ML18025B418
| ML18025B418 | |
| Person / Time | |
|---|---|
| Site: | Quad Cities  |
| Issue date: | 01/25/2018 |
| From: | Karla Stoedter NRC/RGN-III/DRP/B1 |
| To: | Bryan Hanson Exelon Generation Co, Exelon Nuclear |
| References | |
| IR 2017004, IR 2017501 | |
| Download: ML18025B418 (47) | |
See also: IR 05000254/2017004
Text
first initial,
UNITED STATES
NUCLEAR REGULATORY COMMISSION
REGION III
2443 WARRENVILLE RD. SUITE 210
LISLE, IL 60532-4352
January 25, 2018
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 2NRC
INTEGRATED INSPECTION REPORT AND EMERGENCY PREPAREDNESS
ANNUAL INSPECTION REPORT 05000254/2017004; 05000265/2017004;
05000254/2017501 AND 05000265/2017501
Dear Mr. Hanson:
On December 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
January 3, 2018, the NRC inspectors discussed the results of this inspection with Mr. H. Dodd
and other members of your staff. The results of this inspection are documented in the enclosed
report. The NRC also completed its annual inspection of the Emergency Preparedness
Program, which began on January 1, 2017, and the issuance of this letter closes Inspection
Report 05000254/2017501; 05000265/2017501.
Based on the results of this inspection, the NRC inspectors did not identify any findings or
violations of more than minor significance.
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, Request for
Withholding.
Sincerely,
/RA/
Karla Stoedter, Chief
Branch 1
Division of Reactor Projects
Docket Nos. 50-254; 50-265
Enclosure:
IR 05000254/2017004; 05000265/2017004;
05000254/2017501; 05000265/2017501
cc: Distribution via LISTSERV
Letter to Bryan C. Hanson from Karla Stoedter dated January 25, 2018
SUBJECT: QUAD CITIES NUCLEAR POWER STATION, UNITS 1 AND 2NRC
INTEGRATED INSPECTION REPORT AND EMERGENCY PREPAREDNESS
ANNUAL INSPECTION REPORT 05000254/2017004; 05000265/2017004;
05000254/2017501 AND 05000265/2017501
DISTRIBUTION:
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RidsNrrPMQuadCities Resource
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DRPIII
DRSIII
ROPreports.Resource@nrc.gov
ADAMS Accession Number: ML18025B418
OFFICE RIII
NAME KStoedter:bw
DATE 1/25/2018
OFFICIAL RECORD COPY
U.S. NUCLEAR REGULATORY COMMISSION
REGION III
Docket Nos: 50-254; 50-265
Report No: 05000254/2017004; 05000265/2017004
05000254/2017501; 05000265/2017501
Licensee: Exelon Generation Company, LLC
Facility: Quad Cities Nuclear Power Station, Units 1 and 2
Location: Cordova, IL
Dates: October 1 through December 31, 2017
Inspectors: R. Murray, Senior Resident Inspector
K. Carrington, Resident Inspector
J. Beavers, Health Physicist
B. Bergeon, Operations Engineer
J. Cassidy, Senior Health Physicist
N. Fields, Health Physicist
M. Garza, Emergency Preparedness Inspector
V. Meghani, Reactor Inspector
K. Walton, Senior Operations Engineer
Approved by: K. Stoedter, Chief
Branch 1
Division of Reactor Projects
Enclosure
TABLE OF CONTENTS
SUMMARY .................................................................................................................................... 2
REPORT DETAILS ....................................................................................................................... 3
Summary of Plant Status ........................................................................................................... 3
1. REACTOR SAFETY ........................................................................................... 3
1R01 Adverse Weather Protection (71111.01) ..................................................... 3
1R04 Equipment Alignment (71111.04) ................................................................ 4
1R05 Fire Protection (71111.05) ........................................................................... 5
1R11 Licensed Operator Requalification Program (71111.11) ............................. 6
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
1R18 Plant Modifications (71111.18) .................................................................. 13
1R19 Post-Maintenance Testing (71111.19) ...................................................... 14
1R22 Surveillance Testing (71111.22) ................................................................ 15
1EP4 Emergency Action Level and Emergency Plan Changes (71114.04) ........ 16
1EP6 Drill Evaluation (71114.06) ........................................................................ 17
2. RADIATION SAFETY ....................................................................................... 17
2RS2 Occupational As-Low-As-Reasonably-Achievable Planning and Controls
(71124.02) ................................................................................................. 17
2RS5 Radiation Monitoring Instrumentation (71124.05) ..................................... 19
2RS7 Radiological Environmental Monitoring Program (71124.07) .................... 21
4. OTHER ACTIVITIES ........................................................................................ 22
4OA1 Performance Indicator Verification (71151) ............................................... 22
4OA2 Identification and Resolution of Problems (71152) .................................... 24
4OA3 Follow-Up of Events and Notices of Enforcement Discretion (71153) ....... 26
4OA5 Other Activities .......................................................................................... 28
4OA6 Management Meetings .............................................................................. 29
SUPPLEMENTAL INFORMATION ............................................................................................... 2
Key Points of Contact ................................................................................................................ 2
List of Items Opened, Closed, and Discussed........................................................................... 2
List of Documents Reviewed ..................................................................................................... 3
List of Acronyms Used ............................................................................................................ 14
SUMMARY
Inspection Report 05000254/2017004, 05000265/2017004; 10/01/2017 - 12/31/2017;
05000254/2017501, 05000265/2017501; 01/01/2017-12/31/2017; Quad Cities Nuclear Power
Station, Units 1 and 2; Routine Integrated Inspection Report.
This report covers a 3-month period of inspection by resident inspectors and announced
baseline inspections by regional inspectors. 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 NRCs 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.
A. NRC-Identified and Self-Revealed Findings
No findings were identified during this inspection.
2
REPORT DETAILS
Summary of Plant Status
Unit 1
The unit operated at or near full power from October 1 to October 30, 2017. On
October 30, 2017, operators reduced power to 68.5 percent core thermal power in response to
an unanticipated automatic closure of main turbine control valve number 1. Following repairs to
a loose electro-hydraulic control (EHC) system servo cable connection, the unit was returned to
full power on October 31, 2017. On November 16, 2017, operators reduced power to
68 percent core thermal power to respond to unanticipated alarms and impending closure of
main turbine control valve number 1. Following repairs, which included lock-wire installation on
all EHC system servo cable connections to turbine control valves, the unit was returned to full
power on November 17, 2017, and remained at or near full power through the end of the
inspection period. Operating at or near full power includes planned power reductions for
turbine testing, control rod pattern adjustments, and other short-term power changes as
requested by the transmission system operator.
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 and other
short-term 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)
Readiness for Impending Adverse WeatherFish Intrusion in the Intake Bay and the
Crib House
a. Inspection Scope
During the week of December 18, 2017, the inspectors observed the licensees activities
associated with readiness and corrective actions in response to an unusual amount of
Gizzard Shad, which had infiltrated the stations intake bay, and affected the Unit 2
traveling water screens in the crib house and also had a noticeable effect on the Unit 2
main condenser differential pressure. The inspectors observed pre-job, pre-shift, and
control room briefings to determine whether the briefings met licensee standards. The
inspectors reviewed licensee procedures for responding to traveling screen high
differential pressure alarms and procedures for directing reversal of flow to the main
condenser. The inspectors also discussed potential compensatory measures with
control room personnel. Finally, the inspectors periodically reviewed licensee activities
and data collection as specified by licensee procedures to determine whether the fish
intrusion and associated effects were being adequately monitored. The inspectors also
reviewed corrective action program (CAP) items to verify that the licensee was
identifying adverse weather/environmental issues at an appropriate threshold and
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entering them into their CAP in accordance with station corrective action procedures.
Documents reviewed are listed in the Attachment to this report.
This activity constituted one readiness for impending adverse weather condition sample
as defined in Inspection Procedure (IP) 71111.01-05.
b. Findings
No findings were identified.
1R04 Equipment Alignment (71111.04)
Quarterly Partial System Walkdowns
a. Inspection Scope
The inspectors performed partial system walkdowns of the following risk-significant
systems:
- Unit 1 reactor core isolation cooling system following planned maintenance;
- Unit 1 and Unit 1/2 emergency diesel generator (EDG) systems during Unit 2
EDG planned maintenance; and
- Unit 2 high pressure coolant injection (HPCI) system during safe shutdown
makeup pump (SSMP) system planned maintenance.
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, Updated Final Safety Analysis Report (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 parameters 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 three partial system walkdown samples as defined in
IP 71111.04-05.
b. Findings
No findings were identified.
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1R05 Fire Protection (71111.05)
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) 5.0, Unit 2 Turbine Building, Elevation 595-0, Safe Shutdown
Pump Room;
- FZ 11.1.4, Unit 2 Reactor Building, Elevation 544-0, HPCI Pump Room;
- FZ 1.1.1.1, Unit 1 Turbine Building, Elevation 5950, Diesel Generator Room;
and
- FZ 1.1.2.1, Unit 1 Reactor Building, Elevation 5540, Top of Torus Area.
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 licensees fire plan.
The inspectors selected fire areas based on their overall contribution to internal fire risk
as documented in the plants 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 plants 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 licensees 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.
Annual Fire Protection Drill Observation (71111.05A)
a. Inspection Scope
On September 26 and October 4, 2017, the inspectors observed two fire brigade
activations for a report of smoke in cabling for the Unit 1 motor control center (MCC)
18/19-5 and a report of smoke coming from the Unit 2 condensate pit man-lift,
respectively. Based on these observations, the inspectors evaluated the readiness of
the plant fire brigade to fight fires. The inspectors verified that the licensee staff
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identified deficiencies openly, discussed them in a self-critical manner at the drill debrief,
and took appropriate corrective actions. Specific attributes evaluated were:
- proper wearing of turnout gear and self-contained breathing apparatus;
- proper use and layout of fire hoses;
- employment of appropriate firefighting techniques;
- sufficient firefighting equipment brought to the scene;
- effectiveness of fire brigade leader communications, command, and control;
- search for victims and propagation of the fire into other plant areas;
- smoke removal operations;
- utilization of pre-planned strategies;
- adherence to the pre-planned drill scenario; and
- drill objectives.
Documents reviewed are listed in the Attachment to this report.
