ML16225A208
| ML16225A208 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 08/11/2016 |
| From: | Alan Blamey Reactor Projects Region 2 Branch 6 |
| To: | James Shea Tennessee Valley Authority |
| References | |
| EA-14-005 IR 2016002 | |
| Download: ML16225A208 (47) | |
See also: IR 05000260/2016002
Text
UNITED STATES
NUCLEAR REGULATORY COMMISSION
REGION II
245 PEACHTREE CENTER AVENUE NE, SUITE 1200
ATLANTA, GEORGIA 30303-1257
August 11, 2016
Mr. J.W. Shea
Vice President, Nuclear Licensing
Tennessee Valley Authority
Chattanooga, TN 37402-2801
SUBJECT: BROWNS FERRY NUCLEAR PLANT - NRC INTEGRATED INSPECTION
REPORT 05000259/2016002, 05000260/2016002, AND 05000296/2016002
Dear Mr. Shea:
On June 30, 2016, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at
your Browns Ferry Nuclear Plant, Units 1, 2, and 3. On July 15, 2016, the NRC inspectors
discussed the results of this inspection with Mr. K. Bronson and other members of your staff.
Inspectors documented the results of this inspection in the enclosed inspection report.
NRC inspectors documented two findings of very low safety significance (Green) in this report.
One of these findings involved violations of NRC requirements. Additionally, NRC inspectors
documented one Severity Level IV violation with no associated finding. Because of their very
low safety significance, the NRC is treating these violations as noncited violations (NCVs)
consistent with Section 2.3.2.a of the Enforcement Policy.
If you contest the violations or significance of these NCVs, you should provide a response
within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear
Regulatory Commission, ATTN: Document Control Desk, Washington DC 20555-0001; with
copies to the Regional Administrator, Region II; the Director, Office of Enforcement, United
States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident
Inspector at Browns Ferry Nuclear Plant.
In addition, if you disagree with a cross-cutting aspect assignment or a finding not associated
with a regulatory requirement in this report, you should provide a response within 30 days of the
date of this inspection report, with the basis for your disagreement, to the Regional
Administrator, RII, and the NRC Senior Resident Inspector at Browns Ferry Nuclear Plant.
J. Shea 2
In accordance with Title 10 of the Code of Federal Regulations 2.390, Public Inspections,
Exemptions, Requests for Withholding, of the NRC's "Rules of Practice," a copy of this letter, its
enclosure, and your response (if any) will be available electronically for public inspection in the
NRCs Public Document Room or from the Publicly Available Records (PARS) component of
NRCs Agencywide Documents Access and Management System (ADAMS). ADAMS is
accessible from the NRC Website at http://www.nrc.gov/reading-rm/adams.html (the Public
Electronic Reading Room).
Sincerely,
/RA/
Alan Blamey, Chief
Reactor Projects Branch 6
Division of Reactor Projects
Docket Nos.: 50-259, 50-260, 50-296
License Nos.: DPR-33, DPR-52, DPR-68
Enclosure: NRC Integrated Inspection Report 05000259/2016002,
05000260/2016002 and 05000296/2016002
cc: w/encl. Distribution via ListServ
__ ML16225A208 _______ SUNSI REVIEW COMPLETE FORM 665 ATTACHED
OFFICE RII:DRP RII:DRP RII:DRP RII:DRP RII:DRS HQ:RTTB
SIGNATURE Via Email/RA/DED Via Email/RA/TAS4 Via Email/RA/AMR4 Via Email/RA/ADN Via Email/RA/JRP1 Via Email/RA/MSP
NAME D. Dumbacher T. Stephen A. Ruh A. Nielsen J. Panfel M. Peck
DATE 7/29/2016 7/29/2016 7/29/2016 7/28/2016 7/28/2016 7/28/2016
E-MAIL YES NO YES NO YES NO YES NO YES NO YES NO
COPY?
OFFICE RII:DRS RII:DRS RII:DRP RII:DRP
SIGNATURE Via Email/RA/CAF2 Via Email/RA/EMS Via Email/RA/CRK1 AJB3
NAME C. Fontana S. Sanchez C. Kontz A. Blamey
DATE 8/1/2016 8/3/2016 8/8/2016 8/11/2016 8/ /2016 8/ /2016
E-MAIL YES NO YES NO YES NO YES NO YES NO YES NO
COPY?
J. Shea 3
Letter to Joseph W. Shea from Alan Blamey dated August 11, 2016.
SUBJECT: BROWNS FERRY NUCLEAR PLANT - NRC INTEGRATED INSPECTION
REPORT 05000259/2016002, 05000260/2016002, AND 05000296/2016002
Distribution w/encl:
D. Gamberoni, RII
L. Gibson, RII
OE Mail
RIDSNRRDIRS
PUBLIC
RidsNrrPMBrownsFerry Resource
U.S. NUCLEAR REGULATORY COMMISSION
REGION II
Docket Nos.: 50-259, 50-260, 50-296
License Nos.: DPR-33, DPR-52, DPR-68
Report No.: 05000259/2016002, 05000260/2016002, 05000296/2016002
Licensee: Tennessee Valley Authority (TVA)
Facility: Browns Ferry Nuclear Plant, Units 1, 2, and 3
Location: Corner of Shaw and Nuclear Plant Road
Athens, AL 35611
Dates: April 1, 2016, through June 30, 2016
Inspectors: D. Dumbacher, Senior Resident Inspector
T. Stephen, Resident Inspector
A. Ruh, Resident Inspector
C. Fontana, Emergency Preparedness Inspector
S. Sanchez, Senior Emergency Preparedness Inspector
A. Nielsen, Senior Health Physicist
J. Panfel, Reactor Inspector
M. Peck, Senior Reactor Technical Instructor
C.Kontz, Senior Project Engineer
Approved by: Alan Blamey, Chief
Reactor Projects Branch 6
Division of Reactor Projects
Enclosure
TABLE OF CONTENTS
Summary of Findings ........................................................................................................ 3
Summary of Plant Status .................................................................................................. 5
Reactor Safety
1R01 Adverse Weather Protection (71111.01) ..................................................... 5
1R04 Equipment Alignment (71111.04) ................................................................ 6
1R05 Fire Protection (71111.05) ........................................................................... 6
1R06 Flood Protection Measures (71111.06) ....................................................... 7
1R11 Licensed Operator Requalification Program (71111.11) ............................. 8
1R12 Maintenance Effectiveness (71111.12) ....................................................... 9
1R13 Maintenance Risk Assessments
and Emergent Work Control (71111.13) ................................................... 10
1R15 Operability Determinations and Functionality Assessments (71111.15)... 10
1R18 Plant Modifications (71111.18) .................................................................. 11
1R19 Post Maintenance Testing (71111.19) ....................................................... 12
1R22 Surveillance Testing (71111.22) ................................................................ 14
1EP2 Alert and Notification System Testing (71114.02) ..................................... 14
1EP3 Emergency Preparedness Organization Staffing
and Augmentation System (71114.03) ...................................................... 15
1EP4 Emergency Action Level and Emergency Plan Changes (71114.04)........ 15
1EP5 Correction of Emergency Preparedness Weaknesses (71114.05) ........... 16
1EP6 Drill Evaluation (71114.06) ........................................................................ 18
Radiation Safety
2RS6 Radioactive Gaseous and Liquid Effluent Treatment (71124.06).............. 18
2RS7 Radiological Environmental Monitoring Program (REMP) (71124.07) ...... 19
Other Activities
4OA1 Performance Indicator Verification (71151)............................................... 21
4OA2 Problem Identification and Resolution (71152) ......................................... 22
4OA3 Followup of Events and Notices of Enforcement Discretion (71153) ........ 25
4OA5 Other Activities .......................................................................................... 26
4OA6 Meetings, Including Exit ............................................................................ 29
SUMMARY
05000259/2016002, 05000260/2016002, 05000296/2016002; 04/01/2016-06/30/2016;
Browns Ferry Nuclear Plant, Units 1, 2 and 3; (Post Maintenance Testing, Maintenance of
Emergency Preparedness, Problem Identification and Resolution of Problems)
The report covered a three-month period of inspection by resident and regional inspectors. Two
findings and one traditional enforcement violation were identified. The significance of inspection
findings is indicated by their color (Green, White, Yellow, Red) using Inspection Manual Chapter
(IMC) 0609, "Significance Determination Process" (SDP) dated April 29, 2015. Cross-cutting
aspects are determined using IMC 0310, Components Within the Cross Cutting Areas dated
(December 4, 2014). All violations of NRC requirements are dispositioned in accordance with
the NRCs Enforcement Policy dated August 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-Revealing Findings and Violations
Cornerstone: Initiating Events
- Green. A self-revealing, finding for the licensees failure to provide adequate work
instructions for maintenance on the Unit 3 recirculation pump discharge valve motors which
included appropriate testing as described in Procedure NPG - SPP 06.9.3 Post Modification
testing, was a performance deficiency.
The performance deficiency was more than minor because it affected the equipment
performance attribute of the Initiating Events Cornerstone and adversely affected the
cornerstone objective to limit the likelihood of events that upset plant stability and challenge
critical safety functions during shutdown operations. The inspector performed the initial
significance determination using NRC Inspection Manual Chapter 0609, Appendix G,
Attachment 3, Shutdown Operations Significance Determination Process Phase 1 Initial
Screening and Characterization of Findings and determined that the finding was of very low
safety significance. This finding had a cross-cutting aspect in the area of human
performance because the licensee did not ensure that design documentation was correct and
that work packages provided the proper tests to ensure the Variable Frequency Drives (VFD)
/ Recirculation pump trip logic. [H.7]. (Section 1R19)
Cornerstone: Mitigating Systems
Regulations (CFR) 50.72(b)(3)(v) and 10 CFR 50.73(a)(2)(v) was identified for the licensee's
failure to notify the NRC within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and submit an LER within 60 days of discovery of a
condition that could have prevented the fulfillment of a safety function. Specifically, the
licensee failed to notify the NRC that the High Pressure Coolant Injection (HPCI) system had
been rendered inoperable due to an equipment failure. As an immediate corrective action,
the licensee entered the violation into the licensee's corrective action program as CR
1185268.
The licensees failure to provide the required notification constitutes a traditional enforcement
violation because it impacts the NRC's ability to carry out its regulatory function. The
traditional enforcement violation was determined to be Severity Level IV because it matched
4
example 6.9.d.9 of the NRC Enforcement Policy. Because the violation is a traditional
enforcement violation, no cross-cutting aspect was assigned. (Section 4OA2)
Cornerstone: Emergency Preparedness
- Green. The inspectors identified an NCV of Title 10 of the Code of Federal Regulations
(CFR) Part 50.54(q)(2), for the licensees failure to declare a Notification of Unusual Event
(NOUE) within 15 minutes of entry conditions being met. Specifically, on April 6, 2016, at
3:05 pm, Browns Ferry Unit 3 main control room (MCR) operators received a high-high
radiation alarm on the main steam lines (MSL) that met Emergency Action Level (EAL) 1.4-U
for declaring a NOUE. The licensee initiated CR 1159943 to address the issue.
This performance deficiency was more than minor because it was associated with the
Emergency Preparedness cornerstone attribute of Emergency Response Organization
Performance, and adversely affected the cornerstone objective of ensuring that a licensee is
capable of implementing adequate measures to protect the health and safety of the public in
the event of a radiological emergency. Specifically, on April 6, 2016, personnel did not
declare a NOUE within 15 minutes of initial indications that EAL 1.4-U had been exceeded.
