

05/25/2000 1R15 IR 3971856 1D RHRSW Trip Fuses Worked Out of Fuse

Holder 02/08/2017 1R15 IR 3967424 1C RHRSW Pump Abnormal Indications 01/27/2017 1R15 IR 3970782 Extent of Condition for IR 3967424 (Cubicle 1-

6705-13-1-1)

02/06/2017 1R15 IR 3969273 Extent of Condition for IR 3967424 (MOC

Switch Hardware Insp)

02/01/2017

8 1R15 IR 3970964 Extent of Condition for IR 3967424 (Cubicle 1-

6703-13-1)

02/06/2017 1R15 ECAP 3971856 1D RHRSW Trip Fuses Worked Out of Fuse

Holder 03/31/2017

Section 1R19

1R19 WO 1961658 RCIC Pump Operability (IST) 01/11/2017 1R19 QCEMS 0210-

02 Battery Charger Testing for Safety Related

125 Vdc Batteries

15 1R19 WO 1846331 2-125 Battery Charger Terminal Board and

Potentiometer EC 402467

01/18/2017 1R19 QCOS 6600-06 Diesel Generator Cooling Water Pump Flow

Rate Test

45 Section 1R20 1R20 QDC-0200-N-

2257 Q1R24 Decay Heat and Related Calculations 0 1R20 QCGP 2-1 Normal Unit Shutdown 87 1R20 Q1R24 Shutdown Safety Plan 0 1R20 Q1R24 Raw Water Management Plan 1R20 QCOP 0201-13 Reactor Level Upper Wide Range Reference

Leg Extension Use and Control

10 1R20 QCOP 0201-14 Reactor Vessel Level Control Using a Local

Pressure Gauge

11 1R20 QCOP 1000-05 Shutdown Cooling Operation 53 1R20 QCOP 1000-44 Alternate Decay Heat Removal 24 1R20 QCOP 6100-33 Unit 1 Main Power Transformer Backfeed

Operation

8 1R20 QCTS 0600-05 Main Steam Isolation Valve Local Leak Rate Test (AO-1(2)-203-1A/B/C/D, AO-1(2)-203-

2A/B/C/D)

17 1R20 IR 3989801 PSU Unit 1 SRM 23 Not Tracking 03/27/2017 1R20 IR 3990176 PSU Q1R24 NRC ID Oil Leak in U1 DW 03/27/2017 1R20 IR 3990198 PSU 1-0203-3D ERV Steady Stream of Water Leakage 03/27/2017 1R20 IR 3990244 Q1R24 PSU MSIV 1-0203-1A LLRT Exceeded

TS Limit 03/27/2017 1R20 IR 3990246 Q1R24 PSU-INBD MSIV 1-0203-1D

Exceeded TS Limit

03/27/2017 1R20 IR 3990247 PSU Q1R24 OUTBD MSIV 1-0203-2C

Exceeded TS Limit

03/27/2017 1R20 IR 3990255 PSU Q1R24: 1-0203-3D ERV Pilot Valve Leaking 03/28/2017 1R20 IR 3990285 PSU Unexpected Rod Block from SDV High

Level 03/28/2017 1R20 IR 3990393 PSU Q1R24 1C RHR Pump Seal Cooler Piping

Clogged 03/28/2017 1R20 IR 3990758 PSU Q1R24 2C Outboard MSIV Found Outside

of 9.8% 03/29/2017 1R20 IR 3990885 PSU Q1R24 1-0220-105B Failed Outage PM

Opening Force Check

03/29/2016

9 1R20 IR 3991086 PSU Q1R24 1A MSIV PMT Leakage Exceeds

TS Limit 03/29/2017 1R20 SPOG: 1-3-C System Planning Operating Guide 11

Section 1R22

1R22 QCIS 1000-09 RHR Pump Discharge Pressure Calibration and Functional Test

9 1R22 IR 3964960 PS 1-1053e Valve Had Slow Leakby 01/20/2017 1R22 QCOS 6600-37 Unit 1 EDG Largest Load Reject Surveillance 31 1R22 QCOS 6600-39 Unit 2 EDG Largest Load Reject Surveillance 29 1R22 QCOS 6600-44 Unit Diesel Generator Timed Start Test 22 1R22 IR 3950031 1/2 EDG Coolant Temperature Switch Alarmed