These activities constituted one annual fire protection inspection sample as defined in
IP 71111.05-05.
b. Findings
No findings were identified.
1R11 Licensed Operator Requalification Program (71111.11)
Resident Inspector Quarterly Review of Licensed Operator Requalification (71111.11Q)
a. Inspection Scope
On November 7, 2017, the inspectors observed two crews of licensed operators in the
plants 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:
- licensed operator performance;
- crews 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.
The crews 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 (LOR)
program simulator sample as defined in IP 71111.11-05.
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b. Findings
No findings were identified.
.2 Resident Inspector Quarterly Observation during Periods of Heightened Activity or Risk
(71111.11Q)
a. Inspection Scope
On October 31, 2017, the inspectors observed operators raise power from approximately
75 percent to full (100 percent) core thermal power on Unit 1 following an emergent load
reduction due to a spurious closure of turbine control valve number 1.
On December 11, 2017, the inspectors observed operators perform a pre-job brief and
secure the Unit 2 B stator cooling water pump to support an emergent pump
replacement.
During the week of December 17, 2017, the inspectors observed operators in the control
room, on several occasions, during the fish intrusion event that is discussed in
Section 1R01, which included multiple main condenser flow reversals.
These were activities that required heightened awareness or were related to increased
risk. The inspectors evaluated the following areas:
- licensed operator performance;
- crews 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 procedures;
- control board and equipment manipulations;
- oversight and direction from supervisors; and
- ability to identify and implement appropriate TS actions.
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.
.3 Annual Operating Test Results (71111.11A)
a. Inspection Scope
The inspectors reviewed the overall pass/fail results of the Annual Operating Test
and the Biennial Written Examination administered by the licensee from
October 9, 2017, through November 17, 2017, required by Title 10 of the Code of
Federal Regulations (CFR), Part 55.59(a). The results were compared to the thresholds
7
established in IMC 0609, Appendix I, Licensed Operator Requalification Significance
Determination Process (SDP), to assess the overall adequacy of the licensees
Licensed Operator Requalification Training (LORT) Program to meet the requirements of
10 CFR 55.59. (02.02)
This inspection constituted one annual licensed operator requalification examination
results sample as defined in IP 71111.11-05.
b. Findings
No findings were identified.
.4 Biennial Review (71111.11B)
a. Inspection Scope
The following inspection activities were conducted during the weeks of October 9 and
October 16, 2017, to assess: (1) the effectiveness and adequacy of the facility
licensees implementation and maintenance of its systems approach to training (SAT)
based LORT Program put into effect to satisfy the requirements of 10 CFR 55.59;
(2) conformance with the requirements of 10 CFR 55.46 for use of a plant referenced
simulator to conduct operator licensing examinations and for satisfying experience
requirements; and (3) conformance with the operator license conditions specified in
10 CFR 55.53. The documents reviewed are listed in the Attachment to this report.
- Licensee Requalification Examinations (10 CFR 55.59(c); SAT Element 4 as
Defined in 10 CFR 55.4): The inspectors reviewed the licensees program for
development and administration of the LORT biennial written examination and
annual operating tests to assess the licensees ability to develop and administer
examinations that are acceptable for meeting the requirements of
- The inspectors conducted a detailed review of one biennial requalification
written examination versions to assess content, level of difficulty, and quality
of the written examination materials. (02.03)
- The inspectors conducted a detailed review of ten job performance measures
and four simulator scenarios to assess content, level of difficulty, and quality
of the operating test materials. (02.04)
- The inspectors observed the administration of the annual operating test
to assess the licensees effectiveness in conducting the examination(s),
including the conduct of pre-examination briefings, evaluations of individual
operator and crew performance, and post-examination analysis. The
inspectors evaluated the performance of one crew in parallel with the facility
evaluators during two dynamic simulator scenarios, and evaluated various
licensed crew members concurrently with facility evaluators during the
administration of several job performance measures. (02.05)
- The inspectors assessed the adequacy and effectiveness of the remedial
training conducted since the last requalification examinations and the
training planned for the current examination cycle to ensure that they
addressed weaknesses in licensed operator or crew performance identified
during training and plant operations. The inspectors reviewed remedial
training procedures and individual remedial training plans. (02.07)
8
- Conformance with Examination Security Requirements (10 CFR 55.49):
The inspectors conducted an assessment of the licensees processes related
to examination physical security and integrity (e.g., predictability and bias) to
verify compliance with 10 CFR 55.49, Integrity of Examinations and Tests.
The inspectors observed the implementation of physical security controls
(e.g., access restrictions and simulator I/O controls) and integrity measures
(e.g., security agreements, sampling criteria, bank use, and test item repetition)
throughout the inspection period. (02.06)
- Conformance with Operator License Conditions (10 CFR 55.53): The inspectors
reviewed the facility licensee's program for maintaining active operator licenses
and to assess compliance with 10 CFR 55.53(e) and (f). The inspectors
reviewed the procedural guidance and the process for tracking on-shift hours
for licensed operators, and which control room positions were granted
watch-standing credit for maintaining active operator licenses. Additionally,
medical records for seven licensed operators were reviewed for compliance with
10 CFR 55.53(I). (02.08)
- Conformance with Simulator Requirements Specified in 10 CFR 55.46:
The inspectors assessed the adequacy of the licensees simulation facility
(simulator) for use in operator licensing examinations and for satisfying
experience requirements. The inspectors reviewed a sample of simulator
performance test records (e.g., transient tests, malfunction tests, scenario based
tests, post-event tests, steady state tests, and core performance tests), simulator
discrepancies, and the process for ensuring continued assurance of simulator
fidelity in accordance with 10 CFR 55.46. The inspectors reviewed and
evaluated the discrepancy corrective action process to ensure that simulator
fidelity was being maintained. Open simulator discrepancies were reviewed for
importance relative to the impact on 10 CFR 55.45 and 55.59 operator actions as
well as on nuclear and thermal hydraulic operating characteristics. (02.09)
- Problem Identification and Resolution (10 CFR 55.59(c); SAT Element 5 as
Defined in 10 CFR 55.4): The inspectors assessed the licensees ability to
identify, evaluate, and resolve problems associated with licensed operator
performance (a measure of the effectiveness of its LORT Program and their
ability to implement appropriate corrective actions to maintain its LORT Program
up to date). The inspectors reviewed documents related to licensed operator
performance issues (e.g., licensee condition/problem identification reports
including documentation of plant events and review of industry operating
experience from previous 2 years). The inspectors also sampled the licensees
quality assurance oversight activities, including licensee training department
self-assessment reports. (02.10)
This inspection constituted one Biennial LOR Program inspection sample as defined in
IP 71111.11-05.
b. Findings
Introduction: While performing an assessment of the licensees processes related
to examination physical security and integrity (e.g. predictability and bias) to verify
compliance with 10 CFR 55.49, Integrity of Examinations and Tests, the inspectors
9
identified that Quad Cities 2015 LOR written examinations were duplicated from the
2013 LOR examinations, that 2017 LOR written examinations were duplicated from the
2015 LOR examinations, and that four individuals were administered the same written
examinations from the previous exam cycle.
Description: The inspectors identified that, with few exceptions, the licensee had
duplicated or reused questions from the 2015 written exam when they created the
2017 written exam. The licensee created six LOR written exam versions (i.e., A-F), one
for each crew. For the 2017 biennial exam, the licensee essentially swapped exam
versions from 2015 that were given to each crew (i.e., the 2015 Version A was given to
crew B in 2017 and Version B was given to crew A, etc.). The inspectors noted that
no crew received the same exam version in 2017 as they did in 2015. However, due to
crew personnel adjustments/realignments, the inspectors requested the licensee to
investigate if, and how many, operators were going to receive the same exam in 2017 as
in 2015. The licensee identified that one reactor operator had already taken the same
exam in 2017 that they were given in 2015. In addition, the licensee also identified that
two additional licensed operators were scheduled to take the same exam they had taken
in 2015, but they had not yet been given the exam due to the exam schedule. After
discussing the issue and concern with the inspectors, the licensee decided to administer
those two individuals different exam versions to which they had not been previously
exposed. In addition, the inspectors inquired how long the particular set of exam
versions had been reused and swapped among the crews (i.e., before 2015). The
licensee reviewed biennial written exams in 2013 and 2011 and determined the exam
content was different and stated, there was no predictable pattern in exam versions.
After reviewing all of the 2013 exam versions, the inspectors identified that three
versions were a mixture of questions between reused and new questions. For example,
2013 Version A was a mixture of questions of 2015 exam Versions C and D and two
unique questions. The 2013 Version B was a mixture of 2015 Version C and D and
seven unique questions. The 2013 Version F was a mixture of 2015 D and F and five
unique questions. The three remaining versions from 2013 were replicated in 2015, but
given to different crews. The inspectors requested the licensee determine the number of
personnel that took the same exam in 2015 as in 2013, and the licensee identified three
individuals who were given the same exam in 2013 and 2015 (two senior reactor
operators and one reactor operator).
The inspectors are considering this issue to be an unresolved item (URI) concerning
whether the repeated use of a biennial written examination for sequential requalification
programs (consecutive 24 month periods), and the resulting predictability induced to the
examination process, constitutes a violation of 10 CFR 55.49, Integrity of Examinations
and Tests. The inspectors have requested the licensee provide the written
examinations in question to the inspectors for further review. The inspectors will review
individual questions of the written examinations in order to determine if there were
sufficient differences between the examinations to characterize the examinations as
either different or similar. The results of the review will be used to determine if a
violation of 10 CFR 55.49 requirements exists. (URI 05000254/2017004-01;
05000265/2017004-01: Repeat Use of Written Exams during Licensed Operator
Requalification Examinations)
10
1R12 Maintenance Effectiveness (71111.12)
Routine Quarterly Evaluations
a. Inspection Scope
The inspectors evaluated degraded performance issues involving the following
risk-significant systems:
- Units 1 and 2 standby liquid control systems, and
- SSMP system.
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/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 defined in
IP 71111.12-05.
b. Findings
No findings were identified.