The performance deficiency is associated with the Emergency Classification Planning
Standard, and is considered a Risk Significant Planning Standard (RSPS). The failure to
declare a NOUE when directed by the EAL Matrix is considered a lost or degraded RSPS in
accordance with Section 4 of Inspection Manual Chapter (IMC) 0609, Appendix B. Section
4.3.e of IMC 0609, Appendix B, provides the significance determination for a Failure to
Implement, and the performance deficiency was determined to be of very low safety
significance (Green). The finding was associated with a cross-cutting aspect in the
Procedure Adherence component of the Human Performance area because individuals did
not follow processes, procedures and work instructions that would have led them to declare
in a timely manner [H.8]. (Section 1EP5)
B. Licensee-Identified Violations
No findings were identified.
REPORT DETAILS
Summary of Plant Status:
Unit 1 operated at or near 100 percent rated thermal power (RTP) for the entire inspection
period except for a planned downpower to 65 percent on May 12, 2016 for main steam isolation
valve (MSIV) testing and rod pattern adjustment.
Unit 2 operated at or near 100 percent RTP for the entire inspection period.
Unit 3 operated at or near 100 percent RTP except for a planned downpower to 60 percent for
MSIV testing and rod sequence exchange on June 4, 2016.
1. REACTOR SAFETY
Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity
1R01 Adverse Weather Protection (71111.01)
.1 Readiness for Seasonal Extreme Weather Conditions:
a. Inspection Scope
After the licensee completed preparations for seasonal high temperatures, the
inspectors walked down the Unit 3 shutdown board room chiller systems. These
systems were selected because their safety related functions could be affected by
adverse weather. The inspectors reviewed documents listed in the Attachment,
observed plant conditions, and evaluated those conditions using criteria documented in
Procedure NPG-SPP-7.1.7, Station Seasonal Readiness and 0-GOI-200-3, Hot Weather
Operations. Documents reviewed are listed in the Attachment. This activity constituted
one inspection sample sample as defined in Inspection Procedure 71111.01.
b. Findings
No findings were identified.
.2 Summer Readiness of Offsite and Alternate AC Power Systems:
a. Inspection Scope
The inspectors performed the annual review of the licensees readiness of offsite and
alternate alternating current (AC) power systems prior to the onset of the high grid
loading season. The inspectors reviewed procedures affecting these areas and the
communications protocols between the transmission system operator and the licensee
to verify that appropriate information is exchanged when issues arise that could impact
the offsite power system. The inspectors reviewed the generic industry issue for
switchyard Open Phase Circuits, performed thermal monitoring checks of the offsite
power supply systems, reviewed draft design changes for the open phase issue, and
interviewed appropriate plant personnel to assess deficiencies and plant readiness for
summer high grid loading. Documents reviewed are listed in the Attachment. The
6
inspectors completed one Summer Readiness of Offsite and Alternate AC Power
Systems sample as defined in Inspection Procedure 71111.01.
b. Findings
No findings were identified.
1R04 Equipment Alignment (71111.04)
Partial System Walkdown
a. Inspection Scope
The inspectors performed partial walkdowns of the following three systems to verify the
operability of redundant or diverse trains and components when safety equipment was
inoperable. The inspectors focused on identification of discrepancies that could impact
the function of the system and, therefore, potentially increase risk. The inspectors
reviewed applicable operating procedures, walked down control system components,
and determined whether selected breakers, valves, and support equipment were in the
correct position to support system operation. 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 corrective action program (CAP). Documents reviewed are listed
in the Attachment. The inspectors completed three Equipment Alignment Partial
Walkdown samples as defined in Inspection Procedure 71111.04.
- Unit and shutdown boards with a focus on general design criteria (GDC) 17 and auto
transfer functions
- Unit 2 Core Spray system
- Unit 2 Reactor Water Cleanup system
b. Findings
No findings were identified.
1R05 Fire Protection (71111.05)
.1 Fire Protection Tours
a. Inspection Scope
The inspectors reviewed licensee procedures for transient combustibles and fire
protection impairments, and conducted a walkdown of the fire areas (FA) and fire zones
(FZ) listed below. Selected FAs/FZs were examined in order to verify licensee control of
transient combustibles and ignition sources; the material condition of fire protection
equipment and fire barriers; and operational lineup and operational condition of fire
protection features or measures. The inspectors verified that selected fire protection
impairments were identified and controlled in accordance with procedures. The
inspectors reviewed applicable portions of the Fire Protection Report, Volumes 1 and 2,
including the applicable Fire Hazards Analysis, and Pre-Fire Plan drawings, to verify that
the necessary firefighting equipment, such as fire extinguishers, hose stations, ladders,
7
and communications equipment, was in place. Documents reviewed are listed in the
attachment. This activity constituted five Fire Protection Walkdown inspection samples,
as defined in Inspection Procedure 71111.05.
- Fire Zone 1-6, Unit 1 Reactor Building, Elevation 639 south of column line R
- Fire Zone 25-2, Residual Heat Removal Service Water (RHRSW) pump room A
- Fire Zone 25-3, Residual Heat Removal Service Water (RHRSW) pump room C
- Fire Zone 2-6, Unit 2 Reactor Building, Elevation 639 south of column line R
- Fire Zone 3-4, Unit 3 Reactor Building, Elevation 621 and 639 north of column R
b. Findings
No findings were identified.
.2 Annual Drill Observations
a. Inspection Scope
On May 05,2016, the inspectors observed an unannounced fire drill in the Unit common
Control building, 593 elevation in the Communications Board room. The inspectors
assessed fire alarm effectiveness; response time for notifying and assembling the fire
brigade; the selection, placement, and use of firefighting equipment; use of personnel
fire protective clothing and equipment (e.g., turnout gear, self-contained breathing
apparatus); communications; incident command and control; teamwork; and firefighting
strategies. The inspectors also attended the post-drill critique to assess the licensees
ability to review fire brigade performance and identify areas for improvement. Following
the critique, the inspectors compared their findings with the licensees observations and
to the requirements specified in the licensees Fire Protection report. This activity
constituted one Annual Drill Observation inspection sample as defined in Inspection
Procedure 71111.05.
b. Findings
No findings were identified.
1R06 Flood Protection Measures (71111.06)
a. Inspection Scope
The inspectors reviewed two internal flood protection measures samples for the Unit 2
Reactor Water Cleanup rooms and the Diesel Generator Building internal flood design to
verify that flood mitigation plans were consistent with the design requirements and risk
analysis assumptions and that equipment essential for reactor shutdown was properly
protected from a flood caused by pipe breaks in the rooms/building. Specifically, the
inspectors reviewed the licensees moderate energy line break flooding study to fully
understand the licensees flood mitigation strategy, reviewed licensee drawings and then
verified that the assumptions and results remained valid. The inspectors walked down
the areas to verify the assumed flooding sources, adequacy of common area drainage,
and flood detection instrumentation to ensure that a flooding event would not impact
8
reactor shutdown capabilities. Documents reviewed are listed in the Attachment. The
inspectors completed two Internal Flooding samples as defined in Inspection Procedure
b. Findings
No findings were identified.
1R11 Licensed Operator Requalification and Performance (71111.11)
.1 Licensed Operator Requalification
a. Inspection Scope
On April 12, 2016, the inspectors observed a licensed operator training session for an
operating crew according to the Unit 2 Simulator Exercise Guide (SEG) OPL173S414,
Fire Safe Shutdown Procedures, Revision 1 and SEG OPL 173S060 Security Event
Response and Control Room Abandonment, Rev 16.
The inspectors specifically evaluated the following attributes related to the operating
crews performance:
- Clarity and formality of communication
- Ability to take timely action to safely control the unit
- Prioritization, interpretation, and verification of alarms
- Correct use and implementation of procedures including Abnormal Operating
Instructions, Emergency Operating Instructions and Safe Shutdown Instructions
- Timely control board operation and manipulation, including high-risk operator actions
- Timely oversight and direction provided by the shift supervisor, including ability to
identify and implement appropriate technical specifications actions such as reporting
and emergency plan actions and notifications
- Group dynamics involved in crew performance
The inspectors assessed the licensees ability to assess the performance of their
licensed operators. The inspectors reviewed the post-examination critique performed by
the licensee evaluators, and verified that licensee-identified issues were comparable to
issues identified by the inspector. The inspectors reviewed simulator physical fidelity
(i.e., the degree of similarity between the simulator and the reference plant control room,
such as physical location of panels, equipment, instruments, controls, labels, and related
form and function). Documents reviewed are listed in the attachment. This activity
constituted one Observation of Requalification Activity inspection sample as defined in
Inspection Procedure 71111.11.
b. Findings
No findings were identified.
9
.2 Control Room Observations
a. Inspection Scope
Inspectors observed and assessed licensed operator performance in the plant and main
control room, particularly during periods of heightened activity or risk and where the
activities could affect plant safety. Inspectors reviewed various licensee policies and
procedures covering Conduct of Operations, Plant Operations and Power Maneuvering.
Inspectors utilized activities such as post maintenance testing, surveillance testing and
other activities to focus on the following conduct of operations as appropriate;
- Operator compliance and use of procedures.
- Control board manipulations.
- Communication between crew members.
- Use and interpretation of plant instruments, indications and alarms.
- Use of human error prevention techniques.
- Documentation of activities, including initials and sign-offs in procedures.
- Supervision of activities, including risk and reactivity management.
- Pre-job briefs.
This activity constituted one Control Room Observation inspection sample as defined in
Inspection Procedure 71111.11.
b. Findings
No findings were identified.
1R12 Maintenance Effectiveness (71111.12)
.1 Routine
a. Inspection Scope
The inspectors reviewed the specific structures, systems and components (SSC) within
the scope of the Maintenance Rule (MR) (10CFR50.65) with regard to some or all of the
following attributes, as applicable: (1) Appropriate work practices; (2) Identifying and
addressing common cause failures; (3) Scoping in accordance with 10 CFR 50.65(b) of
the MR; (4) Characterizing reliability issues for performance monitoring; (5) Tracking
unavailability for performance monitoring; (6) Balancing reliability and unavailability; (7)
Trending key parameters for condition monitoring; (8) System classification and
reclassification in accordance with 10 CFR 50.65(a)(1) or (a)(2); (9) Appropriateness of
performance criteria in accordance with 10 CFR 50.65(a)(2); and (10) Appropriateness
and adequacy of 10 CFR 50.65 (a)(1) goals, monitoring and corrective actions. The
inspectors compared the licensees performance against site procedures. The
inspectors reviewed, as applicable, work orders, surveillance records, problem
evaluation reports (PERs), system health reports, engineering evaluations, and MR
expert panel minutes; and attended MR expert panel meetings to verify that regulatory
and procedural requirements were met. Documents reviewed are listed in the
10
attachment. This activity constituted four Maintenance Effectiveness inspection samples
as defined in Inspection Procedure 71111.12.
/ Alternate Rod Insertion (ARI) trips and reliability improvement plan
- Maintenance Rule accounting of Unit 3 Recirculation pump start failures on 3-20-16
due to improper discharge valve LS-3 setting.
- Component Class GE CR 105 Contactors
- Unit 3 Core Spray System and Room Coolers
b. Findings
No findings were identified.
1R13 Maintenance Risk Assessments and Emergent Work Evaluation (71111.13)
a. Inspection Scope
For planned online work and/or emergent work that affected the combinations of risk
significant systems listed below, the inspectors examined on-line maintenance risk
assessments, and actions taken to plan and/or control work activities to effectively
manage and minimize risk. The inspectors verified that risk assessments and applicable
risk management actions (RMA) were conducted as required by 10 CFR 50.65(a)(4)
applicable plant procedures. As applicable, the inspectors verified the actual in-plant
configurations to ensure accuracy of the licensees risk assessments and adequacy of
RMA implementations. Documents reviewed are listed in the attachment. This activity
constituted six Maintenance Risk Assessment inspection samples as defined in
Inspection Procedure 71111.13.