Below Setpoint

12/06/2016 1R22 IR 3949824 1/2 EDG Did Not Start During QCOP 6600-58

Hot Fast Restart

12/06/2016 1R22 IR 3943740 2nd LVL UV Relay 2-6706-1274-B241 Contacts Found Degraded

11/21/2016 1R22 QCOS 1000-43 Unit 2 'A' Loop Low Pressure Coolant Injection (LPCI) and Containment Cooling Modes of

RHRs Non-Outage Logic Test

26 1R22 Drawing 4E-

1430 Schematic Diagram Core Spray Systems I and

II BD 1R22 Drawing 4E-

1431 Schematic Diagram Core Spray Motor Operated

Valves Y 1R22 Drawing 4E-

1432 Schematic Diagram Core Spray Motor Operated

Valves U 1R22 QCOS 1400-16 Unit 1 Division II Core Spray Logic Functional

Test 7 1R22 QCOP 0201-18 Hydro Test Pump Operation 1 1R22 QCOS 1400-19 Core Spray Pressure Isolation Valve Seat Leakage Test

0 Section 1EP2 1EP2 FEMA ANS Design Basis Report May 2013 1EP2 FEMA ANS Letter for Backup ANS 12/10/2012 1EP2 Siren Testing and Maintenance Data July 2015-

February 2017 1EP2 IR 2533243 EP-Siren Failure (QC37) 07/27/2015 1EP2 IR 2534053 Potential Site Wide Trend in EP Facilities &

Equipment

07/28/2015 1EP2 IR 2543847 EP-Siren Failure (QC37) 08/19/2017 1EP2 IR 2558312 EP-Siren Failure (QC05) 09/21/2015 1EP2 IR 2565873 EP-Investigation of Siren Failures (QC37, QC39) 10/05/2015 1EP2 IR 2581456 EP-Siren Failure (QC05) 11/03/2015 1EP2 IR 2724917 EP-1

st Half 2016 MW ANS Siren Trend 10/06/2016 1EP2 IR 3983549 EP-Siren Design Report Approval Letter Not

Provided to NRC

03/07/2017

10 Section 1EP3 1EP3 2015 Station Off-hours Drive-in Augmentation and Performance Indicator Drills Findings and

Observation Report

09/30/2015 1EP3 First Quarter of 2016 ERO Augmentation Drill

Report 03/02/2016 1EP3 Fourth Quarter of 2015 ERO Augmentation Drill

Report 12/05/2015 1EP3 Fourth Quarter of 2016 ERO Augmentation Drill

Report 10/20/2016 1EP3 Second Quarter of 2016 ERO Augmentation

Drill Report

06/25/2016 1EP3 Selected Station Emergency Response Personnel Training Records

1EP3 Third Quarter of 2016 ERO Augmentation Drill

Report 09/23/2016 1EP3 IR 2715584 MA/MW ERO Notification System Delayed

Notifications

09/13/2016 1EP3 IR 2716129 Everbridge Delay in ERO Notification For Call-In

Drill 09/13/2016

Section 1EP5 1EP5 EP-QC-1000 Quad Cities Nuclear Power Station Radiological

Emergency Plan

0 1EP5 EP-AA-1006 Radiological Emergency Plan Annex For Quad Cities Station

38 1EP5 EP-AA-1006, Addendum 3 Emergency Action Levels For Quad Cities

Station 2 1EP5 EP-AA-122 Drills and Exercise Program 18 1EP5 EP-AA-125 Emergency Preparedness Self Evaluation

Process 10 1EP5 NOSA-QDC-

16-03 Emergency Preparedness Audit Report 04/20/2016 1EP5 Quad Cities Alert Event Report February 1, 2017 03/01/2017 1EP5 Pre-2017 NRC EP Routine/Program PI Verification Inspection