1R13 Maintenance Risk Assessments and Emergent Work Control (71111.13)
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:
11
- Work Week 17-40-04: Unit 1/2 EDG system extended limiting condition for
operation due to emergent work activities and planned Unit 2 core spray system
maintenance;
- Work Week 17-42-06: Unit 2 EDG system planned maintenance, planned
secondary containment breaches resulting in both units online risk change to
yellow, and Unit 2 125 Vdc battery charger load test;
- Work Week 17-46-10: Unit 1 B low pressure coolant injection and residual
heat removal system planned maintenance resulting in online risk change to
yellow, 345 kV line planned maintenance, Units 1 and 2 reactor buildings
planned maintenance, and planned secondary containment breaches resulting in
both units online risk change to yellow; and
- Work Week 17-51-02: Unit 1 1A 125 Vdc battery charger system emergent
maintenance, and Unit 2 fish intrusion in intake bay.
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.
This inspection constituted four maintenance risk assessments and emergent work
control samples as defined in IP 71111.13-05.
b. Findings
No findings were identified.
1R15 Operability Determinations and Functional Assessments (71111.15)
Operability Evaluations
a. Inspection Scope
The inspectors reviewed the following issues:
- Issue Report (IR) 4059847: 1-7503 [Unit 1 standby gas treatment system
(SBGT) Reactor Building Inlet Valve] Failed to Close During QCOS 7500-08;
- IR 4062552: B Train CREV [control room emergency ventilation] Superheat
Value High;
- IR 4062754: 1A Core Spray Motor Bearing Oil Issue;
- IR 4066290: 1A SBLC Pump Accumulator Schraeder Valve is Stuck Open;
- IR 4072162: Unit 1 HPCI Did Not Trip During QCOS 2300-05;
- IR 4077502 and IR 4081377: MCC 18/19-5 Overvoltage Relay Target Lit (partial
sample); and
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- IR 4078677: EO ID [Equipment Operator Identified], Local Control Switch Would
Not Start the SSMP and IR 4078579: SSMP Reserve Feed MCR [Main Control
Room] Switch Will Not Close.
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
appropriate sections of the TS and UFSAR to the licensees 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.
The inspectors documented one partial operability sample related to MCC 18/19-5
over-voltage relay. The inspection of this sample continued into the next inspection
period.
This operability inspection constituted six samples as defined in IP 71111.15-05.
b. Findings
No findings were identified.
1R18 Plant Modifications (71111.18)
Plant Modifications
a. Inspection Scope
The inspectors reviewed the following modifications:
- Engineering Change 619131: U-1 HPCI Signal Converter Output Failed Alarm
Bypass, Revision 0; and
- Engineering Change 20370: Motor Control Center 18/19-5 Protective Relay
Modification.
The inspectors reviewed the configuration changes and associated 10 CFR 50.59 safety
evaluation screening against the design basis, the UFSAR, and the TS, as applicable, to
verify that the modification did not affect the operability or availability of the affected
systems. The inspectors, as applicable, observed ongoing and completed work
activities to ensure that the modifications were installed as directed and consistent with
the design control documents; the modifications operated as expected; post-modification
testing adequately demonstrated continued system operability, availability, and reliability;
and that operation of the modifications did not impact the operability of any interfacing
systems. As applicable, the inspectors verified that relevant procedure, design, and
licensing documents were properly updated. Lastly, the inspectors discussed the plant
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modification with operations, engineering, and training personnel to ensure that the
individuals were aware of how the operation with the plant modification in place could
impact overall plant performance. Documents reviewed are listed in the Attachment to
this report.
This inspection constituted one temporary modification sample and one permanent plant
modification sample as defined in IP 71111.18-05.
b. Findings
No findings were identified.
1R19 Post-Maintenance Testing (71111.19)
Post-Maintenance Testing
a. Inspection Scope
The inspectors reviewed the following post-maintenance activities to verify that
procedures and test activities were adequate to ensure system operability and functional
capability:
- B CREV operability test following planned maintenance;
- Unit 1/2 EDG system testing and calibration following governor booster pump
and relay replacements and other 2-year planned maintenance;
- A SBGT auto start test, following relay replacement;
- Unit 1 station blackout diesel generator system post-maintenance testing
following 2-year planned maintenance activities;
replacement;
- Unit 2 Division I turbine first stage low pressure above setpoint calibration and
functional test, following pressure switch 2-0504-A replacement;
- SSMP system operability test following planned maintenance; and
- Unit 2 station blackout diesel generator system post-maintenance testing
following 2-year planned 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
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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 eight post-maintenance testing samples as defined in
IP 71111.19-05.
b. Findings
No findings were identified.
1R22 Surveillance Testing (71111.22)
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
function and to verify testing was conducted in accordance with applicable procedural
and TS requirements:
- QCOS 7000-08: U2 SBGT Initiation Logic Test (Routine);
- QCOS 1400-07: Core Spray Pump Comprehensive/Performance Test
(In-Service Test); and
- Surveillance Frequency Control Program Surveillance Test Interval Number
QDC-17-002: 125/250 Vdc Battery Service Testing (Routine).
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;
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- 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.
Documents reviewed are listed in the Attachment to this report.
This inspection constituted two 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.
1EP4 Emergency Action Level and Emergency Plan Changes (71114.04)
a. Inspection Scope
The regional inspectors performed an in-office review of the latest revisions to the
Emergency Plan, Emergency Action Levels (EALs), and EAL Bases document to
determine if these changes decreased the effectiveness of the Emergency Plan.
The inspectors also performed a review of the licensees 10 CFR 50.54(q) change
process, and Emergency Plan change documentation to ensure proper implementation
for maintaining Emergency Plan integrity.
The NRC review was not documented in a safety evaluation report, and did not
constitute approval of licensee-generated changes; therefore, this revision is subject to
future inspection. The specific documents reviewed during this inspection are listed in
the Attachment to this report.
This EAL and Emergency Plan Change inspection constituted one sample as defined
in IP 71114.04-06.
b. Findings
No findings were identified.
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1EP6 Drill Evaluation (71114.06)
Emergency Preparedness Drill Observation
a. Inspection Scope
The inspectors evaluated the conduct of a routine licensee emergency drill on
November 8, 2017, to identify any weaknesses and deficiencies in classification,
notification, and protective action recommendation development activities. The
inspectors observed emergency response operations in the Operations Support Center
and Technical 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 weaknesses 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 CAP. As part of the inspection, the inspectors
reviewed the drill package and other documents listed in the Attachment to this report.
This emergency preparedness drill inspection constituted one sample as defined in
IP 71114.06-05.
b. Findings
No findings were identified.
2. RADIATION SAFETY
Cornerstones: Public Radiation Safety, Occupational Radiation Safety
2RS2 Occupational As-Low-As-Reasonably-Achievable Planning and Controls (71124.02)
Radiological Work Planning (02.02)
a. Inspection Scope
The inspectors compared the results achieved with the intended dose established in the
As-Low-As-Reasonably-Achievable (ALARA) planning. The inspectors compared the
person-hour estimates provided by work groups to the radiation protection group with the
actual work activity time results, and evaluated the accuracy of these time estimates.
The inspectors evaluated the reasons for any inconsistencies between intended and
actual work activity doses.
The inspectors evaluated whether post-job reviews were conducted to identify lessons
learned and entered into the licensees CAP.
These inspection activities supplemented those documented in NRC Integrated
Inspection Report 05000254/2016002; 05000265/2016002 and constituted one complete
sample as defined in IP 71124.02-05.
b. Findings
No findings were identified.
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Verification of Dose Estimates and Exposure Tracking Systems (02.03)
a. Inspection Scope
The inspectors assessed whether the assumptions and basis for the current annual
collective exposure estimate were reasonably accurate. The inspectors assessed
source term reduction effectiveness and reviewed applicable procedures for estimating
exposures from specific work activities.
The inspectors reviewed the assumptions and bases in ALARA work planning
documents for selected activities and verified that the licensee has established
measures to track, trend, and if necessary to reduce, occupational doses for ongoing
work activities.
The inspectors determined whether a dose threshold criteria was established to prompt
additional reviews and/or additional ALARA planning and controls and evaluated the
licensees method of adjusting exposure estimates, or re-planning work, when
unexpected changes in scope or emergent work were encountered. The inspectors
determined if adjustments to exposure estimates were based on sound radiation
protection and ALARA principles or if they are just adjusted to account for failures to
control the work. The inspectors evaluated whether there was sufficient station
management review and approval of adjustments to exposure estimates and that the
reasons for the adjustments were justifiable.
The inspectors reviewed selected occasions with inconsistent or incongruent results
from the licensees intended radiological outcomes to determine whether the cause was
attributed to a failure to adequately plan work activities, or failure to provide sufficient
management oversight of in-plant work activities, or failure to conduct the work activity
without significant rework, or failure to implement radiological controls as planned.
These inspection activities constituted one complete sample as defined in
IP 71124.02-05.
b. Findings
No findings were identified.
Implementation of As-Low-As-Reasonably-Achievable and Radiological Work Controls
(02.04)
a. Inspection Scope
The inspectors compared the radiological results achieved with the intended radiological
outcomes and verified that the licensee captured lessons learned for use in the next
outage.
These inspection activities supplemented those documented in NRC Integrated
Inspection Report 05000254/2016002; 05000265/2016002 and 05000254/2017001;
05000265/2017001 constituted one complete sample as defined in IP 71124.02-05.
b. Findings
No findings were identified.
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Problem Identification and Resolution (02.06)
a. Inspection Scope
The inspectors reviewed self-assessments and/or audits performed of the ALARA
program and determined if these reviews identified problems or areas for improvement.
The inspectors assessed whether problems associated with ALARA planning and
controls were being identified by the licensee at an appropriate threshold and properly
addressed for resolution.
These inspection activities constituted one complete sample as defined in
IP 71124.02-05.
b. Findings
No findings were identified.
2RS5 Radiation Monitoring Instrumentation (71124.05)
Walkdowns and Observations (02.02)
a. Inspection Scope
The inspectors assessed select portable survey instruments that were available for use
for current calibration and source check stickers, and instrument material condition and
operability.
The inspectors observed licensee staff demonstrate performance checks of various
types of portable survey instruments. The inspectors assessed whether high-range
instruments responded to radiation on all appropriate scales.
The inspectors walked down area radiation monitors and continuous air monitors to
determine whether they were appropriately positioned relative to the radiation sources or
areas they were intended to monitor. The inspectors compared monitor response with
actual area conditions for selected monitors.
The inspectors assessed the functional checks for select personnel contamination
monitors, portal monitors, and small article monitors to verify they were performed in
accordance with the manufacturers recommendations and licensee procedures.