- Unit 3 Automatic Depressurization System valve 3-PCV-1-22 out of service
- Tornado Watch on April 1, 2016
- Shutdown Bus 2 on alternate feed and B emergency desiel generator (EDG) out of
service. April 25-29, 2016
- Unit 3 Yellow Risk due to residual heat removal (RHR) Loop II out of service
- Units 1 and 2 Yellow risk due to D1 residual heat removal service water (RHRSW)
pump out of service, 1 of 2 battery chargers out of service for 'C' DG, Shutdown Bus
2 on alternate feed, and non-functional 3EC / C desiel generator (DG) crosstie
capability
- Unit 3 Yellow Risk due to Main Bank 3 battery out of service
b. Findings
No findings were identified.
1R15 Operability Determinations and Functionality Assessment (71111.15)
a. Inspection Scope
The inspectors reviewed the operability/functional evaluations listed below to verify
technical adequacy and ensure that the licensee had adequately assessed technical
11
specification (TS) operability. The inspectors reviewed applicable sections of the
Updated Final Safety Analysis Report (UFSAR) to verify that the system or component
remained available to perform its intended function. In addition, where appropriate, the
inspectors reviewed licensee procedures to ensure that the licensees evaluation met
procedure requirements. Where applicable, inspectors examined the implementation of
compensatory measures to verify that they achieved the intended purpose and that the
measures were adequately controlled. The inspectors reviewed PERs on a daily basis
to verify that the licensee was identifying and correcting any deficiencies associated with
operability evaluations. Documents reviewed are listed in the attachment. This activity
constituted six Operability Evaluation inspection samples as defined in Inspection
Procedure 71111.15.
- High Pressure Fire Protection System break discrepant minimum wall thickness
calculations (CR 1178002)
- Automatic bus transfer of Unit Board 1B to Start Bus 1B was not blocked while
Shutdown Bus 2 was supplied by Unit Board 1B (CR 1165168)
- Loss of voltage regulator supplying Unit Station Service Transformer 3B Load Tap
Changer (CR 1163822)
- Unit 3 Jet Pump number 12 flow indication elevated and outside of surveillance 3-
3.4.2.1 curve (CR 1182784)
b. Findings
No findings were identified.
1R18 Plant Modifications (71111.18)
Permanent Plant Modifications
a. Inspection Scope
The inspectors verified that the plant modification listed below did not affect the safety
functions of important safety systems. The inspectors confirmed the modifications did
not degrade the design bases, licensing bases, and performance capability of risk
significant structures, systems and components. The inspectors also verified
modifications performed during plant configurations involving increased risk did not place
the plant in an unsafe condition. Additionally, the inspectors evaluated whether system
operability and availability, configuration control, post-installation test activities, and
changes to documents, such as drawings, procedures, and operator training materials,
complied with licensee standards and NRC requirements. In addition, the inspectors
reviewed a sample of related corrective action documents to verify the licensee was
identifying and correcting any deficiencies associated with modifications. Documents
reviewed are listed in the attachment. This activity constituted one Plant Modification
sample as defined in Inspection Procedure 71111.18.
- DCN 66071, 4kV and 480V Load Restrictions
12
b. Findings
No findings were identified.
1R19 Post Maintenance Testing (71111.19)
a. Inspection Scope
The inspectors witnessed and reviewed post-maintenance tests (PMT) listed below to
verify that procedures and test activities confirmed SSC operability and functional
capability following the described maintenance. The inspectors reviewed the licensees
completed test procedures to ensure any of the SSC safety function(s) that may have
been affected were adequately tested, that the acceptance criteria were consistent with
information in the applicable licensing basis and/or design basis documents. The
inspectors witnessed and/or reviewed the test data, to verify that test results adequately
demonstrated restoration of the affected safety function(s). The inspectors verified that
problems associated with PMTs were identified and entered into the CAP. Documents
reviewed are listed in the attachment. This activity constituted two Post Maintenance
Test inspection samples samples as defined in Inspection Procedure 71111.19.
- Unit 3 Recirculation Pump start failures CR 1151665
- Post maintenance test of the D EDG; WO117886451
b. Findings
Introduction. A self-revealing Green finding was identified for the licensees failure to
provide adequate work instructions for performing maintenance on the discharge
valves for 3A and 3B Recirculation Pump motors.
Description. On March 20, 2016 the licensee replaced the Unit 3, A and B, recirculation
pump discharge valve motors. The work instructions referenced drawing 3-47A370-68-
10 to set the valve limit switches in conjunction with the motor replacement.
On March 20, 2016 the licensee commenced the hydrostatic test of the RCS. System
temperature was approximately 157 degrees. Time to reactor core boiling was just over
2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. Shutdown cooling was operating on the opposite train. Two attempts were
made to start the 3B Recirculation pump to support the test. Each time the pump tripped
without an obvious indication or cause.
At 1:00 a.m. on March 21, 2016, the operators secured Loop II of shutdown cooling to
allow use of the 3A recirculation pump to perform the hydostatic testing. Unit 3 entered
TS 3.4.8.B, RHR Shutdown Cooling System - Cold Shutdown, for not having any
shutdown cooling in service. The licensees intention was to perform the testing and
restore RCS core flow within the one hour TS allowed outage time. At 1:10 a.m. the 3A
Recirculation pump was started and then immediately tripped. Loop II of shutdown
cooling was restored at 1:19 a.m.
For a total of 19 minutes the Unit 3 reactor had no operating core flow. RCS
temperature did not increase significantly and did not result in a mode change due to the
relatively low decay heat and quick response by the operators.
13
The licensee discovered drawing 3-47A370-68-10 had erroneous information for setting
the valve limit switches. This resulted in a time delay trip signal being generated to trip
the associated Recirculation pump Variable Frequency Drive (VFD) upon pump start and
discharge valve opening. Following discovery that the drawing 3-47A370-68-10 error
had resulted in an incorrect limit switch setting, a work order was created and performed
to set the limit switches to the proper settings. This restored the pump start design
features.
Station Procedure NPG-SPP-06.3 covered PMT requirements. Steps 3.2.2.3 and
3.2.3.A.1 required that plant operability requirements be considered in determining a
required PMT. Also the procedure cautioned that a Surveillance Instruction may not be
sufficient and that a supplemental PMT may be required in order to test all components
or features affected by the activity. Procedure NPG - SPP 06.9.3, Post Modification
Testing step 2.0.D stated that modification tests must cover other functions and
operations of the systems to ensure that they have not been affected by the repair.
Following completion of the maintenance, no supplemental post maintenance testing
beyond the normal valve stroke surveillances was performed. The normal valve stroke
surveillances did not verify that the limit switch settings would permit recirculation pump
starts and operation.
Analysis. The failure to provide adequate work instructions for maintenance on the Unit
3 recirculation pump discharge valve motors which included appropriate testing as
described in Procedure NPG - SPP 06.9.3 Post Modification Testing, was a
performance deficiency. The performance deficiency was more than minor because it
affected the equipment performance attribute of the Initiating Events Cornerstone and
adversely affected the cornerstone objective to limit the likelihood of events that upset
plant stability and challenge critical safety functions during shutdown operations.
Specifically, two trains of equipment which provide for maintaining flow through the
core during shutdown operations were unintentionally rendered inoperable. The
inspector performed the initial significance determination using NRC Inspection Manual
Chapter 0609, Appendix G, Attachment 3, Shutdown Operations Significance
Determination Process Phase 1 Initial Screening and Characterization of Findings.
The inspectors determined, per Attachment 3, that the finding was of very low safety
significance because (1) RCS time to boil was longer than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and potential to
reach RHR shutoff head was greater than 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />; (2) two diverse trains of RHR
Shutdown cooling, low pressure Core Spray and Control Rod drive pumps were all
available; (3) full credit was given for operator actions as they were actually
demonstrated and all support equipment was available; and (4) containment venting
was always available as the drywell hatch was open for the testing. The licensee
initiated CRs 1151665 and 1151935 to address the inadequate post maintenance work
instructions that resulted in the unexpected trip of the 3A and 3B Recirculation pumps.
This finding had a human performance cross-cutting aspect because the licensee did
not ensure that design documentation was correct and that work packages provided
the proper tests to ensure a functional VFD / Recirculation pump trip logic. [H.7,
Documentation].
Enforcement: This finding does not involve enforcement action because no violation of a
regulatory requirement was identified. Because this finding does not involve a violation
and is of very low safety significance, it is identified as a FIN (FIN 05000296/2016002-
01, Failure to Provide Adequate Maintenance Work Instructions Results in Loss of Core
Flow While Shutdown)
14
1R22 Surveillance Testing (71111.22)
a. Inspection Scope
The inspectors witnessed portions of, and/or reviewed completed test data for the
following surveillance tests of risk-significant and/or safety-related systems to verify that
the tests met technical specification surveillance requirements, UFSAR commitments,
and in-service testing and licensee procedure requirements. The inspectors review
confirmed whether the testing effectively demonstrated that the SSCs were operationally
capable of performing their intended safety functions and fulfilled the intent of the
associated surveillance requirement. Documents reviewed are listed in the attachment.
This activity constituted six Surveillance Testing inspection samples: four routine test,
and two in-service tests as defined in Inspection Procedure 71111.22.
Routine Surveillance Tests:
- 3-SI-4.4.A.1, Unit 3 Standby Liquid Control Pump Functional Test
- Inspection of normally inaccessible 1C RHR heat exchanger service water side for
fouling per licensee procedure NPG-SPP-09.14
- 2-SR-3.5.1.6(CS II), Unit 2 Core Spray Flow Rate Loop II
- 3-SR-3.8.1.7(3C), Diesel Generator 3C 24 Hour Run
In-service Tests:
- 1-SR-3.5.3.3, Reactor Core Isolation Cooling (RCIC) System Rated Flow at Normal
Operating Pressure
b. Findings
No findings were identified.
Cornerstone: Emergency Preparedness (EP)
1EP2 Alert and Notification System Evaluation
a. Inspection Scope
The inspectors evaluated the adequacy of the licensees methods for testing and
maintaining the alert and notification system in accordance with NRC Inspection
Procedure 71114, Attachment 02, Alert and Notification System Evaluation. The
applicable planning standard, 10 CFR Part 50.47(b)(5), and its related 10 CFR Part 50,
Appendix E requirements were used as reference criteria. The criteria contained in
NUREG-0654, Criteria for Preparation and Evaluation of Radiological Emergency
Response Plans and Preparedness in Support of Nuclear Power Plants, Revision 1,
were also used as a reference.
The inspectors reviewed various documents which are listed in the Attachment and
interviewed personnel responsible for system performance, siren maintenance, and
siren testing. This inspection activity satisfied one inspection sample for the alert and
notification system on a biennial basis as defined in Inspection Procedure 71114.02.
15
b. Findings
No findings were identified.
1EP3 Emergency Response Organization Staffing and Augmentation System
a. Inspection Scope
The inspectors reviewed the licensees Emergency Response Organization (ERO)
augmentation staffing requirements and process for notifying the ERO to ensure the
readiness of key staff for responding to an event and timely facility activation. The
qualification records of key position ERO personnel were reviewed to ensure all ERO
qualifications were current. A sample of problems identified from augmentation drills or
system tests performed since the last inspection was reviewed to assess the
effectiveness of corrective actions.
The inspection was conducted in accordance with NRC Inspection Procedure 71114,
Attachment 03, Emergency Response Organization Staffing and Augmentation System.
The applicable planning standard, 10 CFR 50.47(b)(2), and its related 10 CFR 50,
Appendix E requirements were used as reference criteria.
The inspectors reviewed various documents which are listed in the Attachment. This
inspection activity satisfied one inspection sample for the ERO staffing and
augmentation system on a biennial basis as defined in Inspection Procedure 71114.03.
b. Findings
No findings were identified.