01/17/2017 1EP5 Apparent Cause Investigation Report 901-54

C1 Offgas Condenser Hi Level Unexpected

Alarm 12/09/2016 1EP5 IR 3970216 Observations from the MCR During E-Plan

Execution

02/01/2017 1EP5 IR 3979009 QDC-EP-2017-MA5ALERT-TSC-OTHER

Issues 02/27/2017 1EP5 IR 3970213 ENS Line Communication Issue During E-Plan

Execution

02/01/2017 1EP5 IR 3970242 EP-REAL Event (QDC Alert)-EOF-FAILED

Objective

02/01/2017 1EP5 IR 3970210 Bridge Line Issue Identified During E-Plan

Execution

02/01/2017

11 1EP5 IR 3972155 EP-REAL EVENT (QDC ALERT)-EOF-FACILITIES AND EQUIPMENT Issues

02/01/2017 1EP5 IR 2655742 NOS ID: 5 of 13 Forms Were Not Initialed, Signed, or Checked

04/14/2016 1EP5 IR 2733875 Potential Trend in EP Facilities & Equipment 10/28/2016 1EP5 IR 2742255 QC EP NRC Graded Exercise OSC Performance

11/16/2016 1EP5 IR 2742262 QC EP NRC Graded Exercise TSC Performance

11/16/2016 1EP5 IR 2742202 QC EP NRC Graded Exercise CR/SIM Performance

11/16/2016 1EP5 IR 2737679 SJAE Rad Monitors Reading Low 11/05/2016 1EP5 IR 3949032 QDC-EP-2016-NRC-TSC-OTHER Issues 11/16/2016 1EP5 IR 3970920 Reinforce Expectations for EP Event Response 02/01/2017 1EP5 Most current review of Letters of Agreement

with: St. Joseph Medical Center, General Electric, Rock Island County Sheriff, Cordova Fire Protection District, Trinity Medical Center,

Silvis Campus Hospital

Section 1EP6

1EP6 1Q17 PI Drill 2017 1

st Qtr PI Drill-Quad Cities Generating

Station 02/15/2017

Section 2RS1 2RS1 IR 3964145-04 Check-In: NRC RP-Exposure Controls Inspection

02/26/2017 2RS1 Quad Cities Radiation Protection; 2015 Alpha Assessment

12/29/2015 2RS1 Quad Cities Radiation Protection; 2016 Alpha Assessment

12/27/2016 2RS1 Radioactive Source Inventory 08/31/2016 2RS1 Radioactive Source Inventory 02/23/2017 2RS1 Semi-Annual Source Leak Test Report 08/31/2016 2RS1 Semi-Annual Source Leak Test Report 02/24/2017 2RS1 RP-AA-210 Dosimetry Issue, Usage, and Control 27 2RS1 RP-AA-300 Radiological Survey Program 14 2RS1 RP-QC-300-

1001 Radiological Survey Surveillance Program 11 2RS1 RP-AA-301 Radiological Air Sampling Program 10 2RS1 RP-AA-302 Determination of Alpha Levels and Monitoring 8 2RS1 RP-AA-350-

1001 Response to Guardhouse Portal Monitor Alarms 2 2RS1 RP-AA-460 Controls for High and Locked Radiation Areas 29 2RS1 RP-QC-460-

1002 High Radiation Area Inspections 7 2RS1 RWP QC-01-

17-00510 Radiation Work Permit and Associated ALARA File; DW Main Steam Safety Relief Valve

Activities (Q1R24)

1 2RS1 RWP QC-01-

17-00519 Radiation Work Permit and Associated ALARA File; DW Insulation Activities (Q1R24)

0

12 2RS1 RWP QC-01-

17-00541 Radiation Work Permit and Associated ALARA File; DW I/B MSIV Over Haul (Q1R24)

0 2RS1 RWP QC-01-

17-00901 Radiation Work Permit and Associated ALARA File; FF Rx Disassembly/Reassembly Activities

(Q1R24) 0 Section 2RS2 2RS2 RP-AA-403 Administration of the Radiation Work Permit Program 9 2RS2 RP-QC-552 Source Term External System/Component Flushing 1 Section 2RS3 2RS3 RP-AA-440 Respiratory Protection Program 13 2RS3 RP-AA-825-

1033 Operation of the MSA Optimair MM 2K Mask Mounted Air Purifying Respirator

2 2RS3 RP-QC-835 Operation, Inspection, and Use of the MSA Firehawk M7XT Air Mask Self-Contained