These inspection activities constituted one complete sample as defined in
IP 71124.05-05.
b. Findings
No findings were identified.
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Calibration and Testing Program (02.03)
a. Inspection Scope
The inspectors assessed laboratory analytical instruments used for radiological analyses
to determine whether daily performance checks and calibration data indicated that the
frequency of the calibrations was adequate and there were no indications of degraded
instrument performance. The inspectors assessed whether appropriate corrective
actions were implemented in response to indications of degraded instrument
performance.
The inspectors reviewed the methods and sources used to perform whole body count
functional checks before daily use and assessed whether check sources were
appropriate and aligned with the plants isotopic mix. The inspectors reviewed whole
body count calibration records since the last inspection and evaluated whether
calibration sources were representative of the plant source term and that appropriate
calibration phantoms were used. The inspectors looked for anomalous results or other
indications of instrument performance problems.
Inspectors reviewed select containment high-range monitor calibration and assessed
whether an electronic calibration was completed for all range decades, with at least one
decade at or below 10 rem/hour calibrated using an appropriate radiation source, and
calibration acceptance criteria was reasonable.
The inspectors reviewed select monitors used to survey personnel and equipment for
unrestricted release to assess whether the alarm setpoints were reasonable under the
circumstances to ensure that licensed material was not released from the site. The
inspectors reviewed the calibration documentation for each instrument selected and
discussed the calibration methods with the licensee to determine consistency with the
manufacturers recommendations.
The inspectors reviewed calibration documentation for select portable survey
instruments, area radiation monitors, and air samplers. The inspectors reviewed
detector measurement geometry and calibration methods for portable survey
instruments and area radiation monitors calibrated onsite and observed the licensee
demonstrate use of the instrument calibrator. The inspectors assessed whether
appropriate corrective actions were taken for instruments that failed performance checks
or were found significantly out of calibration, and that the licensee had evaluated the
possible consequences of instrument use since the last successful calibration or
performance check.
The inspectors reviewed the current output values for instrument calibrators. The
inspectors assessed whether the licensee periodically measured calibrator output over
the range of the instruments used with measuring devices that have been calibrated by a
facility using National Institute of Standards and Technology traceable sources and
corrective factors for these measuring devices were properly applied in its output
verification.
The inspectors reviewed the licensees Title 10 of the Code of Federal Regulations,
Part 61, Licensing Requirements for Land Disposal of Radioactive Waste, source term
to assess whether calibration sources used were representative of the types and
energies of radiation encountered in the plant.
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These inspection activities constituted one complete sample as defined in
IP 71124.05-05.
b. Findings
No findings were identified.
Problem Identification and Resolution (02.04)
a. Inspection Scope
The inspectors evaluated whether problems associated with radiation monitoring
instrumentation 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
that involve radiation monitoring instrumentation.
These inspection activities constituted one complete sample as defined in
IP 71124.05-05.
b. Findings
No findings were identified.
2RS7 Radiological Environmental Monitoring Program (71124.07)
Groundwater Protection Initiative Implementation (02.03)
a. Inspection Scope
The inspectors reviewed leak and spill events and Title 10 of the Code of Federal
Regulations, Part 50.75(g) records and assessed whether the source of the leak or spill
was identified and appropriately mitigated.
These inspection activities supplemented those documented in NRC Integrated
Inspection Report 05000254/2017003; 05000265/2017003 and constituted one complete
sample as defined in IP 71124.07-05.
b. Findings
No findings were identified
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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 Reactor Coolant System Specific Activity
a. Inspection Scope
The inspectors sampled licensee submittals for the reactor coolant system specific
activity performance indicator (PI) for Quad Cities Nuclear Power Station, Units 1
and 2, for the period from the third quarter 2016 through the third quarter 2017. The
inspectors used PI definitions and guidance contained in the Nuclear Energy
Institute (NEI) Document 99-02, Regulatory Assessment Performance Indicator
Guideline, Revision 7, dated August 2013, to determine the accuracy of the PI data
reported during those periods. The inspectors reviewed the licensees reactor coolant
system chemistry samples, TS requirements, IRs, event reports, and NRC integrated
inspection reports to validate the accuracy of the submittals. The inspectors also
reviewed the licensees IR database to determine if any problems had been identified
with the PI data collected or transmitted for this indicator. In addition to record reviews,
the inspectors observed a chemistry technician obtain and analyze a reactor coolant
system sample. Documents reviewed are listed in the Attachment to this report.
This inspection constituted two reactor coolant system specific activity samples as
defined in IP 71151-05.
b. Findings
No findings were identified.
Mitigating Systems Performance IndexHigh Pressure Injection Systems
a. Inspection Scope
The inspectors sampled licensee submittals for the mitigating systems performance
index (MSPI)high pressure injection systems PI for Quad Cities Nuclear Power
Station, Units 1 and 2, for the period from the fourth quarter 2016 through the third
quarter 2017. 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 licensees operator narrative logs, IRs, MSPI
derivation reports, event reports and NRC integrated inspection reports for the period of
October 1, 2016, through September 30, 2017, to validate the accuracy of the
submittals. The inspectors reviewed the MSPI component risk coefficient to determine if
it had changed by more than 25 percent in value since the previous inspection, and if so,
that the change was in accordance with applicable NEI guidance. The inspectors also
reviewed the licensees 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.
22
This inspection constituted two MSPI high pressure injection system samples as defined
in IP 71151-05.
b. Findings
No findings were identified.
Mitigating Systems Performance IndexHeat Removal Systems
a. Inspection Scope
The inspectors sampled licensee submittals for the MSPIheat removal systems PI for
Quad Cities Nuclear Power Station, Units 1 and 2, for the period from the fourth quarter
2016 through the third quarter 2017. 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 licensees operator narrative
logs, IRs, event reports, MSPI derivation reports, and NRC integrated inspection reports
for the period of October 1, 2016, through September 30, 2017, to validate the accuracy
of the submittals. The inspectors reviewed the MSPI component risk coefficient to
determine if it had changed by more than 25 percent in value since the previous
inspection, and if so, that the change was in accordance with applicable NEI guidance.
The inspectors also reviewed the licensees 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 MSPI heat removal systems samples as defined in
IP 71151-05.
b. Findings
No findings were identified.
Mitigating Systems Performance IndexResidual Heat Removal System
a. Inspection Scope
The inspectors sampled licensee submittals for the MSPIResidual Heat Removal
System PI for Units 1 and 2 for the period from the fourth quarter 2016 through the third
quarter 2017. 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 licensees operator narrative logs, IRs, MSPI
derivation reports, event reports and NRC integrated inspection reports for the period of
October 1, 2016, through September 30, 2017, to validate the accuracy of the
submittals. The inspectors reviewed the MSPI component risk coefficient to determine if
it had changed by more than 25 percent in value since the previous inspection, and if so,
that the change was in accordance with applicable NEI guidance. The inspectors also
reviewed the licensees 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.
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This inspection constituted two MSPI residual heat removal systems samples as defined
in IP 71151-05.
b. Findings
No findings were identified.
Mitigating Systems Performance IndexCooling Water Systems
a. Inspection Scope
The inspectors sampled licensee submittals for the MSPIcooling water systems PI
Units 1 and 2 for the period from the fourth quarter 2016 through the third quarter 2017.
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 licensees operator narrative logs, IRs, MSPI derivation reports,
event reports and NRC integrated inspection reports for the period of October 1, 2016,
through September 30, 2017, to validate the accuracy of the submittals. The inspectors
reviewed the MSPI component risk coefficient to determine if it had changed by more
than 25 percent in value since the previous inspection, and if so, that the change was in
accordance with applicable NEI guidance. The inspectors also reviewed the licensees
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 MSPI cooling water systems samples as defined in
IP 71151-05.
b. Findings
No findings were identified.
4OA2 Identification and Resolution of Problems (71152)
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 licensees 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 licensees corrective action
program 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.
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b. Findings
No findings were identified.
Semi-Annual Trend Review
a. Inspection Scope
The inspectors performed a review of the licensees CAP and associated documents to
identify trends that could indicate the existence of a more significant safety issue. The
inspectors review was focused on repetitive equipment issues, but also considered the
results of daily inspector CAP item screening discussed in Section 4OA2.1 above,
licensee trending efforts, and licensee human performance results. The inspectors
review nominally considered the 6-month period of June 1, 2017, through November 30,
2017, although some examples expanded beyond those dates where the scope of the
trend warranted.
The review also included issues documented outside the CAP in major equipment
problem lists, repetitive and/or rework maintenance lists, departmental
problem/challenges lists, system health reports, quality assurance audit/surveillance
reports, self-assessment reports, and Maintenance Rule assessments. The inspectors
compared and contrasted their results with the results contained in the licensees
CAP trending reports. Corrective actions associated with a sample of the issues
identified in the licensees trending reports were reviewed for adequacy.
This review constituted one semi-annual trend review inspection sample as defined in
b. Observations and Assessments
The inspectors reviewed the licensees internal trend review which spanned the range of
four quarters for emerging cross-cutting themes. The cross-cutting areas identified by
the licensee as having been impacted over the last four quarters were work
management, training, avoiding complacency, and conservative bias. The inspectors
reviewed the licensees assessment which did not identify any trends/themes in the
areas impacted. The inspectors verified the licensee continuously monitored
cross-cutting areas for the presence of recurring themes. The inspectors review did not
identify any recurring themes with equipment issues or in other areas such as work
management, human performance, or problem identification and resolution that were
indicative of a more significant safety issue. The inspectors also performed a more
focused review of the licensees corrective action database and resolution and
identification of issues associated with safety-related relays. The inspectors reviewed
the database to identify if any previous relay failures could be attributed to gaps in the
licensees preventative maintenance strategies and work practices. No trends/themes
were identified.
c. Findings
No findings were identified.
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4OA3 Follow-Up of Events and Notices of Enforcement Discretion (71153)
(Closed) Licensee Event Report 05000265/2017-001-00: High Pressure Coolant
Injection Minimum Flow Valve Failed to Open
On May 15, 2017, operations personnel performed surveillance procedure QCOS 2300-
05, HPCI Pump Operability Test. While securing from the test, operators tripped the
HPCI turbine, and the HPCI minimum flow bypass valve failed to open on low flow.