1EP4 Emergency Action Level and Emergency Plan Changes
a. Inspection Scope
Since the last NRC inspection of this program area, two changes were made to the
Radiological Emergency Plan and one change was made to the Emergency Action
Levels, along with changes to several implementing procedures. The licensee
determined that, in accordance with 10 CFR 50.54(q), the Plan continued to meet the
requirements of 10 CFR 50.47(b) and Appendix E to 10 CFR Part 50. The inspectors
reviewed these changes to evaluate for potential reductions in the effectiveness of the
Plan. However, this review was not documented in a Safety Evaluation Report and does
not constitute formal NRC approval of the changes. Therefore, these changes remain
subject to future NRC inspection in their entirety.
The inspection was conducted in accordance with NRC Inspection Procedure 71114,
Attachment 04, Emergency Action Level and Emergency Plan Changes. The applicable
planning standards of 10 CFR 50.47(b), and its related requirements in 10 CFR 50,
Appendix E were used as reference criteria.
The inspectors reviewed various documents that are listed in the Attachment to this
report. This inspection activity satisfied one inspection sample for the emergency action
16
level and emergency plan changes on an annual basis as defined in Inspection
Procedure 71114.04.
b. Findings
No findings were identified.
1EP5 Maintenance of Emergency Preparedness
a. Inspection Scope
The inspectors reviewed the corrective actions identified through the Emergency
Preparedness program to determine the significance of the issues, the completeness
and effectiveness of corrective actions, and to determine if issues were recurring. The
licensees post-event after action reports, self-assessments, and audits were reviewed to
assess the licensees ability to be self-critical, thus avoiding complacency and
degradation of their emergency preparedness program. Inspectors reviewed the
licensees 10 CFR 50.54(q) change process, personnel training, and selected
screenings and evaluations to assess adequacy. The inspectors toured facilities and
reviewed equipment and facility maintenance records to assess licensees adequacy in
maintaining them. The inspectors evaluated the capabilities of selected radiation
monitoring instrumentation to adequately support Emergency Action Level (EAL)
declarations.
The inspection was conducted in accordance with NRC Inspection Procedure 71114,
Attachment 05, Maintenance of Emergency Preparedness. The applicable planning
standards, related 10 CFR 50, Appendix E requirements, and 10 CFR 50.54(q) and (t)
were used as reference criteria.
The inspectors reviewed various documents which are listed in the Attachment. This
inspection activity satisfied one inspection sample for the maintenance of emergency
preparedness on a biennial basis as defined in Inspection Procedure 71114.05.
b. Findings
Introduction: The inspectors identified a Green non-cited violation (NCV) of 10 CFR
50.54(q)(2), for the licensees failure to declare a Notification of Unusual Event (NOUE)
within 15 minutes of entry conditions being met. Specifically, on April 6, 2016, at 3:05
pm, Browns Ferry Unit 3 main control room (MCR) operators received a high-high
radiation alarm on the main steam lines (MSL) that met Emergency Action Level (EAL)
1.4-U for declaring a NOUE.
Description: At 3:05 pm on April 6, 2016, the Browns Ferry Unit 3 MCR received a high-
high alarm on MSL Radiation Monitor 3-RA-90-135C. At 3:26 pm, the MCR operators
reduced power to 91% in accordance with (IAW) their annunciator response procedure.
The power reduction reduced the radiation levels from above 1700 mR/hr to
approximately 1200 mR/hr, which cleared the alarm. The licensee subsequently
investigated the cause of the MSL high radiation alarm and determined that it was
attributed to an oil leak from the 3B reactor feed pump that made its way into the pumps
seal water lines. The licensee also determined that the oil coated the condensate
17
demineralizers which caused a chemical reaction that resulted in the production of
elevated levels of radioactive isotopes Nitrogen-13 and Nitrogen-16.
The annunciator response procedure lists the alarm for the MSL high-high as 3-times
(3X) background, but there was not an efficient mechanism for the control room staff to
verify the set-point and confirm the alarm conditions. The licensees Emergency Plan
Implementing Procedure (EPIP)-1, Emergency Classification Procedure Event
Classification Matrix, Section 3.1 [3] states, in part: if alarms are indeterminate and
the existence cannot be reasonably discounted, the condition is considered authentic
and the Shift Emergency Director (SED) should follow the indications provided.
Contrary to the above, since the initial indications were met at 3:05 pm, the SED should
have declared the NOUE prior to 3:20 pm. It was not until the senior resident inspector
challenged the operators that the licensee decided to investigate further and concluded,
several days after the event, that the operators indeed should have declared a NOUE.
Analysis: The failure to declare a NOUE when an EAL entry criteria had been met as
described in Emergency Plan Implementing Procedure (EPIP)-1, was considered a
performance deficiency. This finding is more than minor because it was associated with
the Emergency Preparedness cornerstone attribute of Emergency Response
Organization Performance, and adversely affected the cornerstone objective of ensuring
that a licensee is capable of implementing adequate measures to protect the health and
safety of the public in the event of a radiological emergency. Specifically, on April 6,
2016, personnel did not declare a NOUE within 15 minutes of initial indications that EAL
1.4-U had been exceeded. The performance deficiency is associated with the
Emergency Classification Planning Standard and is considered a Risk Significant
Planning Standard (RSPS). The failure to declare a NOUE when directed by the EAL
Matrix is considered a lost or degraded RSPS in accordance with Section 4 of Inspection
Manual Chapter (IMC) 0609, Appendix B. Section 4.3.e of IMC 0609, Appendix B,
provides the significance determination for a Failure to Implement, and the
performance deficiency was determined to be of very low safety significance (Green).
The finding was associated with a cross-cutting aspect in the Procedure Adherence
component of the Human Performance area because individuals did not follow
processes, procedures and work instructions that would have led them to declare in a
timely manner [H.8].
Enforcement: Title 10 CFR 50.54(q)(2) requires that a holder of a nuclear power reactor
operating license under this part, shall follow and maintain the effectiveness of an
emergency plan that meets the requirements of 10 CFR 50.47(b). Title 10 CFR 50.47(b)(4) requires a standard emergency classification and action level scheme, the
bases of which include facility system and effluent parameters, is in use by the nuclear
facility licensee, and state and local response plans call for reliance on information
provided by facility licensees for determinations of minimum initial offsite response
measures. Contrary to the above, on April 6, 2016, the licensee failed to implement an
emergency plan that met the standards in Title 10 CFR 50.47(b)(4) when they did not
declare a NOUE within 15 minutes as described by their EAL scheme. Specifically, the
licensee failed to declare a NOUE when conditions were met. Corrective actions
included entering the issue into their CAP as CR 1159943, formally evaluating the
decision-making process used during the event, and clarifying responsibilities for
Declaration, Classification and Notification. Because this violation was of very low safety
significance and was entered into the CAP, this violation is being treated as an NCV
18
consistent with Section 2.3.2.a of the NRC Enforcement Policy. (NCV 05000296/2016002-02, Failure to Declare Notification of Unusual Event)
1EP6 Drill Evaluation (IP 71114.06)
a. Inspection Scope
The inspectors observed an Emergency Planning (EP) Radiological Emergency Plan
(REP) training drill that contributed to the licensees Drill/Exercise Performance (DEP)
and ERO performance indicator (PI) measures on May 11, 2016. This drill was intended
to identify any licensee weaknesses and deficiencies in classification, notification, dose
assessment and protective action recommendation (PAR) development activities. The
inspectors observed emergency response operations in the Simulated Control Room
and the Technical Support Center, to verify that event classification and notifications
were done in accordance with EPIP-1, Emergency Classification Procedure, and
licensee conformance with other applicable Emergency Plan Implementing Procedures.
The inspectors attended the post-drill critiques to compare any inspector-observed
weaknesses with those identified by the licensee in order to verify whether the licensee
was properly identifying EP related issues and entering them in to the CAP, as
appropriate. Documents reviewed are listed in the attachment. This activity constituted
one Drill Evaluation sample as defined in Inspection Procedure 71114.06.
b. Findings
No findings were identified.
2. RADIATION SAFETY
2RS6 Radioactive Gaseous and Liquid Effluent Treatment (IP 71124.06)
a. Inspection Scope:
Radioactive Effluent Processing Systems The inspectors walked-down selected
components of the gaseous and liquid radioactive waste (radwaste) processing and
effluent discharge systems. To the extent practical, the inspectors observed and
evaluated the material condition of in-place waste processing equipment for indications
of degradation or leakage that could constitute a possible release pathway to the
environment. Inspected components included floor drain tanks, waste monitor tanks,
radiation monitoring systems, and associated piping and valves. The inspectors
interviewed licensee staff regarding equipment configuration and effluent monitor
operation. The inspectors also walked down and reviewed surveillance test records for
three trains of standby-gas treatment filters.
Effluent Monitoring and Discharge The inspectors observed the collection and
processing of gaseous effluent samples from the Main Stack system. Technician
proficiency in collecting, processing, and preparing the applicable release permits was
evaluated. The inspectors reviewed recent liquid and gaseous release permits including
pre-release sampling results, effluent monitor alarm setpoints, and public dose
calculations. For the Main Stack Wide-Range Noble Gas Monitor and the Unit 1 Plant
Vent Exhaust Radiation Monitor, the inspectors reviewed calibration and functional test
records and evaluated traceability of radioactive calibration sources to National Institute
19
of Standards and Technology (NIST) standards. The inspectors also evaluated the
licensees capability to collect high-range post-accident effluent samples from these
monitoring systems. The inspectors reviewed and discussed with licensee staff the
methodology for determining vent and stack flow rates and compared current vent flows
to design values in the Offsite Dose Calculation Manual (ODCM).
The inspectors reviewed the 2014 and 2015 Annual Radioactive Effluent Release
Reports to evaluate reported doses to the public, review any anomalous events, and
review ODCM changes. The inspectors also reviewed compensatory sampling data for
time periods when selected radiation monitors were out of service. The inspectors
reviewed the results of interlaboratory cross-checks for laboratory instruments used to
analyze effluent samples. The inspectors also reviewed licensee effluent source term
characterizations and changes to effluent release points. In addition, the inspectors
evaluated recent land use census results
Problem Identification and Resolution The inspectors reviewed and discussed selected
Corrective Action Program (CAP) documents associated with gaseous and liquid effluent
processing and release activities. The inspectors evaluated the licensees ability to
identify and resolve the issues. The inspectors also reviewed recent self-assessment
results.
Inspection Criteria Radwaste system operation and effluent processing activities were
evaluated against requirements and guidance documented in the following: 10 CFR Part
20; 10 CFR Part 50 Appendix I; Technical Specifications (TS) Section 5; ODCM;
Updated Final Safety Analysis Report (UFSAR) Section 9; Regulatory Guide (RG) 1.21,
Measuring, Evaluating, and Reporting Radioactivity in Solid Wastes and Releases of
Radioactive Materials in Liquid and Gaseous Effluents from Light-Water-Cooled Nuclear
Power Plants; RG 1.109, Calculation of Annual Doses to Man from Routine Releases
of Reactor Effluents for the Purpose of Evaluating Compliance with 10 CFR Part 50
Appendix I; and approved licensee procedures. Documents reviewed during the
inspection are listed in the report Attachment.
This inspectors completed the required six samples as defined in Inspection Procedure
b. Findings
No findings were identified.
2RS7 Radiological Environmental Monitoring Program (REMP) (IP 71124.07)
a. Inspection Scope
REMP Implementation The inspectors reviewed the 2015 and 2014 Annual
Environmental Operating Reports and the 2015 Annual Radioactive Effluent Release
Report. Selected environmental measurements were reviewed for consistency with
licensee effluent data, evaluated for radionuclide concentration trends, and compared
with detection level sensitivity requirements as described in the ODCM. The inspectors
assessed the licensees response to any missed or anomalous environmental samples.
The inspectors also reviewed the results of interlaboratory cross-checks for laboratory
20
instruments used to analyze environmental samples. Any changes to the ODCM, Land
Use Census, or environmental program processes were discussed with licensee staff.