Breathing Apparatus

4 2RS3 RP-AA-825-

1014 Operation and Inspection of the 3M Versaflo

TR-300 PAPR System

3 2RS3 RP-AA-825-

1020 Operation and Use of Air Line Supplied

Respirators

1 2RS3 RP-AA-441 Evaluation and Selection Process for

Radiological Respirator Use

6 2RS3 RP-AA-440, Attachment 2

Review of Contractor Respiratory Protection

Program 03/21/2017 2RS3 RP-QC-835, Attachment 7 Flow Testing and Overhauls Various

Dates 2RS3 RP-QC-835, Attachment 3 MSA Firehawk M7XT Air Mask Inspection Various

Dates 2RS3 Generic Respiratory Protection Classroom Training 08/22/2016 2RS3 Respiratory Protection Training Level I January

2013 2RS3 Respiratory Protection Training Level II 01/16/2016 2RS3 Respiratory Protection Qualification Reports Various

Dates 2RS3 Quarterly Service Air and Self Contained

Breathing Apparatus

03/24/2017 2RS3 IR 3990963 MRC SCBA Manifold Fitting Size Incorrect 03/29/2017

Section 2RS4 2RS4 RP-AA-203-

1001 Personnel Exposure Investigations 9 2RS4 RP-AA-220 Bioassay Program 12 2RS4 RP-AA-210 Dosimetry Issue, Usage, and Control 27 2RS4 RP-AA-203-

1001, Attachment 1 Personnel Exposure Investigation Various

Dates 2RS4 RP-AA-214, Attachment 2 Area Dosimetry Worksheet Various

Dates

13 2RS4 IR 3982939 Correct Dose in Sentinel, but not Printing on Form 4 03/07/2017

Section 4OA1

4OA1 Explanation for Performance Indicator P.8.1.2 January-

December 2016 4OA1 Operator Narrative Logs January-

December 2016 4OA1 NRC Performance Indicator Data, Emergency Preparedness-Drill/Exercise Performance

October- December 2016 4OA1 NRC Performance Indicator Data, Emergency

Preparedness-ERO Readiness

October- December 2016 4OA1 NRC Performance Indicator Data, Emergency Preparedness-Alert and Notification System

Reliability

October- December 2016 Section 4OA2

4OA2 IR 3959913 CO2 Released into Turbine Building 01/05/2017 4OA2 IR 3964028 'A' AFU [Air Filtration Unit] Fan Failed to Start 01/18/2017 4OA2 IR 3965646 NRC ID: Pipe Unsupported Feed Pump Suction Press 'A'

01/23/2017 4OA2 EACE 3956145 Feedwater Heater Trip and Emergency Power

Reduction

02/13/2017 4OA2 IR 3977123 Unit 1 Essential Service Inverter Input Breaker

Trip 02/22/2017 4OA2 IR 3981113 Received 902-5 H6 Alarm 03/03/2017 4OA2 IR 3979804 U2 Turbine Oil Reservoir Level Rising 02/28/2017 4OA2 IR 3980721 2A Turbine Oil Cooler Tube Leak Identified 03/02/2017 4OA2 IR 3981972 2B ASD Backup PLC Failure 03/06/2017 4OA2 IR 3981671 Received 901-7 B5 and DEHC S1-P312 03/05/2017 4OA2 ECAP 3967424 1C RHRSW Pump Abnormal Indications 03/20/2017 4OA2 Drawing M-36 Diagram of Core Spray Piping BI 4OA2 IR 3985153 Core Spray Keep Fill Check Valve 1-1402-64B, Stuck 4OA2 IR 3983951 2-8802-A Valve Failed to Open During Return

to Service

03/10/2017 4OA2 IR 3984062 1B RPS MG Generator Voltage Out of Spec 03/10/2017 4OA2 IR 3984303 RPS B 1/2 Scram-SDV High Level (Blown Safety Related Fuse)

03/12/2017 4OA2 IR 3983620 1B RPS EPA's Tripped Following MG Set Start 03/09/2017 4OA2 IR 3984044 2A Turbine Oil Cooler Tube Leak Still Leaking 03/10/2017 4OA2 IR 3981835 U1 SDV Drain Valves Failed to Open During