Operators attempted to manually open the minimum flow bypass valve. However, when
they released the control switch, the valve returned to the closed position. Since the
acceptance criteria in the surveillance procedure requires proper operation of the
minimum flow valve, the licensee declared the HPCI system inoperable due to the
apparent failure of the minimum flow valve to operate properly. The licensee
documented the issue in IR 4011130, During HPCI S/D MO 2-2301-14 did not Auto
Open. The licensees investigation identified that the HPCI pump discharge flow
indicating switch had an intermittent failure that was caused by a manufacturing defect.
The defect caused the minimum flow valve to receive a sporadic continuous closed
signal. The licensee replaced the flow indicating switch (FIS), retested the system, and
declared HPCI operable. An engineering evaluation by the licensee discussed that the
minimum flow bypass valve is designed for pump protection when other discharge line
valves are closed (i.e. during testing). Therefore, in the event of a loss of coolant
accident, HPCI would have still been able to perform its design safety-related function
because the HPCI discharge valves to the reactor would open and no pump damage
would be expected to occur. Based on the inspectors discussions with the licensee, the
licensee determined that their procedure direction, to declare HPCI inoperable, may
have been overly restrictive and initiated a procedure change to clarify the function of the
minimum flow valve. The inspectors reviewed the licensees evaluation and did not
identified a performance deficiency.
Documents reviewed are listed in the Attachment to this report. This licensee event
report (LER) is closed.
This event follow-up review constituted one sample as defined in IP 71153-05.
Retraction of Event Notification No. 52955: High Pressure Coolant Injection System
The original event occurred on September 8, 2017, when the Unit 2 HPCI minimum flow
valve, MO 2-2301-14, flow indicating switch, FIS 2-2354, failed to meet the TS
allowable value during calibration testing using procedure QCIS 2300-10, HPCI Pump
Discharge Flow Switch Calibration and Functional Test, Revision 8, and HPCI was
subsequently declared inoperable. The licensee reported the event as a condition that
could have prevented fulfillment of a safety function in accordance with
10 CFR 50.72(b)(3)(v)(D). Since the HPCI system is a single train system, the loss of
HPCI would prevent the high pressure injection safety function that HPCI provides. The
flow indicating switch, FIS 2-2354, was successfully recalibrated and HPCI was returned
to Operable status approximately 10 minutes after it was found out of tolerance.
After reviewing the details of this event under IR 4050176, the licensee determined that
the surveillance procedure contained an overly restrictive statement that directed
operators to immediately declare the HPCI system inoperable when FIS 2-2354 fails.
This statement was in conflict with TS 3.3.5.1, Condition E, which allows 7 days to
26
restore the HPCI FIS (instrument channel only) to an operable status prior to entry into
TS 3.3.5.1, Condition H, which requires declaring HPCI inoperable immediately.
Therefore, during the period of the FIS inoperability10 minutesthe HPCI system was
not required to be declared inoperable in accordance with TS. Licensee corrective
actions included a revision to the procedure which would direct entry into the appropriate
instrumentation TS.
The inspectors reviewed the licensees basis for the event retraction and verified that
HPCI was not required to be declared inoperable at the time of the event. The
inspectors noted that while the FIS failed the calibration, it would have still functioned
and opened the minimum flow valve. However, it would have opened at a lower flow
rate than required by the TS. The inspectors also noted that this FIS calibration
surveillance failure differed from the event described in LER 05000265/2017-001 due to
the failure mechanism of the FIS. The event described in that LER prevented the
minimum flow valve from operating automatically or manually, and the minimum flow
valve was declared inoperable during that event, again due to procedural guidance in
another surveillance procedure that was later determined to be overly restrictive. No
performance deficiencies were identified.
This event follow-up review constituted one sample as defined in IP 71153-05.
(Closed) Licensee Event Report 05000254/2017-003-00: Control Room Emergency
Ventilation Air Conditioning Piping Refrigerant Leak Due to High Cycle Fatigue
On September 21, 2017, the licensee identified a refrigerant leak at an expansion joint
located on the discharge piping of the CREV air conditioning (AC) system compressor.
The licensee declared the refrigeration condensing unit inoperable and entered TS 3.7.5,
Condition A, which required restoration of the CREV AC system within 30 days. The
licensee was required to report the condition under 10 CFR 50.72/73 (a)(2)(v)(D)
because the CREV AC system is a single train safety system required to mitigate the
consequences of an accident. The licensee determined that the piping failure was
caused by high cycle fatigue at the expansion joint, which had been in service for
approximately 20 years. As a result, the licensee replaced the compressor discharge
pipe fitting (expansion joint).
The licensee had experienced three compressor failures over the 20-year timespan,
which were suspected to be the main causes of the increased vibrations on the piping.
Due to previous compressor modifications following the prior failures, the licensee
expected the replaced fitting will continue to function beyond the life of the plant. The
inspectors reviewed the licensees evaluation and corrective actions. No performance
deficiencies were identified.
This event follow-up review constituted one sample as defined in IP 71153-05.
27
4OA5 Other Activities
Review of Independent Spent Fuel Storage Installation Storage Pad Design (60856,
Appendix A)
a. Inspection Scope
The licensee currently has an Independent Spent Fuel Storage Installation (ISFSI) pad
with a capacity to store 60 casks and plans to expand the ISFSI capacity by installation
of a new pad to accommodate an additional 114 casks. Title 10 of the Code of Federal
Regulations (10 CFR) 72.212(b)(5)(ii) requires that licensees perform written evaluations,
before use, which establish that cask storage pads and areas have been designed to
adequately support the static and dynamic loads of the stored casks, considering potential
amplification of earthquakes through soil-structure interaction, and soil liquefaction
potential or other soil instability due to vibratory ground motion.
The inspectors evaluated the licensees soil and ISFSI pad engineering design
evaluations for the new pad to verify the licensees compliance with the cask Certificate of
Compliance (CoC), 10 CFR Part 72 requirements, and industry standards.
The licensee was utilizing the Holtec HI-STORM 100S, Version B (218) dry cask storage
system. The new reinforced concrete pad was 35 inches thick and capable of
supporting 114 HI-STORM casks in a 6-by-19 array. The pad was 89 feet wide and
307.5 feet long. The licensee designed and constructed the ISFSI pad as an
important-to-safety (category C) structure.
The inspectors reviewed the licensees soil investigation reports and calculations
documenting the engineering properties and design soil profile of the ISFSI site based
on new geotechnical investigations of the ISFSI areas combined with the data in the plant
UFSAR. The inspectors reviewed documents to verify that the pad design duly addressed
geological and hydrological considerations using the information from the earlier and the
new soil investigations as applicable. The inspectors reviewed the licensees liquefaction
analysis to verify seismic input and safety factors were consistent with Regulatory
Guidance 1.198, Procedures and Criteria for Assessing Seismic Soil Liquefaction at
Nuclear Power Plant Sites.
The inspectors reviewed documents for the generation of new seismic acceleration time
histories from the seismic ground motion spectra for the reactor site to be used as inputs for
the ISFSI analyses. The inspectors reviewed the soil structure interaction analysis
methodology and calculations to verify adequacy of the soil/pad/cask analytical model. The
inspectors reviewed the ISFSI pad structural design to verify the methodology, load factors
and acceptance criteria, as well as considerations of settlements, static/dynamic and
sequential/partial loadings.
The inspectors reviewed the licensees cask haul path evaluations to verify that
maximum expected loads were considered in the design of the new haul path. The
inspectors interviewed licensee personnel and performed walkdowns of the haul path
and the ISFSI areas to verify that licensee had reviewed the haul path for the
right-of-way requirements and potential interferences from nearby structures and
overhead lines and that any impact on buried utilities was also addressed, as applicable.
28
b. Findings
No findings were identified.
On-site Fabrication of Components and Construction of an Independent Spent Fuel
Storage Installation (60853)
a. Inspection Scope
The inspectors performed a walkdown of the new ISFSI pad construction site on
September 26 and 27, 2017, after the licensee had performed significant earthwork and
placed engineered fill for the pad, but before any concrete formwork or rebar for the pad
had been placed. The inspectors observed the licensees process for setting up and
performing a plate load test on the engineered fill for the ISFSI pad. The inspectors also
interviewed licensee and contractor personnel to evaluate their understanding of the
design and construction specifications for the ISFSI pad.
The inspectors evaluated the licensees construction activities for the new pad to verify the
licensees compliance with the cask CoC, 10 CFR Part 72 requirements, the cask Final
Safety Analysis Report, the ISFSI pad design specification, and applicable industry
standards.
As the licensee continues the construction process for this ISFSI pad expansion into
2018 to include both rebar and concrete placement, the inspectors will continue to utilize
IP 60853 to evaluate the licensees compliance. The results of this inspection will be
documented in a future inspection report.
b. Findings
No findings were identified.
4OA6 Management Meetings
Exit Meeting Summary
On January 3, 2018, the inspectors presented the inspection results to Mr. H. Dodd 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.
Interim Exit Meetings
Interim exits were conducted for:
- The results of the biennial LORT program inspection were presented to
Mr. H. Dodd, Plant Manager, and other licensee staff members on
October 20, 2017.
- The inspectors presented the characterization of a potential enforcement issue
(URI) identified during the biennial LORT inspection to Mr. E. Pannell, Training
Manager, and other licensee staff members via telephone conference on
January 2, 2018.
29
- The results of the ISFSI pad inspection were presented to Mr. C. Alguire and
other members of the licensee staff via telephone conference on
November 20, 2017.
- The results of the emergency preparedness program inspection were presented
to Mr. G. Buckley, Emergency Preparedness Manager, via telephone on
November 22, 2017.
- The results for the radiation safety program review inspection were presented
with Mr. H. Dodd, Plant Manager, on December 14, 2017.
The inspectors confirmed that none of the potential report inputs discussed were
considered proprietary. Proprietary material received during the inspections was
returned to the licensee.