The inspectors observed routine collection of airborne particulate and iodine samples at
selected locations as required by the licensees ODCM. The inspectors noted the
material condition of the continuous air samplers and environmental dosimeters. The
inspectors also reviewed calibration and maintenance records for the environmental
sampling equipment.
Meteorological Monitoring Program The inspectors observed the physical condition of
the meteorological tower and its instrumentation and discussed equipment operability
and maintenance history with licensee staff. The inspectors evaluated transmission of
locally generated meteorological data to other licensee groups such as emergency
operations personnel and main control room operators. Calibration records for the
meteorological measurements of wind speed, wind direction, and temperature were
reviewed. The inspectors also reviewed meteorological measurement data recovery for
2014 and 2015.
Ground Water Protection The inspectors reviewed the licensees continued
implementation of the industrys Ground Water Protection Initiative (Nuclear Energy
Institute (NEI) 07-07) and discussed any changes to the program. The inspectors
discussed program guidance for dealing with spills, leaks, and unexpected discharges
with licensee staff and reviewed recent monitoring well results and any voluntary
communications. The inspectors also reviewed recent entries into the 10 CFR 50.75(g)
decommissioning file. The inspectors reviewed and discussed the licensees program
for monitoring of structures, systems, and components with the potential to release
radioactive material to the environment. Potential effluent release points due to onsite
surface water bodies were also evaluated.
Problem Identification and Resolution The inspectors reviewed CAP documents in the
areas of radiological environmental monitoring, meteorological tower maintenance, and
groundwater protection. The inspectors evaluated the licensees ability to identify and
resolve the issues. The inspectors also reviewed recent self-assessment results.
Inspection Criteria The inspectors evaluated REMP implementation, meteorological
monitoring, and groundwater protection against the requirements and guidance
contained in: 10 CFR Part 20; Appendices E and I to 10 CFR Part 50; TS Section 5.0;
ODCM; UFSAR Chapter 2; RG 4.15, Quality Assurance for Radiological Monitoring
Programs (Normal Operation) - Effluent Streams and the Environment; Branch Technical
Position, An Acceptable Radiological Environmental Monitoring Program - 1979; RG
1.23, Meteorological Monitoring Programs for Nuclear Power Plants, Rev. 1; NEI 07-
07, Industry Groundwater Protection Initiative - Final Guidance Document; and
approved licensee procedures. Documents reviewed during the inspection are listed in
the report Attachment.
This inspectors completed the required three samples as defined in Inspection
Procedure 71124.07.
b. Findings
No findings were identified.
21
4. OTHER ACTIVITIES
4OA1 Performance Indicator (PI) Verification
.1 Cornerstone: Mitigating Systems
a. Inspection Scope
The inspectors reviewed the licensees procedures and methods for compiling and
reporting the following PIs. The inspectors examined the licensees PI data for the
specific PIs listed below for the second quarter of 2015 through the first quarter of 2016.
The inspectors reviewed the licensees data and graphical representations as reported
to the NRC to verify that the data was correctly reported. The inspectors validated this
data against relevant licensee records (e.g., CRs, Daily Operator Logs, Plan of the Day,
Licensee Event Reports, etc.), and assessed any reported problems regarding
implementation of the PI program. The inspectors verified that the PI data was
appropriately captured, calculated correctly, and discrepancies resolved. The inspectors
used the Nuclear Energy Institute (NEI) 99-02, Regulatory Assessment Performance
Indicator Guideline, to ensure that industry reporting guidelines were appropriately
applied. This activity constituted six PI inspection samples, as defined in Inspection
Procedure 71151.
- Unit 1, 2, and 3 Mitigating Systems Performance Index (MSPI) for High Pressure
Injection System (HPCI)
b. Findings
No findings were identified.
.2 Cornerstone: Emergency Preparedness
a. Inspection Scope
The inspectors sampled licensee submittals relative to the PIs listed below for the period
October 1, 2015, through March 31, 2016. To verify the accuracy of the PI data reported
during that period, PI definitions and guidance contained in NEI 99-02, Regulatory
Assessment Performance Indicator Guideline, Revision 7, was used to confirm the
reporting basis for each data element.
Emergency Preparedness Cornerstone
- Drill/Exercise Performance (DEP)
- Emergency Response Organization (ERO) Readiness
- Alert and Notification System (ANS) Reliability
For the specified review period, the inspectors examined data reported to the NRC,
procedural guidance for reporting PI information, and records used by the licensee to
identify potential PI occurrences. The inspectors verified the accuracy of the PI for ERO
drill and exercise performance through review of a sample of drill and event records.
22
The inspectors reviewed selected training records to verify the accuracy of the PI for
ERO drill participation for personnel assigned to key positions in the ERO. The
inspectors verified the accuracy of the PI for alert and notification system reliability
through review of a sample of the licensees records of periodic system tests. The
inspectors also interviewed the licensee personnel who were responsible for collecting
and evaluating the PI data. Licensee procedures, records, and other documents
reviewed within this inspection area are listed in the Attachment. This inspection
satisfied three inspection samples for PI verification on an annual basis as defined in
b. Findings
No findings were identified.
.3 Cornerstone: Public Radiation Safety
a. Inspection Scope
The inspectors reviewed the Radiological Control Effluent Release Occurrences PI
results for the Public Radiation Safety Cornerstone from May 2015 through May 2016.
For the assessment period, the inspectors reviewed cumulative and projected doses to
the public contained in liquid and gaseous release calculations and condition reports
related to Radiological Effluent Technical Specifications/ODCM issues. Documents
reviewed during the inspection are listed in the report Attachment. This inspection
satisfied one inspection sample for PI verification as defined in Inspection Procedure
71151.
b. Findings
No findings were identified.
4OA2 Problem Identification and Resolution of Problems (71152)
.1 Review of items entered into the Corrective Action Program:
a. Inspection Scope
As required by Inspection Procedure 71152, Identification and Resolution of Problems,
and in order to help identify repetitive equipment failures or specific human performance
issues for follow-up, the inspectors performed a daily screening of items entered into the
licensees CAP. This review was accomplished by reviewing daily CR reports, and
periodically attending Management Review Committee (MRC) and Plant Screening
Committee (PSC) meetings.
b. Findings
No findings were identified.
.2 Focused Annual Sample Review #1 - Potential Part 21 condition for Masterpact circuit
breakers failing to close:
23
a. Inspection Scope
The inspectors conducted a review of the status of the licensees analysis for a potential
Part 21 condition for Masterpact circuit breakers that have a continuous closed signal
applied. In circuits with a continuous closed signal applied when the breaker is closed, a
breaker anti-pump latch can become lodged against the close coil plunger. The purpose
of the anti-pump latch is to protect the breaker from excessive rapid opening and closing
from conflicting signals. With the anti-pump latch lodged in this fashion, the breaker may
fail to close when required. The inspectors verified that the licensee was evaluating
whether this potential Part 21 condition applied. Documents reviewed are listed in the
attachment. This activity constituted one focused annual inspection sample as defined
in IP 71152.
b. Findings
No findings were identified.
.3 Focused Annual Sample Review #2 - Control of contractor oversight for large projects
and refueling outage work:
a. Inspection Scope
The inspectors conducted a review of the licensee program and guidance related to
ensuring contractors work quality. Specifically, the inspectors reviewed the training,
planning and qualification requirements for the NFPA 0805, Refueling activities, Dry
Cask activities and MOV work activities. Guidance was contained in corporate
procedure NPG-SPP-07.7, NPG CTS Role and Oversight of Supplemental Personnel.
Documents reviewed are listed in the attachment. This activity constituted one focused
annual inspection sample as defined in IP 71152.
b. Findings
No findings were identified.
.4 Semi-annual Trend Review
a. Inspection Scope
As required by Inspection Procedure 71152, the inspectors performed a review of the
licensees CAP and other associated programs and 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 included licensee trending efforts
and licensee human performance results. The inspectors review nominally considered
the six-month period of January through June 2016. The inspectors reviewed licensee
trend reports and the Integrated Trend Reports from December 1, 2015, to June 1, 2016,
in order to determine the existence of any adverse trends that the licensee may not have
previously identified. This inspection constituted one Semi-annual Trend Review
inspection sample. Documents reviewed are listed in the Attachment.
24
b. Observations and Findings
The licensee had identified trends and appropriately addressed them in their CAP.
The inspectors observed that the licensee had performed a detailed review. The
licensee routinely reviewed cause codes, involved organizations, key words, and
system links to identify potential trends in their data. The inspectors compared the
licensee process results with the results of the inspectors daily screening. Trends
that have been identified by the inspectors and reported to the licensee were
appropriately entered into the licensees trending program.
Noteworthy Licensee identified trends included:
- Increasing onsite Tritium trend (CR 1138969)
- Trend in Radiation Protection posting errors (1162617)
- Adverse Trend in Reactor Feed Pump failures (1167376)
Noteworthy NRC identified degrading trends included:
- Seasonal readiness preparations not ensuring all necessary equipment operating
reliably for anticipated cold or hot weather
- Adverse trend in Control room and Shutdown Board room chillers failures
- Adverse trend in reporting component failures and events to the NRC
One violation was identified:
Failure to Report a Condition that Could Have Prevented Fulfillment of a Safety Function
Introduction: An NRC identified Severity Level IV NCV of 10 CFR 50.72(b)(3)(v) and 10
CFR 50.73(a)(2)(v) was identified for the licensee's failure to notify the NRC within 8
hours and submit a LER within 60 days of discovery of a condition that could have
prevented the fulfillment of a safety function. Specifically, the licensee failed to notify the
NRC that the High Pressure Coolant Injection (HPCI) system had been rendered
inoperable due to an equipment failure.
Description: On March 17, 2016 the licensee conducted planned maintenance on the
Unit 2 HPCI system to replace the valve packing material in the steam admission valve.
The maintenance required the system to be depressurized and be taken out of service,
which made the system inoperable. After the valve packing was installed, the licensee
performed diagnostic testing of the motor operated valve on March 18, which required
stroking of the valve. The diagnostic tests were completed satisfactorily and HPCI was
returned to service on March 19 at 7:38 a.m. A final operability surveillance stroke time
test per 2-SR-3.6.1.3.5(HPCI) was to be performed prior to declaring the system
operable. When operators attempted to perform the surveillance at 10:24 a.m., the
valve would not open. The inability of the valve to open would prevent steam from being
admitted to the HPCI turbine, which would have rendered the system inoperable.
Troubleshooting later revealed that the breaker thermal overloads had tripped and also
that a breaker contactor in the valve closing circuit had become hot enough to fuse its
contacts together, which prevented the valve from opening. The cause of the equipment
failure was determined to be due to excessive valve stroking during the earlier diagnostic
testing.
25
On March 22, 2015, the inspectors identified to the operations Shift Manager that the
valve failure met the three conditions listed in section 3.2.7 of NUREG-1022 which
described when an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and 60 day report per 10 CFR 50.72(b)(3)(v) and 10 CFR
50.73(a)(2)(v) are required. Specifically, the inspectors identified that the discovery of
the unexpected breaker failure was a condition that would have resulted in the single-
train HPCI system being declared inoperable. On March 24, CR 1153334 was
generated to evaluate the reportability of the condition; however, the licensees
evaluation incorrectly determined that the condition was not reportable.
Analysis: The inspectors determined the failure to notify the NRC within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and
submit a LER within 60 days of discovery of a condition that could have prevented the
fulfillment of a safety function, was a performance deficiency. Specifically, the licensee
failed to notify the NRC that the HPCI system had been rendered inoperable due to an
equipment failure. The licensees failure to provide the required notifications constitutes
a traditional enforcement violation because it impacts the NRC's ability to carry out its
regulatory function. The traditional enforcement violation was determined to be Severity
Level IV because it matched example 6.9.d.9 of the NRC Enforcement Policy. Because
the violation is a traditional enforcement violation, no cross-cutting aspect was assigned.