Surveillance

03/06/2017 4OA2 IR 3990038 PSU MSIV As Found Closure Timing Out of

Band 03/27/2017 4OA2 IR 3990217 Received 902-5 H-6, SBLC Squib Valve Circuit

Alarm-A Squib

03/27/2017

14 4OA2 First Quarter 2017 Operator Burdens List for Units 1 and 2

4OA2 IR 3991293 IEMA Identified, Scaffold in Contact with 1B RHR Room Cooler

03/30/2017 4OA2 IR 3983983 1A RFP FME Impeller Pieces Found Missing During Maintenance

03/10/2017 4OA2 EC 618850 Lost Parts Evaluation Per ER-AA-2008 for the Lost Parts Missing from 1A Reactor Feed Pump

1-3201-A Prior to Q1R24 During Maintenance

Under WO 1842789

0 4OA2 CY-QC-170-

301 Quad Cities Offsite Dose Calculation Manual (ODCM ) January 2013 4OA2 CY-QC-120-

735, Attachment 1 Main Chimney & Reactor Vent Noble Gas Release Rate-Noble Gas Release Rates

04/15/2016 4OA2 GEK-27808A Calculation of Alarm and Trip Setpoints for the

Reactor Building Vent Stack Noble Gas Monitor

Section 4OA3

4OA3 Drawing 4E-

1654C Internal Schematic and Device Location Diagram 4160V Switchgear Bus 14 Cubicles 1,3,7,8,10, 12 and 14

N 4OA3 EN 52527 Fire in Unit 2 MCR Panel 902-3 02/01/2017 4OA3 IR 3969324 Light Socket for 2-203-3E Damaged During

Bulb Change

02/01/2017 4OA3 IR 3971265 Remove Fuse and Send to Power Labs-Root

Cause 3969324

02/07/2017 4OA3 IR 3971834 Safety Related Fuse Replacement in 2-2202-

32 Panel 02/08/2017 4OA3 OP-AA-101-

113-1004 Human Performance Issue Verbal Report Format 36 Section 4OA5

4OA5 IR 3952808 Check-in Self-Assessment: Interim Compensatory Measures Associated with the Open Phase Condition Design Vulnerabilities in

Electric Power Systems

01/31/2017 4OA5 LN 6500 4KV/480V Distribution 27

4OA5 Standing Order

S12-06 Single Open Phase Detection 03/16/2012

4OA5 STN 12-021 Switchyard Vulnerability-Single Open Phase Detection Operability Evaluation Compensatory

Measure 4OA5 QCAN 902-8 F-

4 Reserve Auxiliary Transformer 22 Open Phase Detection Low Load/Trouble

2 4OA5 EC 0000387740 Switchyard Vulnerability-Single Open Phase

Detection

5

15 LIST OF ACRONYMS USED

ALARA As-Low-As-Reasonably-Achievable ADAMS Agencywide Document Access Management System ADS Automatic Depressurization System ANS Alert and Notification System

ASME American Society of Mechanical Engineers

CAP Corrective Action Program

CFR Code of Federal Regulations

DBE Design Basis Event DEP Drill and Exercise Performance DGCWP Diesel Generator Cooling Water Pump

DRP Division of Reactor Projects

EC Engineering Change

EDG Emergency Diesel Generator EP Emergency Preparedness ERO Emergency Response Organization

ERV Electromatic Relief Valve

FZ Fire Zone

HPCI High Pressure Coolant Injection IMC Inspection Manual Chapter IP Inspection Procedure

IR Issue Report

ISI Inservice Inspection

LCO Limiting Condition for Operation

LER Licensee Event Report LPCI Low Pressure Coolant Injection MOC Mechanism Operated Contact

MT Magnetic Particle Examination

NCV Non-Cited Violation

NDE Non-Destructive Examination NEI Nuclear Energy Institute NRC U.S. Nuclear Regulatory Commission

OPC Open Phase Condition

OSP Outage Safety Plan

PARS Publicly Available Records System

PI Performance Indicator PMT Post-Maintenance Testing RCIC Reactor Core Isolation Cooling

RFO Refueling Outage

RHR Residual Heat Removal

RHRSW Residual Heat Removal Service Water SCBA Self-Contained Breathing Apparatus SSCs Structures, Systems, and Components

TS Technical Specification

UFSAR Updated Final Safety Analysis Report

UHS Ultimate Heat Sink

URI Unresolved Item VDC Voltage Direct Current VT Visual Examination WO Work Order

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