ATTACHMENT: SUPPLEMENTAL INFORMATION
30
SUPPLEMENTAL INFORMATION
KEY POINTS OF CONTACT
Licensee
H. Dodd, Plant General Manager
M. Anderson, Maintenance Director
J. Bries, Operations Director
T. Bell, Engineering Director
D. Collins, Radiation Protection Manager
J. Cox, Shift Operations Superintendent
R. Craddick, Organizational Effectiveness Manager
M. Humphrey, Regulatory Assurance
T. Petersen, Regulatory Assurance
J. Roos, System Engineering Electrical Manager
T. Wojcik, Engineering Manager
J. Woolridge, Chemistry Manager
U.S. Nuclear Regulatory Commission
L. Kozak, Acting Chief, Reactor Projects Branch 1
R. Murray, Senior Resident Inspector
K. Carrington, Resident Inspector
Illinois Emergency Management Agency (IEMA)
C. Mathews, IEMA
C. Settles, IEMA
Attachment
LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED
Opened
05000254/2017004-01; URI Repeat Use of Written Exams during Licensed Operator
05000265/2017004-01 Requalification Examinations (Section 1R11)
Closed
05000265/2017001-00 LER High Pressure Coolant Injection Minimum Flow Valve
Failed to Open (Section 4OA3.1)05000254/2017003-00 LER Control Room Emergency Ventilation Air Conditioning
Piping Refrigerant Leak Due to High Cycle Fatigue
(Section 4OA3.3)
Discussed
None.
2
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 Document Description or Title Revision or
Number Number Date
Section 1R01
1R01 QCAN 901(2)-7 Traveling Screens High DP Annunciator 5
C-15 Response
1R01 QCOP 4400-09 Circulating Water System Flow Reversal-TIC 30a/ TIC
3452 3452
1R01 QCOP 4400-02 Circulating Water System Startup and 37
Shutdown
1R01 IR 4084820 Fish Impingement Challenges Unit Availability 12/16/2017
1R01 IR 4084886 EO ID: 2C Traveling Screen Metal Guide 12/17/2017
Ripped out of Place
1R01 IR 4084887 One Panel of 2D Traveling Screen Found 12/17/2017
Partially Detached
Section 1R04
1R04 IR 4050467 EO ID: U1 RCIC Turbine Vacuum Pump Leak 09/10/2017
1R04 QOM 1-1300-02 Unit 1 RCIC Valve Checklist (RCIC Room) 10
1R04 QOM 1-1301-03 Unit 1 RCIC Valve Checklist (Not in RCIC 10
Room)
1R04 STN 17-073 RCIC Turbine Vacuum Pump
1R04 QCOP 6600-23 Unit 1 Diesel Generator Preparation for 3
Standby Operation
1R04 QCOP 6600-04 Diesel Generator 1/2 Preparation for Standby 23
Operation
1R04 QOM 2-2300-01 Unit 2 HPCI Valve Checklist 18
1R04 QOM 1-2300-02 HPCI System Fuse and Breaker Checklist 6
Section 1R05
1R05 QDC-4100-M- Combustible Loading Calculation for the Power 6D
0691 Block, SBO Building and Crib House
1R05 Fire Hazards Analysis Methodology and 22
Assumptions
1R05 Quad Cites Generating Station Pre-Fire Plan: October
Unit 2 TB 5950 Elev. Safe Shutdown Pump 2013
Room, Fire Zone 5.0
1R05 Quad Cites Generating Station Pre-Fire Plan: July 2009
Unit 2 RB 5440 Elev. HPCI Pump Room, Fire
Zone 11.1.4
Section 1R11
1R11 AT 3984542-04 SA: Pre-NRC 71111.11B 10/12/2017
1R11 IR 4083711 NRC Concern Related to LORT 12/13/2017
Comprehensive Written Exams
3
1R11 IR 4063652 NRC ID: Active License Tracking Log 10/16/2017
Discrepancies
1R11 TQ-AA-306 Simulator Management 8
1R11 TQ-AA-155-F04 Simulator Evaluation FormsIndividual, 10/19/2017
Crew F
1R11 TQ-AA-155-F05 Simulator Evaluation FormsCrew, Crew F 10/19/2017
1R11 TQ-AA-155-F04 Simulator Evaluation FormsIndividual, 10/19/2017
Crew F
1R11 NOSA-QDC-15- Quad Cities Functional Area Audit Report 09/23/2015
08
1R11 Q1C25 Simulator Core Model Test
1R11 Q1C25 Simulator Cert Testing
1R11 LORT 2017 Operating Exam #7 Scenario 20
Based Testing
1R11 LORT 2017 Operating Exam #3 Scenario 21
Based Testing
1R11 ILT NRC Scenario #2 Scenario Based Testing 0
1R11 Simulator ComparisonCV #4 Failure 04/15/2017
1R11 Simulator ComparisonU1 Feedwater Heater 05/30/2015
Excursion
1R11 Simulator ComparisonU1 Feedwater Heater 11/14/2015
Excursion
1R11 Simulator ComparisonU1 Manual SCRAM 04/02/2015
Due to D-Ring Header Steam Leak
1R11 IR 3949564 TrainingSimulator Critical Task List Review 12/05/2016
1R11 IR 2674201 Paragon Knowledge Gap Regarding Drywell
Inerted State
1R11 IR 2687088 Did Not Proactively Ensure REMA Dates Were
Valid-Updated for Downpower Extension
1R11 IR 2697050 Did Not Notify Key Personnel Outside the MCR
When HVAC Tripped on High Toxic Gas
1R11 IR 2716967 Supervisor Left RoleAcknowledged Control
Room Alarms Due to Perceived Time Pressure
1R11 IR 3956869 Missed Opportunity to Update Crew on Status
of FW Heater Transient Before Re-Latching of
1R11 IR 4003770 Crew Didnt Recognize Load Drop Exceeded
20% in One Hour, Didnt Request RETS
Sample
1R11 IR 2503095 Update Needed to Time Sensitive Actions in
OP-QC-102-106
1R11 IR 4055629 TrainingSimulator Crash During OBE 09/25/2017
1R11 IR 4030214 Simulator Crashed During LORT Training 07/10/2017
Scenario
1R11 IR 2741979 QDC-EP-2016-NRC-Simulator Issue 11/16/2016
1R11 IR 2726915 Simulator MST Abort Caused Lost Simulator 10/11/2016
Training Time
1R11 IR 2568617 TrainingDelay in LORT NRC Exams Due to 10/07/2015
Simulator Malfunctions
4
1R11 IR 2618447 Training: Loss of Training Time Due to 01/28/2016
Simulator Malfunction
1R11 SWR 133381 Simulator Crashing When Reactor 10/05/2017
Depressurizes Less Than 20 psi
1R11 SWR 133333 Meter Scaling Items from SWR 132888 That 09/20/2017
Require a Software Change
1R11 SWR 133628 EC 619744Cyber Security Remediation: 10/12/2017
Isolate Recorders from Recorder Server
Network
1R11 Reactivation of License Logs (various) February
2016 - April
2017
1R11 Active License Tracking Logs 1 Quarter
st
2016, 3rd
Quarter
2016, 2nd
Quarter
2017
1R11 2017 Crew F RO Written LORT Annual
Requalification Exam
1R11 2017 Crew F SRO Written LORT Annual
Requalification Exam
1R11 Quad Cities Operation Static Exam Bank, Static 5
Exam: STATIC23
1R11 JPM LP-003-II-A Locally Start of U1/2 DG with Failure of the 1/2 1
EDGCWP
1R11 JPM LP-040-I Bypassing RCIC Steam Line Isolation Signal 11
1R11 JPM LS-001-II-A Startup the RHRSW System with Reduced 13
Pump Capacity
1R11 JPM LS-038-I Perform the Unit 1 Weekly Turbine Generator 3
Tests
1R11 JPM LS-083-I Bypass A Channel of the Reactor Mode 3
Switch to Shutdown Scram
1R11 JPM SRO-012-I Initiate a Fire Impairment Permit Requiring 4
Compensatory Actions
1R11 JPM LP-042-II Main Feedwater Regulator into Local Operation 3
1R11 JPM LP-043-I Local Emergency Start of the 1(2) SBO Diesel 13
Generator
1R11 JPM LS-002-I-A Shutdown the U 1/2 B SBGT with a Failure of 8
Damper to Close
1R11 JPM LS-005-II Transfer Auxiliary Power from Xfmr 11 to 22
Xfmr 12
1R11 JPM LS-044-I-A HPCI Startup with an Inadvertent Isolation 4
1R11 JPM SRO-003-I Review Faulted Jet Pump Operability 9
Surveillance
1R11 License Requalification Operating Exam #7, 23
dated 08/17
1R11 License Requalification Operating Exam #3, 24
dated 08/17
5
1R11 License Requalification Operating Exam #10, 19
dated 08/17
1R11 License Requalification Operating Exam #20, 18
dated 08/17
Section 1R12
1R12 ENGAGE PM Template for SSMP System
1R12 Maintenance Rule Basis DocumentSS2900
(Safe Shutdown Make-Up Pump)
1R12 IR 1201017 SSMP Room Cooler Trend IR 04/11/2011
1R12 IR 1209711 MRule: Performance Criteria Exceeded (SSMP 04/29/2011
RM Cooler)
1R12 IR 1592607 SSMP HS 1-2940-4 Difficult to Place In PTL 12/04/2013
1R12 IR 2633959 SSMP MCC 30 Local Control Switch Failed 03/01/2016
1R12 IR 2728974 MRule Unavailability Missed for SSMP 10/17/2016
1R12 IR 3997936 PSUMCR SSMP FIC 0-2940-7 Is Not 04/13/2017
Controlling in Auto or Man
1R12 IR 4027615 WO to Remove Spare Contacts SSMP MCC 30 06/30/2017
C3
1R12 IR 4030993 WO Needed for SSMP FIC 2940-7 07/12/2017
1R12 IR 4040433 SSMP FIC Would Not Reach 400 GPM with 08/09/2017
Setpoint at 400 GPM
1R12 IR 4078579 SSMP Reserve Feed MCR Switch Will Not 11/28/2017
Close
1R12 IR 4078677 EO ID: Local Control Switch Would Not Start 11/28/2017
the SSMP
Section 1R13
1R13 Work Week Profile 17-40-04
1R13 Work Week Profile 17-42-06