Enforcement: 10 CFR 50.72(b)(3)(v) and 10 CFR 50.73(a)(2)(v), require, in part, that
licensees shall notify the NRC within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and submit a LER within 60 days of
discovery of any event or condition that at the time of discovery could have prevented
the fulfillment of the safety function of structures or systems that are needed to: (A) Shut
down the reactor and maintain it in a safe shutdown condition; (B) Remove residual
heat; (C) Control the release of radioactive material; or (D) Mitigate the consequences of
an accident. Contrary to the above, the licensee failed to notify the NRC within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />
on March 19, 2016 and report by May 18, 2016 when they discovered the High Pressure
Coolant Injection (HPCI) system had been rendered inoperable due to an equipment
failure which met the reporting requirements of 10 CFR 50.72(b)(3)(v) and 10 CFR
50.73(a)(2)(v). As an immediate corrective action, the licensee entered the violation into
the licensee's corrective action program as CR 1185268. This violation is being treated
as an NCV consistent with Section 2.3.2 of the Enforcement Policy. (NCV 05000260/2016002-03, Failure to Report a Condition that Could Have Prevented
Fulfillment of a Safety Function)
4OA3 Follow-up of Events and Notices of Enforcement Discretion (71153)
.1 (Closed) Licensee Event Report (LER) 05000260/2015-002-01 High Pressure Coolant
Injection System Inoperable due to Manual Isolation of Steam Leak
a. Inspection Scope
The inspectors had previously inspected the September 16, 2015 manual isolation of the
Unit 2 High Pressure Coolant Injection (HPCI) system due to a leak on the steam
admission valve. This inspection is documented in the Browns Ferry Inspection Report
number 2016-01 (ML16134A224). This LER was a revision based on information
provided to and inspected by the NRC based on updated licensee analysis of this
incident. The inspectors reviewed this LER revision.
26
b. Findings
The enforcement aspects of this event are discussed in Browns Ferry Inspection Report
number 2016-01 (ML16134A224). No new violations were identified in this LER. This
LER is closed.
.2 (Closed) LER 050000296/2016-001-00 Inoperable Residual Heat Removal Pump Results
in Condition Prohibited by Technical Specifications and Safety System Functional Failure
a. Inspection Scope
On January 19, 2016 it was discovered that the 3A RHR pump motor breaker transfer
switch (MBTS) had malfunctioned which prevented the pump from being capable of
automatically initiating and also from being manually started from the main control room.
This loss of capability rendered the pump inoperable. An evaluation determined that the
pump was inoperable for approximately eleven days from January 9, 2016 until January
20, 2016, which exceeded the TS Required Action times of TS LCO 3.5.1. The capability
to start the pump manually from the local breaker was considered to be available during
this timeframe. The cause of the MBTS failure was binding in the ball detent and position
sprocket mechanism which prevented the switch from satisfactorily latching and making
good electrical contact while in the NORMAL position. The switch had been installed
greater than its twenty-one year service life and had no preventive maintenance
performed because the vendor manual guidance cautioned against the use of any
lubricants and/or cleaning agents in any form. During the time of the 3A RHR Pump
MBTS failure, the 3B and 3D RHR pumps were also inoperable for 48 minutes on
January 14, 2016, which resulted in a RHR Safety System Functional Failure.
b. Findings
No findings were identified. This LER is closed.
4OA5 Other Activities
.1 Operation of an Independent Spent Fuel Storage Installation (ISFSI) (IP 60855.1)
a. Inspection Scope
The inspectors reviewed changes made to the ISFSI programs and procedures, including
associated 10 CFR 72.48, Changes, Tests, and Experiments, screens and evaluations
to verify that changes made were consistent with the license or certificate of compliance.
The inspectors reviewed records to verify that the licensee recorded and maintained the
location of each fuel assembly placed in the ISFSI. The inspectors verified, by direct
observation that the licensee performed fuel cask loading in a safe manner and in
compliance with approved procedures. Documents reviewed are listed in the attachment.
This activity constituted one semi-annual Operation of an ISFSI inspection sample, as
defined in Inspection Procedure 60855.1.
b. Findings
No findings were identified.
27
.2 Failure to Meet the Deadline for Voluntary Reporting of Elevated Groundwater Tritium
a. Inspection Scope
During performance of Inspection Procedure 71124.07, Radiological Environmental
Monitoring Program (REMP), the inspectors noted that on April 26, 2016, the licensee
had detected elevated tritium levels of 36,444 pCi/L in groundwater monitoring well MW-
01. Per NEI 07-07, this result exceeded the voluntary reporting threshold of 20,000 pCi/L
for groundwater that is or could be used as drinking water. This sample result should
have triggered a voluntary report to State and Local officials by close-of-business on April
27, 2016. However, no report was made until June 20, 2016 (Event Number: 52025),
when groundwater well MW-08 also exceeded 20,000 pCi/L (22,400 pCi/L). This
represents a deviation from the industrys Groundwater Protection Initiative as described
by NEI 07-07, Objective 2.2, Voluntary Communication.
b. Findings
No findings were identified.
.3 Follow-up On Alternative Dispute Resolution Confirmatory Orders (IP 92702)
a. Inspection Scope
The NRC staff performed this follow up inspection in accordance with IP 92702 for
selected commitments in Confirmatory Order (ML14121A551) issued on May 1, 2014,
following an alternate dispute resolution (ADR) session on April 3, 2014, to disposition
two related traditional enforcement apparent violations; 1) Inaccurate Information
Provided Concerning Onsite Emergency Response Organization Staffing Requirements
and 2) Inappropriate Amendment of License.
The inspection objectives were to verify the licensees implementation of commitments
contained in the Order to provide assurance that (as appropriate):
- adequate corrective actions have been implemented for the traditional enforcement
violations;
- the root causes of these enforcement actions have been identified;
- that generic implications have been addressed;
- that the licensee's programs and practices have been appropriately enhanced to
prevent recurrence.
The following commitments were reviewed and closed:
- b.i.6 TVA will implement, via an independent entity, an effectiveness review of the
corrective actions completed to date with regard to the 10 CFR 50.9 and 10
CFR 50.90 Root Cause Analyses.
- b.ii.4 TVA will perform a detailed review of all procedures revised prior to August 15,
2014, during the Procedure Upgrade Project to ensure that the licensing basis
information required by the revised SPP-01.1 and SPP-01.2 is identified. This
review will include all licensing, administrative and governance procedures.
28
The revised procedures will institutionalize the licensing review process and
provide sustainability from that point forward in the Procedure Upgrade Project.
Operators regarding the scope and hierarchy of licensing basis documents,
lessons learned from circumstances associated with EA-14-005, and the
associated change process. The training material will be available for NRC
review
- b.ii.6 Through December 31, 2014, changes to BFN licensing commitments will be
reviewed and approved by a second site licensing engineer in addition to
review and approval by site licensing. The focus of this additional review will be
to ensure that the correct regulatory change process(es) has/have been used.
This action will be discontinued upon completion of the training encompassed
in item 5 above.
- b.ii.7 TVA will review a sample of facility changes, based on plant risk and
complexity, that have occurred from 2004 to May 2014, to determine whether
these changes have been appropriately incorporated into the licensing basis
documents. TVAs method of selecting facility changes to be sampled will be
provided to the NRC by July 15, 2014. Any identified discrepancies will be
dispositioned through the corrective action process. The results of this review
will be made available to the NRC.
complexity, accomplished within the last 3 years and processed outside of the
10 CFR 50.59 process to determine whether these changes have been
appropriately incorporated into the licensing basis documents. TVAs method of
selecting facility changes to be sampled will be provided to the NRC by July 15,
2014. Any identified discrepancies will be dispositioned through the corrective
action process. The results of this review will be made available to the NRC.
- b.ii.9 TVA will make a presentation to the 1) Regulatory Issue Working Group and 2)
the Regulating Utility Group regarding the circumstances of the violations
discussed above and the importance of leadership attention to the effective
management of the current licensing basis and complete and accurate
communications with the NRC. The presentation will be made available to the
NRC in advance.
The inspectors reviewed the licensees RCAs associated with the violations in
addition to other evaluations conducted in support of and as a result of the RCA.
The inspectors reviewed corrective actions that were taken and implemented to
address the identified causes. The inspectors verified that corrective actions
planned and implemented were appropriate to address the causes and prevent
recurrence and were consistent with the requirements of the Order.
b. Findings and Observations
No findings were identified.
29
4OA6 Meetings, Including Exit
.1 Exit Meeting Summary
On July 15, 2016, the resident inspectors presented the quarterly inspection results to Mr.
Kevin Bronson, Sr. Site Vice President, and other members of the licensees staff, who
acknowledged the findings. The inspectors verified that all proprietary information was
returned to the licensee.