1R13 Work Week Profile 17-46-10
1R13 Work Week Profile 17-51-02
1R13 2017.11.13.22.05. Protected System/Pathway Checklist 11/13/2017
49
1R13 ER-AA-600-1042 On-line Risk Management 11
1R13 QC-CRM-38 Overall On-line Risk Determination 0
1R13 WC-AA-101 On-line Work Control Process 27
Section 1R15
1R15 GEK-9597 Quad Cities Nuclear Power Station Equipment December
ManualChapter 34, Heating, Ventilation, and 1973
Air Conditioning
1R15 IR 2730448 Lessons Learned From B CREVs LCO Week 10/20/2016
of 10-10-16
1R15 IR 4062552 B Train CREV Superheat Value High 10/13/2017
1R15 NES 709-3 Installation, Operation and Maintenance 3
Instructions for Refrigeration Condensing Units
Control Room HVAC Upgrade Nuclear Electric
Generating Facilities at Dresden and Quad
Cities
1R15 QDC-5700-H- Heat Gain Calculation for Train B Control Room 0
0805 HVAC System
6
1R15 GE Sil No. 657 Standby Liquid Control System Accumulator 09/07/2006
Bladder
1R15 IR 4066290 1A SBLC Pump Accumulator Schraeder Valve 10/24/2017
is Stuck Open
1R15 4E-1527, Sheet 3 Schematic Diagram High Pressure Coolant Q
Injection System Sensors and Auxiliary Relays
1R15 4E-1533 Schematic Diagram HPCI Turbine Motor Gear AP
Unit Speed Exchanger and Auxiliary Valves
1R15 M-46 Diagram of HPCI Turbine Lubricating and G
Hydraulic Oil System and Pump Seal Cooler
Piping
1R15 QCOS 2300-05 HPCI Pump Operability Test 79
1R15 IR 4078579 SSMP Reserve Feed MCR Switch Will Not 11/28/2017
Close
1R15 IR 4078677 EO ID: Local Control Switch Would Not Start 11/28/2017
the SSMP
1R15 QCOP 2900-01 Safe Shutdown Makeup Pump System 39
Preparation for Standby Operation
1R15 QCOS 2900-10 Safe Shutdown Makeup Pump Local Panel 5
Flow Test
Section 1R18
1R18 4E-1828 Wiring Diagram HPCI System Signal N
1R18 EC 619131 U-1 HPCI Signal Converter Output Failed 04/18/2017
Alarm Bypass
1R18 IR 3992828 Local Current Meter 1-2386-8206 Erratic 04/01/2017
1R18 IR 3997418 Unexpected 901-3 H-9 Alarm 04/12/2017
1R18 QCAN 901(2)-3 HPCI Controller Signal Converter Output Failed 3
1R18 WO 4625756 Unexpected 901-3 H-9 Alarm 04/28/2017
Section 1R19
1R19 EC 24448 Replace the 1/2 Standby Diesel
Generator Seismic Qualification Utility Group
(SQUQ) Relays and the Associated DC Control
Power Transfer Switch
1R19 IR 4057911 Incorrect Step in QCIPM 6600-03 10/01/2017
1R19 IR 4057926 1/2 EDG Governor Booster Pump Needs to Be 10/01/2017
Replaced
1R19 IR 4067226 1/2 EDG LCO Extent of Condition Issues 10/26/2017
1R19 QCEPM 0400-10 Emergency Diesel Speed Sensing Circuit 26
Testing and Calibration
1R19 QCMMS 6600-03 Emergency Diesel Generator Periodic 33
Preventive Maintenance Inspection
1R19 WO 1656769-03 IM Replace U-0 EDG Speed Switch 0-6601-ES 09/29/2016
1R19 WO 1914200 (LR) Diesel Generator Periodic Insp 10/02/2017
1R19 WO 1914200-02 (LR) Diesel Generator Periodic Insp 10/02/2017
1R19 Drawing R107D- Equipment Arrangement, Control Room
1321710-F, Refrigeration Condensing Unit
Sheet 2
1R19 WO 4694130 Control Room Emergency Filtration Sys Test 10/12/2017
(IST)
1R19 WO 4697777 B CR HVAC Bundled PMT Review 10/13/2017
7
1R19 WO 4709406 Unit 1 HPCI Did Not Trip During QCOS 2300- 11/09/2017
05
1R19 QCOS 2300-05 HPCI Pump Operability Test 79
1R19 WO 1924709 SBO DG Jacket Water Booster Pump Recirc 11/03/2017
Valve Pressure Control Test
1R19 WO 1945526 SBO Overspeed Trip Test 11/03/2017
1R19 WO 4671151 SBO DG Load Test 11/03/2017
1R19 WO 4671154 SBO DG Jacket Water Booster Pump Test 11/03/2017
1R19 WO 4671158 SBO DG Starting Air Compressor B 11/03/2017
1R19 WO 4712561 PS 2-0504-A Did Not Function as Expected 11/16/2017
1R19 QCIS 0500-06 Unit 2 Division I Turbine First Stage Low 7
Pressure Above Setpoint Calibration and
Functional Test
1R19 QCOS 2900-01 Safe Shutdown Makeup Pump Flow Rate Test 38
1R19 WO 4717433-01 SSMP Reserve Feed MCR Switch Will Not 11/29/2017
Close
1R19 WO 4717766-01 Local Control Switch Would Not Start the 11/29/2017
1R19 QCOP 2900-01 Safe Shutdown Makeup Pump System 39
Preparation for Standby Operation
1R19 QCOS 2900-10 Safe Shutdown Makeup Pump Local Panel 5
Flow Test
1R19 QCOS 7500-04 Unit 1 Standby Gas Treatment Initiation and 36
Reactor Building Ventilation Isolation Test
Section 1R22
1R22 IR 4059849 Discrepancies to QCOS 7500-08 10/05/2017
1R22 QCOS 1400-07 Core Spray Pump 15
Comprehensive/Performance Test
1R22 QCEMS 0230-11 Modified Performance Test of Unit 1(2) 125 10
VDC Normal or Alternate Battery
1R22 IEEE/ANSI 450- Recommended Practice for 03/09/1987
1987 Maintenance,Testing, and Replacement of
Large Lead Batteries for Generating Stations
and Substations
Section 1EP4
1EP4 EP-AA-1000 Exelon Nuclear Standardized Radiological 29
1EP4 EP-AA-1006 Quad Cities Emergency Plan Annex 37 and 38
1EP4 EP-AA-1006, Emergency Actions Levels for Quad Cities 2 and 3
Addendum 3
1EP4 EP-QC-1000 Quad Cities Power Station Radiological 0
1EP4 Evaluation 16-106 50.54(q) Evaluation and Effectiveness Review 09/19/2016
1EP4 Evaluation 17-27 50.54(q) Evaluation and Effectiveness Review 03/20/2017
Section 1EP6
1EP6 Nuclear Accident Reporting System (NARS) 11/08/2017
Form for Quad Cities 4th Qtr PI Drill
1EP6 Quad Cities Generating Station 2017 4th Qtr PI 11/08/2017
Drill
8
1EP6 EP-AA-111-F-06 Quad Cities PAR Flowchart G
Section 2RS2
2RS2 IR 3995639-04 Occupational ALARA Planning and Controls 10/31/2017
2RS2 IR 3964145 Check-In Self-Assessment; Exposure Controls 02/28/2017
Inspection
2RS2 IR 2635387 Check-In Self-Assessment; Fleet ALARA 12/21/2016
Program
2RS2 IR 2589636 Check-In Self-Assessment; Exposure Controls 02/22/2016
Inspection, ALARA
2RS2 IR 2426117 Check-In Self-Assessment; Occupational 07/17/2015
ALARA Planning and Controls
2RS2 IR 3996125 CB&I Accumulated Dose Alarm 04/09/2017
2RS2 RP-AA-203- Personnel Exposure Investigation; EID 04/09/2017
1001, Hurley1491
Attachment 1
2RS2 IR 2686986 Potential Adverse Trend for Online Emergent 06/26/2016
Dose
2RS2 IR 3994959 Accumulated Dose Alarm Received in Unit 04/06/2017
MSIV Room
2RS2 IR 4006044 ALARA Post Job Review QC-01-17-00506 05/03/2017
2RS2 IR 4001030 RWP QC-01-17-00802 TB Main Cond 04/21/2017
Activities Exceed 25% Estimate
2RS2 IR 4000935 RWP QC-01-17-00517 Estimate >1 REM & 04/21/2017
Under Original Estimate
2RS2 IR 4000935 RWP QC-01-17-00518 Estimate >1 REM & 04/21/2017
Under Original Estimate
2RS2 IR 4000612 OLL: RWP QC-01-17-00403-01 OB MSIV 04/20/2017
Activities Exceeded Estimates
2RS2 RWP QC-01-17- DW Scaffolding Activities (Q1R24) Various
00506 Dates
2RS2 RWP QC-01-17- DW I/B MSIV Over Haul (Q1R24) Various
00541 Dates
2RS2 RWP QC-01-17- FF Rx Disassembly/Reassembly Activities Various
00901 (Q1R24) Dates
2RS2 RWP QC-02-16- DW Scaffolding Activities Various
00506 Dates
2RS2 RWP QC-02-16- DW Ventilation/Cooler System Activities Various
00507 (Q2R23) Dates
2RS2 Quad Cities Generating Station; Radiation N/A
Protection Q1R23 Refueling Outage Report
2RS2 Quad Cities Generating Station; Radiation N/A
Protection Q2R23 Refueling Outage Report
2RS2 Quad Cities Generating Station; Radiation 07/25/2017
Protection Q1R24 Refueling Outage Report
2RS2 RP-AA-400-1001 Establishing Collective Radiation Exposure 4
Annual Business Plan Goals
2RS2 RP-AA-401 Operational ALARA Planning and Controls 22
2RS2 CC-AA-401 Maintenance Specification: Installation and 10
Control of Temporary Shielding
9
2RS2 RP-QC-552 Source Term Reduction External 1
System/Component Flushing
2RS2 RP-AA-402 Radiation Protection Dose Excellence Planning 8
Process
2RS2 RP-AA-402, Abbreviated Exposure Reduction Plan 2017- 0
Attachment 1 2021
2RS2 RP-AA-400 ALARA Program 14
2RS2 RP-AA-230 Operation of the Canberra FASTSCAN Whole 3
Body Counter Using ABACOS Plus
2RS2 RP-AA-227 Operation of the Canberra ACCUSCAN Whole 0
Body Counter
2RS2 RP-AA-700 Controls for Radiation Protection 4
Instrumentation
2RS2 RP-AA-700-1401 Operation and Calibration of Eberline Model 4