ATTACHMENT: SUPPLEMENTAL INFORMATION
SUPPLEMENTAL INFORMATION
KEY POINTS OF CONTACT
Licensee
S. Bono, Site Vice President
L. Hughes, General Plant Manager
J. Paul, Nuclear Site Licensing Manager
M. McAndrew, Manager of Operations
L. Slizewski, Superintendent of Operations
M. Kirschenheiter, Assistant Director for Site Engineering
B. L. McCoy, Spent Fuel Storage Program Manager
M. Oliver, Licensing Engineer
E. Bates, Licensing Engineer
D. Drummonds, Program Engineer
L. Crutcher, Component Engineer
M. Lawson, Radiation Protection Manager
J. Smith, System Engineer
P. Campbell, System Engineer
J. Kulisek, EP Manager
K. Skinner, System Engineer
L. Holland, System Engineer
D. Jackson, System Engineer
D. Ford, System Engineer
J. Addison, Manager of Drills and Exercises
M. Clark, Emergency Preparedness Specialist
J. Garner, Site Licensing
W. Lee, Corporate Emergency Preparedness Director
J. Parshall, EP Program Planning and Implementation Manager
T. Scott, Site Quality Assurance Manager
P. Summers, Plant Support Director
S. Taubuki, Emergency Preparedness Specialist
B. Tidwell, Emergency Preparedness Manager
C. Vaughn, Operations Training Manager
C. Hensley, Chemistry Manager
B. Calkin, Site Licensing
Attachment
LIST OF ITEMS OPENED, CLOSED AND DISCUSSED
Opened and Closed
05000296/2016002-01 FIN Failure to Provide Adequate Maintenance
Results in Loss of Core Flow While
Shutdown (Section 1R19)05000296/2016002-02 NCV Failure to Declare Notification of Unusual
Event (1EP5)05000260/2016002-03 NCV Failure to Report a Condition that Could
Have Prevented Fulfillment of a Safety
Function (Section 4OA2.4)
Closed
05000260/2015-002-01 LER High Pressure Coolant Injection System
Inoperable due to Manual Isolation of Steam
Leak (Section 4OA3.1)
05000296/2016-001-00 LER Inoperable Residual Heat Removal Pump
Results in Condition Prohibited by Technical
Specifications and Safety System
Functional Failure (Section 4OA3.2)
05000259, 260, 296- 00 ORD 05/01/2014 Confirmatory Order Action b.i.6
(Section 4OA5.3)
05000259, 260, 296- 00 ORD 05/01/2014 Confirmatory Order Action b.ii.4
(Section 4OA5.3)
05000259, 260, 296- 00 ORD 05/01/2014 Confirmatory Order Action b.ii.5
(Section 4OA5.3)
05000259, 260, 296- 00 ORD 05/01/2014 Confirmatory Order Action b.ii.6
(Section 4OA5.3)
05000259, 260, 296- 00 ORD 05/01/2014 Confirmatory Order Action b.ii.7
(Section 4OA5.3)
05000259, 260, 296- 00 ORD 05/01/2014 Confirmatory Order Action b.ii.8
(Section 4OA5.3)
05000259, 260, 296- 00 ORD 05/01/2014 Confirmatory Order Action b.ii.9
(Section 4OA5.3)
LIST OF DOCUMENTS REVIEWED
Section 1R01: Adverse Weather Protection
Procedures:
0-AOI-57-1E, Grid Instability
0-GOI-200-3, Hot Weather Operations
NPG-SPP-7.1.7, Station Seasonal Readiness
TRO-EA-SOP-30.405, Nuclear Offsite Power Requirements
TRO-TO-SPP-30.128, Superseded
Other Documents:
CR 1170536
Section 1R04: Equipment Alignment
Procedures:
0-GOI-300-5, Environmentally Qualified Doors, Rev 13
Drawings:
0-47E225-137, Harsh Environmental Data, Rev 5
2-47E814-1 Flow Diagram Core Spray System, Rev 55
1-47-E836-1-1 Unit 1 Flow diagram for raw service water and high pressure fire protection
system, Rev 4
Other Documents:
Calculation ND-Q2999-970011, Reactor Building Environmental Analysis for High Energy Line
Brakes, Rev 3
Calculation R14920914110, Flooding in the Reactor Building Due to Breaks in the RWCU
System, Revision 4
VSDS Standard May Survey Report, Survey # M-20160311-24, B RWCU Pump Room,
March 11, 2016
VSDS Standard May Survey Report, Survey # M-20160518-23, A RWCU Pump Room,
May 18, 2016
CR 1161329 CR 1161330 CR 1168380 CR 1168949 CR 1169591
CR 1174095 CR 1175745
Section 1R05: Fire Protection
Procedures:
NPG-SPP 18.4.7 Control of Transient Combustibles, Rev 5
Other Documents:
Fire Protection Report Volume 1, Rev 20
Fire Protection Report Volume 2, Rev 52
Fire Protection Report Volume 2, Rev 53
NFPA 0805 Fire Protection Report Manual
Section 1R06: Flood Protection Measures
NDN-000-999-2007-0031, IF - BFN Probabilistic Risk Assessment - Internal Flooding Analysis,
Rev 0
NDQ0999920076 Flooding in the Reactor Building Due to Breaks in the RWCU System, Rev 4
CR 1144474
4
Section 1R11: Licensed Operator Requalification
Unit 2 Simulator Exercise Guide (SEG) OPL173S060, Security Event Response and Control
Room Abandonment, Revision 16
Unit 2 SEG OPL 173S414, Fire Safe Shutdown Procedures, Rev 1
Section 1R12: Maintenance Effectiveness
CR 1110412 CR 1133110 CR 1182208
Email from Maintenance Rule Coordinator about scoping requirements for Recirculation pumps
Level 2 Evaluation for CR 1110412
Maintenance Rule (a)(1) evaluation and reliability plan for Unit 3 ATWS - RPT failures (Function
068-B)
Maintenance Rule (a)(1) evaluation for U1,2,3 CR 105 Contactors
Maintenance Rule (a)(1) evaluation for U3 Function 075-B
Maintenance Rule (a)(1) plan for U1,2,3 CR 105 Contactors
Section 1R13: Maintenance Risk Assessments and Emergent Work Control
Procedures:
0-AOI-100-7, Severe Weather, Rev 36
NPG-SPP-07.3.4 Protected Equipment, Rev. 2
NPG-SPP-09.11.1 Equipment Out of Service Management, Rev. 10
Other Documents:
eSOMS Narrative Logs dated April 1, April 19, May 9 and May 18, and June 21, 2016
eSOMS Action Tracking Status for Units 1, 2 and 3 on April 1, April 19, May 9, May 18, and
June 21, 2016
Browns Ferry Unit 1, 2, and 3 Equipment Out Of Service Report dated April 1, April 19, May 9,
May 18, and June 21, 2016
Section 1R15: Operability Evaluations
Procedures:
0-OI-57A, Switchyard and 4160V AC Electrical System, Rev 157
NPG-SPP-22.302 Corrective Action Program Screening and Oversight, Rev 1
Drawings:
1-47E858-1 Units 1 & 0 Flow Diagram RHR Service Water System, Rev 72
Other Documents:
B31.1 USA Standard Code for Pressure Piping, 1967 Edition
DCN 51565 Installation of Electronic Voltage Regulator for Load Tap Changer motors
DCN 66071, 4kV and 480V Load Restrictions
EACE for CR 1154210
EDQ0-057-2004-0026, AC and DC Load Limitations for Units 1, 2, and 3 Operating, Rev 23
EDQ0057920034, 4.16kV and 480V Busload, Voltage Drop and Short Circuit Calculation, Rev
101
Equipment Apparent Cause Evaluation (EACE) for CR 1102016, Rev 0, 1 and 2
Fire Protection Report Volume 1, Rev 20
Fire Protection Report Volume 2, Rev 52
Fire Pump Surveillance data results from August 2008 until November 1, 2015
FSAR, Appendix O License Renewal Programs, Rev 26
5
MDQ002320100019, RHRSW System Hydraulic Analysis for Units 1, 2, & 3 Heat Exchangers,
Rev 2
NDQ0999940013, Reliability Analysis of the Pre-Accident and Common Accident Signal Logic
for BFN Units 1, 2 and 3, Rev 9
UFSAR Section 8.4, Normal Auxiliary Power System
CR 1102016 CR 1102418 CR 1154210 CR 1162713 CR 1163252 CR 1163822
CR 1165160 CR 1165168 PER 46252 PER 828936 CR 1178002
Past Operability Evaluation for CR 1165168
WO 03-001714-000
MDQ0000262016000558, Minimum Wall Thickness for HPFP Yard Main Fire Loop, Rev 0
Section 1R18: Plant Modifications
CR 1165519
DCN 66071, 4kV and 480V Load Restrictions
Probalistic Safety Assessment on Blocking Automatic Transfers to the Second Offsite Source
Prompt Determination of Operability for PER 994066
UFSAR Section 8.4, Normal Auxiliary Power System
Section 1R19: Post Maintenance Testing
Procedures:
0-SR-3.8.1.1(D) Diesel Generator D Monthly Operability Test
3-OI-68, Reactor Recirculation System
NPG-SPP-06.3, Pre-Post-Maintenance Testing, revision 0001
NPG-SPP-06.9.3, Post Modification Testing, revision 0006
Other Documents:
CR 1151665, VFD-068-3112, Variable Frequency Drive tripped when 3B Recirculation Pump
started.
CR 1151935, Recirculation Pump 3B MOV rotor 4 was not set prior to LS-3 opening
G-50, Torque and Limit Switch Settings for Motor Operated Valves, revision 0008
Minor Maintenance WO 117684570
Operator logs for March 20, 2016
Technical Specification 3.4.8.B
Technical Specification Bases SR 3.5.1.5
Section 1R22: Surveillance Testing
Procedures:
0-SI-4.5.C.1(D SMP), RHRSW Room D Sump Pump Test
1-SR-3.5.3.3, RCIC System Rated Flow at Normal Operating Pressure
2-SR-3.5.1.6(CS II), Unit 2 Core Spray Flow Rate Loop II
3-SR-3.8.1.7(3C), Diesel Generator 3C 24 Hour Run
3-SI-4.4.A.1, Unit 3 SLC Pump Functional Test, Rev 57
Other Documents:
Heat Exchanger Visual Inspection and Evaluation form per NPG-SPP-09.14-1 of 1C RHR Heat
Exchanger dated May 4, 2016.
WO 116797629 for CS 2-SR-3.5.1.6(CS II)
WO 116798894 for 3-SR-3.8.1.7(3C)
WO 117378609 for 0-SI-4.5.C.1(D SMP)
6
WO 117378627 for RCIC SR-3.5.3.3
Section 1EP2: Alert and Notification System Evaluation
Procedures:
EPDP-8, Emergency Preparedness Quality Assurance, Rev. 4
EPDP-10, Facilitation of the Alert and Notification System and Notification Tests, Rev. 6
EPDP-14, Evaluation of Changes to Alert and Notification Systems (ANS), Rev. 0
EPDP-17, NPG Emergency Plan Effectiveness Review (10 CFR 50.54(q)), Rev. 5
EPFS-9, Inspection, Service, and Maintenance of the Prompt Notification System (PNS) at
Browns Ferry, Sequoyah, and Watts Bar Nuclear Plants, Rev. 9
NPG-SPP-18.3.5, Equipment Important to Emergency Response, Rev. 4
Other Documents:
Documentation of Quarterly siren maintenance for 2nd quarter 2014 to 1st quarter 2016
Documentation of bi-weekly siren tests and maintenance for 2nd quarter 2014 to 1st quarter 2016
Siren Annual Maintenance records: 2014 to 2015
508, Electromechanical Siren Installation and Operating Instructions, Rev. 12/11
2015 & 2016 Browns Ferry Emergency Planning Calendar mailer to members of the public in
the 10-mile EPZ
CR 973613 CR 1008361 CR 1134691 CR 1134696 CR 1149293 CR 1160115
CR 1168226
Section 1EP3: Emergency Response Organization Staffing and Augmentation System
Procedures:
EPDP-3, Emergency Plan Exercises and Preparedness Drills, Rev. 13
EPIP-2, Notification of Unusual Event, Rev. 36
EPIP-6, Activation and Operation of the Technical Support Center (TSC), Rev. 37
EPIP-7, Activation and Operation of the Operations Support Center (OSC), Rev. 33
TRN-30, REP Training, Rev. 32
Other Documents:
Browns Ferry Nuclear Plant On-Shift Staffing Analysis Report, dated 12/10/12
Browns Ferry Nuclear Plant NEI 12-01 Phase 2 Extended Loss of Power ERO Staffing Analysis
Report, Rev. 0, dated 1/23/15
Exercise Report Browns Ferry Augmentation Drill, dated 12/4/14
Exercise Report Browns Ferry Augmentation Drill, dated 5/11/15
Exercise Report Browns Ferry Augmentation Drill, dated 5/15/15
Selected Qualification Records for Key Position ERO Personnel
Various EP staff and ERO member training records
CR 963870 CR 1018295 CR 1018296 CR 1018297 CR 1044179 CR 1136856
CR 1158631
Section 1EP4: Emergency Action Level and Emergency Plan Changes
Procedures:
NP-REP Radiological Emergency Plan, Rev. 105 & 106
NP-REP Radiological Emergency Plan App. A, Browns Ferry Nuclear Plant, Rev. 105 & 106
EPDP-3, Alert, Rev. 37
EPDP-17, NPG Emergency Plan Effectiveness Review [10 CFR 50.54(q)], Rev. 5
EPIP-1, Emergency Classification Procedure, Rev. 52 & 53
7
Other Documents:
CECC 2014-050, EPDP-17, Att. 2 Screening Evaluation Form for change of location of JIC,
dated 6/2/15
CECC 2014-050, EPDP-17, Att. 4 Effectiveness Evaluation Form for change of location of JIC,
dated 6/2/15
CECC 2015-026, EPDP-17, Att. 2 Screening Evaluation Form for REP App. A, Rev. 106, dated
7/21/15
CECC 2015-045, EPDP-17, Att. 2 Screening Evaluation Form for removal of JIC Liaison
position from the ERO, dated 10/30/15
CECC 2015-045, EPDP-17, Att. 4 Effectiveness Evaluation Form for removal of JIC Liaison
position from the ERO, dated 10/30/15
CECC 2015-059, EPDP-17, Att. 2 Screening Evaluation Form for changes to the NP-REP
(Generic) Rev. 106, dated 12/4/15
CECC 2015-060, EPDP-17, Att. 2 Screening Evaluation Form for wording changes to NP-REP
(Generic) Rev. 106, dated 12/4/15
CECC 2015-061, EPDP-17, Att. 2 Screening Evaluation Form for addition of EPDP-3,
Emergency Plan Exercises & Preparedness Drills, to Section 16.3 of NP-REP (Generic) Rev.