PM-7 Personnel Contamination Monitor
2RS2 RPP-AA-700- Calibration Data Sheet PM-7 Portal Monitor; 11/30/2017
1401, Portal Monitor Instrument #PM15
Attachment 3
2RS2 RP-AA-700-1218 Calibration of HI-VOL Air Samplers 3
2RS2 RP-AA-700- Radeco H-809C, H-809V-I; H-809V-II 07/19/2017
1218, Calibration Data Sheet; Radeco Serial Number
Attachment 1 HV098
2RS2 RP-AA-1208 Operation of the Shepherd Model 89 Calibrator 3
2RS2 RP-AA-700- Irradiator Reference Data Sheet; Instrument 08/10/2017
1208, Model Number MGP Telepole WR and FH-40
Attachment 1 GL/FH 40 TG and Telepole II
2RS2 RP-AA-700- Irradiator Reference Data Sheet; ADM-300 07/14/2017
1208, Calibration Record; ADM-300 Serial Number
Attachment 1 10651
2RS2 RP-AA-1231 Operation and Calibration of the Model LAM-11 2
Large Articles Monitor
2RS2 RP-AA-700- LAM Calibration Data Sheet; LAM-11 Serial 03/10/2017
1231, Number LAM1
Attachment 2
2RS2 RP-QC-711-100 Calibration of the IPM 7/8 Whole Body Monitors 0
2RS2 RP-QC-700-100, IPM 7/8 Calibration Record; Monitor Serial 01/10/2017
Attachment 1 Number 365
2RS2 RP-AA-700- SAM-12 Calibration Data Sheet; SAM-12 03/17/2017
1239, Serial #12234
Attachment 2
2RS2 RP-AA-700-1235 Operation and Calibration of the PM-12 3
Gamma Portal Monitor
2RS2 RP-AA-700- PM-12 Calibration Data Sheet; PM-12 Serial 07/07/2017
1235, Number PM1224
Attachment 3
2RS2 Certificate of Calibration; Asset/Equipment 02/22/2017
- 0012244; Model #RO20AA
2RS2 Certificate of Calibration; Asset/Equipment 01/23/2017
- 076568; Model #FH-40G-L
10
2RS2 Certificate of Calibration; Asset/Equipment 02/23/2017
- 076728; Model #ASP-1 w/HP-220
2RS2 Certificate of Calibration; Asset/Equipment 03/26/2017
- 076927; Model #ASP-1
2RS2 Certificate of Calibration; Asset/Equipment 02/22/2017
- 0011992; Model Ludlum 3
2RS2 Certificate of Calibration; Asset/Equipment 08/30/2017
- 0017511; Model # REM 500
2RS2 Certificate of Calibration; Asset/Equipment 03/08/2017
- 0798022 Model #AMP-100
2RS2 Certificate of Calibration; Asset/Equipment 02/23/2017
- 0015972; Model # AMS-4/AMS4OPT14
2RS2 RP-AA-700, Out of Tolerance Report; 0015972 03/02/2017
Attachment 1
2RS2 Certificate of Calibration; Asset/Equipment 02/23/2017
- 078022; Model #FHZ 612
2RS2 RP-AA-700, Out of Tolerance Report; 078022 03/02/2017
Attachment 1
2RS2 NCS-16-001 Implementation of Weekly Source Checks for 06/03/2016
RCA/PA Exit Monitors
2RS2 QDC-15-005 Unconditional Release Detection Thresholds 12/30/2015
and Dose Consequences
2RS2 QDC-17-002 2017 LAM Calibration Parameters 11/22/2017
2RS2 WO 1739632-01 Replace DW Rad Monitor (2-2149-B) 12/23/2015
2RS2 IR 2622489 Check In Self-Assessment; Radiation 10/25/2016
Protection Instrumentation
2RS2 IR 3992875 NRC Inspection (71124.05) Radiation 10/23/2017
Monitoring Instrumentation Self-Assessment
2RS2 IR 04061863 Instruments Not Labelled Appropriately 10/11/2017
2RS2 IR 02652614 CCP: Contradiction between Plan Drawings for 04/07/2016
ARM 35 & 36
2RS2 Quad Cities 10 CFR 61 Program Waste Stream 2017
Characterization and Scaling Factor Review
2RS2 50.75(g) Documented Contaminated Areas; N/A
K:RP/50.75.g
2RS2 LS-AA-2090 Monthly Data Elements for NRC Reactor 07/27/2016
Coolant System (RCS) Specific Activity and through
Supporting Data 09/28/2017
Section 4OA1
4OA1 Operator Logs from 10/01/2016 to 09/30/2017
4OA1 Units 1 and 2 HPCI and RCIC
Unavailability/Demands Data from 10/01/2016
to 09/30/2017
4OA1 MSPI Basis Document 6a
Section 4OA2
4OA2 IR 4054673 U2 CRD Water Analysis Follow Up to
4OA2 IR 4062547 CREV AC Temperature Indication Abnormal 10/13/2017
4OA2 IR 4066450 U1 1A 125V DC Battery Charger Amperage 10/24/2017
Oscillations
11
4OA2 IR 4066516 Very Slow Leak from 1A RHR Motor Lower 10/24/2017
Reservoir Drain Plug
4OA2 IR 4068539 Part 21 Potential Issue with Speed Switch 10/30/2017
4OA2 IR 4068562 Flex Generator #3 Diesel Fuel High in Water/ 10/30/2017
Sediment Test
4OA2 IR 4068571 Flex Diesel Generator #2 Diesel Fuel is 10/30/2017
Degraded
4OA2 IR 4068869 U1 Control Valve #1 Suicided Closed 10/31/2017
4OA2 Exelon Nuclear: Quad Cities Station- R.1: October
Regulatory Inspection Findings & Performance 2017
Indicator Overview
4OA2 IR 4074136 Debris Found Under Coupling of 2-6657 11/13/2017
4OA2 IR 4057926 1/2 EDG Governor Booster Pump Needs to be 10/01/2017
Replaced
4OA2 IR 4067226 1/2 EDG LCO Extent of Condition Issues 10/26/2017
4OA2 IR 4068869 U1 Control Valve #1 Suicided Closed 10/31/2017
4OA2 IR 4084574 Review of Dresden IR 4061472 for Impact at 12/15/2017
Quad Cities
4OA2 IR 4081789 OOT, PS 1-1462-A, Trend Code B1 12/07/2017
4OA2 IR 4084402 M&TE Evaluation Requires U1 QCIS 1400-01 12/15/2017
to be Re-Performed
4OA2 IR 4086596 RB Floor Drain Line Plugged 12/21/2017
4OA2 IR 4086637 Received Unexpected Alarms 902-4 G-18 and 12/21/2017
C-18
4OA2 IR 4086651 Suspect RBEDT Pump Degradation 12/21/2017
Section 4OA3
4OA3 IR 4050176 OOT, FIS 2-2354, Trend Code B2 09/08/2017
4OA3 IR 5054681 Refrigerant Leak on B Train of CR HVAC 11/09/2017
Compressor Piping
4OA5 Letter from Terracon Consultants to Exelon 09/19/2017
Business Services Co. Re: Plate Load Test
Submittal
4OA5 QCNPS 10 CFR 72.212 Evaluation Report 12
4OA5 ASTM Standard Test Method for Nonrepetitive Static Reapproved
D1196/D1196M Plate Load Tests of Soils and Flexible 2016
Pavement Components, for Use in Evaluation
and Design of Airport and Highway Pavements
4OA5 CoC 72-1014 Certificate of Compliance for Spent Fuel Amendment
Storage Casks, Issued to Holtec International 8
4OA5 Drawing B-2166 ISFSI Expansion Pad, Sheets 1-6 New
4OA5 Drawing B-2183 ISFSI Expansion Area, Final Slope New
Configuration
4OA5 EC 405175 Dry Cask Storage Project, Installation of ISFSI 0
Pad 2
4OA5 HI-2002444 Holtec International HI-STORM 100 System 11.1
4OA5 QDC-0000-S- Evaluation of Buried Utilities and Existing 3A
1339 Building Foundations Along the Haul Path for
the Dry Cask Storage Project
12
4OA5 QDC-0836-S- Seismic Soil Liquefaction Evaluation for ISFSI 0
2205 Pad Site
4OA5 QDC-0836-S- Time History Generation for Non-Linear Soil- 0
2206 Structure-Interaction Analysis for ISFSI Pad
Expansion
4OA5 QDC-0836-S- Geotechnical Slope Stability Analysis for ISFSI 0
2234 Pad Expansion Project
4OA5 QDC-0836-S- Geotechnical Analysis of Bearing Capacity, 0
2235 Subgrade Modulus Parameters for ISFSI Pad
Expansion
4OA5 QDC-0836-S- Strain-Dependent Soil Properties for ISFSI Pad 0
2238 Expansion
4OA5 QDC-0836-S- Non-Linear Soil-Structure-Interaction (SSI) 0
2239 Analysis for ISFSI Pad Expansion
4OA5 QDC-0836-S- ISFSI Pad Design for ISFSI Pad Expansion 0
2240
4OA5 RRTI-2144-011 Response to Request for Technical Information 0
Holtec International
4OA5 Specification Q- ISFSI Expansion: ISFSI Pad, Final Grading 1
2052 and Misc. Concrete Structures
13
LIST OF ACRONYMS USED
AC Air Conditioning
ADAMS Agencywide Document Access Management System
ALARA As-Low-As-Reasonably-Achievable
CAP Corrective Action Program
CFR Code of Federal Regulations
CoC Certificate of Compliance
CREV Control Room Emergency Ventilation
EAL Emergency Actions Level
EDG Emergency Diesel Generator
EHC Electro-hydraulic Control
FIS Flow Indicating Switch
FZ Fire Zone
HPCI High Pressure Coolant Injection
IMC Inspection Manual Chapter
IP Inspection Procedure
IR Issue Report
ISFSI Independent Spent Fuel Storage Installation
LER Licensee Event Report
LOR Licensed Operator Requalification
LORT Licensed Operator Requalification Training
MCC Motor Control Center
MSPI Mitigating System Performance Index
NEI Nuclear Energy Institute
NRC U.S. Nuclear Regulatory Commission
PI Performance Indicator
SAT Systems Approach to Training
SBGT Standby Gas Treatment
SDP Significance Determination Process
SSMP Safe Shutdown Makeup Pump
TS Technical Specification
UFSAR Updated Final Safety Analysis Report
URI Unresolved Item