106, dated 12/4/15
CECC 2016-017, EPDP-17, Attachment 2 Screening Evaluation Form for REP Appendix A,
Rev.107, dated 5/19/16
CECC 2016-018, EPDP-17, Attachment 2 Screening Evaluation Form for REP Appendix A,
Rev.107, dated 5/18/16
BFN-2015-023, EPDP-17, Att. 2 Screening Evaluation Form for EPIP-1 Rev. 52, dated 12/16/16
BFN-2016-026, EPDP-17, Att. 2 Screening Evaluation Form for EPIP-1, Rev. 53, dated 5/19/16
BFN-2016-029, EPDP-17, Att. 2 Screening Evaluation Form for EPIP-1, Rev. 53, dated 5/19/16
BFN-2016-030, EPDP-17, Att. 2 Screening Evaluation Form for EPIP-1, Rev. 53, dated 5/19/16
CR 940284 CR 977864 CR 1067432 CR 1106129 CR 1131140 CR 1132342
CR 1157129 CR 1180166 CR 1180169 CR 1180171
Section 1EP5: Maintenance of Emergency Preparedness
Procedures:
EPDP-1, Procedures, Maps, and Drawings, Rev. 11
EPDP-17, NPG Emergency Plan Effectiveness Review, Rev. 5
EPIP-1, Emergency Classification Procedure, Rev. 53
EPIP-6, Activation and Operation of the Technical Support Center, Rev.37
EPIP-7, Activation and Operation of the Operations Support Center, Rev.33
NPG-SPP-18.3, Emergency Preparedness, Rev. 12
NPG-SPP-18.3.5, Equipment important to Emergency Response, Rev. 4
NPG-SPP-18.3.7, Alternate Facility Activation and Operation, Rev. 2
NPG-SPP-22.300, Corrective Action Program, Rev. 6
NPG-SPP-22.301, Condition Report Initiation, Rev. 6
NPG-SPP-22.302, Corrective Action Program Screening, Rev. 9
NPG-SPP-22.303, Condition Report Actions, Closures, and Approval, Rev. 9
NPG-SPP-22.304, Condition Report Trending, Rev. 4
NPG-SPP-22.305, Level 2 Evaluation, Rev. 6
NPG-SPP-22.306, Level 1 Evaluation, Rev. 6
REP, Radiological Emergency Plan, (Generic Part), Rev. 106
REP, Radiological Emergency Plan, (Appendix A - BFN), Rev. 107
Other Documents:
Annual Review and Approval of ETE Update Levels, dated 12/11/15
8
BFN Self-assessment BFN-EP-SSA-15-002, Risk Significant External Inspection
BFN Self-assessment BFN-EP-SSA-16-001, Emergency Responder SCBA Qualification
Verification
BFN Self-assessment BFN-EP-SSA-16-102, Pre-NRC Baseline Inspection
Browns Ferry NOUE Event Report, dated 5/2/16
Browns Ferry Nuclear Plant- Quality Assurance Oversight Report QA-BF-16-010, dated 5/25/16
Drill Report Browns Ferry Off Year Report, dated 8/19/14
Drill Report Browns Ferry Graded Exercise, dated 11/11/15
Drill Report Browns Ferry SAMG Drill, dated 1/27/16
Evacuation Time Estimates for Browns Ferry Nuclear Power Plant Plume Exposure Pathway
Emergency Planning Zone, dated August 2013
Radiological Emergency Plan Effluent Radiation Monitor EAL calculations, dated 1/7/16
Site Audit Report SSA-1501 Radiological Emergency Preparedness Browns Ferry, dated
2/25/15
Various Inventories of Emergency Facilities, Emergency Equipment and Supplies for 1st Quarter
2016
Work Order 115705064, Wide Range Effluent Radiation Monitor System - Mid and High Range
Noble Gas Calibration, dated 5/20/15
Work Order 115869304, Wide Range Effluent Radiation Monitor System - Noble Gas
Calibration, dated 10/29/15
CR 972013 CR 982716 CR 983249 CR 992269 CR 1001273 CR 1018297
CR 1011323 CR 1020921 CR 1081855 CR 1086387 CR 1100545 CR 1101654
CR 1101656 CR 1101697 CR 1101700 CR 1101712 CR 1103755 CR 1111436
CR 1133821 CR 1157129 CR 1163146 CR 1165533
Section 1EP6: Drill Evaluation (IP 71114.06)
CR 1170676 CR 1170953 CR 1170704 CR 1170717 CR 1170719 CR 1170838
CR 1170725 CR 1170740 CR 1170747 CR 1170800 CR 1170802 CR 1170816
CR 1170843
Section 2RS6: Radioactive Gaseous and Liquid Effluent Treatment
Procedures:
Offsite Dose Calculation Manual, Rev. 22 and Rev. 23
CI-710, Liquid Permit Processing, Rev. 21
CI-712, Liquid Monthly Calculations, Rev. 12
CI-714, Particulate and Charcoal Filter Sampling and Analysis, Rev. 41
CI-716, Processing Gaseous Permits from Charcoal/Particulate Filters, Rev. 17
CI-720, Determining Vent Flow, Rev. 16
CI-721, Manual Liquid Release Permit Generation, Rev. 00
0-SI-4.8.A.1-1, Liquid Effluent Permit, Rev. 09
0-SI-4.8.A.5-1, Appendix I Dose Calculations - Liquid Effluents, Rev. 19
0-SI-4.8.B.2-1, Airborne Effluent Analysis - Particulate and Charcoal Filter Analysis, Rev. 42
0-SI-4.8.B.1.a.1, Airborne Effluent Release Rate, Rev. 58
0-SI-4.8.B.2-8, Airborne Effluent Analysis - Stack Noble Gas, Rev. 17
0-SI-4.8.B.3, Appendix I Dose Calculations - Airborne Effluents, Rev. 25
0-SI-4.8.C, Annual 40CFR190 Dose Calculation, Rev. 11
NPG-SPP-22.302, Corrective Action Program Screening, Rev. 9
Other Documents:
Annual Radioactive Effluent Release Report, 2014 and 2015
BFN-VRD-MI07-0030, Microdesigns, Inc., Calibration of the Wide-Range Gaseous Effluent
9
Radiation Monitoring System (WRGERMS), 08/31/89
Certificate of Gamma Standard Source, Cs-137 177-29-3, 08/01/86
Certificate of Calibration, Source 22695-135 Ba-133, 02/12/87
Effluent Monitor Out-of-service List, June 2014 - May 2016
WO 115869304, Wide Range Gaseous Effluent Rad Mon Sys - Mid & High Range Noble Gas
Calibration, 11/05/15
WO 114630294, Wide Range Gaseous Effluent Rad Mon Sys - Mid & High Range Noble Gas
Calibration, 12/04/12
WO 115378045, Rx Bldg Vent Exhaust Rad Mon Calibration and Functional Test 1-RM-90-250,
12/16/14
WO 116907681, Rx Bldg Vent Exhaust Rad Mon Calibration and Functional Test 1-RM-90-250,
07/10/15
WO 115528159, RCW Rad Mon (1-RM-90-132D) Calibration and Functional Test, 03/07/14
WO 115433665, RCW Rad Mon (1-RM-90-132D) Calibration and Functional Test, 01/09/15
WO 115755949, Airborne Effluents - Main Stack Mon Sys Calibration, 05/28/15
WO 116986591, Airborne Effluents - Main Stack Mon Sys Calibration, 08/04/15
WO 113150722, SGT Filter Pressure Drop Test & In Place Leak Test - Train A, 11/07/12
WO 115240014, SGT Filter Pressure Drop Test & In Place Leak Test - Train A, 09/26/14
WO 113816413, SGT Filter Pressure Drop Test & In Place Leak Test - Train B, 12/21/12
WO 115756003, SBGTS Iodine Removal Efficiency - Train B, 02/06/15
WO 114313192, SGT Filter Pressure Drop Test & In Place Leak Test - Train C, 03/24/13
WO 115869445, SBGTS Iodine Removal Efficiency - Train C, 05/22/15
WO 116796700, Airborne Effluent Release Rate, 05/07/16
Gaseous Radioactive Waste Release Permit no. 160276.030.016.G
Gaseous Radioactive Waste Release Permit no. 160303.037.020.G
Gaseous Radioactive Waste Release Permit no. 160295.031.016.G
Gaseous Radioactive Waste Release Permit no. 160311.041.021.G
Liquid Radioactive Waste Release Permit no. 150173.004.110.L
Liquid Radioactive Waste Release Permit no. 160001.002.001.L
Results of Radiochemistry Interlaboratory Cross-Check Program, 3rd Quarter 2015 - 1st Quarter
2016
2015 Part 61 CWPS, DAW, RWCU, Thermex Analyses
Special Report for the Bypass of the Gaseous Radwaste Offgas Charcoal Absorbers, 12/23/14
BFN-RP-SSA-16-002, RP Public Radiation Safety Baseline Snapshot Self-Assessment Report,
02/05/16
BFN-CEM-SSA-15-006, Liquid Effluent Monitoring Snapshot Self-Assessment Report, 07/01/15
CR 849316 CR 861975 CR 934551 CR 956279 CR 970739 CR 974829
CR 981336 CR 1012875 CR 1101799 CR 1148656 CR 1153528
Section 2RS7: Radiological Environmental Monitoring Program (REMP)
Procedures:
Offsite Dose Calculation Manual, Rev. 23
CI-420, Collection of Radiological Environmental Monitoring Samples, Rev. 8
CI-421, Well Sampling and Maintenance, Rev. 13
NPG-SPP-05.14, Guide for Communicating Inadvertent Radiological Spills/Leaks to Outside
Agencies, Rev. 4
EPFS-4, Environmental Data Station Meteorological Sensor Exchange, Rev. 20
EPFS-6, Calibration of Environmental Data Station Data Logger and Sonic Channels, Rev. 16
Instruction No. 450.01-005, Calibration of Air Temperature Sensors - Nuclear, Rev. 4
NPG-SPP-22.302, Corrective Action Program Screening, Rev. 9
10
Other Documents:
2014 Annual Radiological Environmental Operating Report
2015 Annual Radiological Environmental Operating Report
2015 Annual Radioactive Effluent Report
Meteorological Data Recoverability Report, 2014 - 2015
Risk Ranked Structures, Systems, and Components
Work Order 116795748
Meteorological Monitoring Instrument Report of Calibration, Ultrasonic Wind Sensor B0830001,
9/22/14, 9/17/15
Meteorological Monitoring Instrument Report of Calibration, Ultrasonic Wind Sensor B2310005,
2/12/15, 9/17/15
Meteorological Monitoring Instrument Report of Calibration, Ultrasonic Wind Sensor B4410001,
7/8/15, 10/19/15
Meteorological Monitoring Instrument Report of Calibration, RTD 205498, 8/21/14, 10/1/15
Meteorological Monitoring Instrument Report of Calibration, RTD 205510, 8/21/14, 10/1/15
Meteorological Monitoring Instrument Report of Calibration, RTD 205523, 8/21/14, 10/1/15
Calibration Data Sheets, Radiological Environmental Monitoring Air Sampler Gas Meter Serial
Nos. 1030568, 1030570, 1030580, 1030601, 1030581, 1030569, 1030603; 9/4/14, 8/26/15
Calibration Data Sheets, Radiological Environmental Monitoring Air Sampler Gas Meter Serial
Nos. 1030571, 1040145, 1030582, 14436698, 1030574, 17074896, 1030583; 9/4/14, 8/25/15
Browns Ferry 50.75(g) entries from Jun2 1, 2014 - June 1, 2016
Groundwater Monitoring Well Results, 10/23/15 - 5/27/16
BFN-RP-SSA-16-002, RP Public Radiation Safety Baseline Self-Assessment
BFN-CEM-SSA-15-002, Groundwater Protection Program, NEI 07-07, Self-Assessment
CR 1031186 CR 1066646 CR 1149617 CR 1164659 CR 885869 CR 915148
CR 993178 CR 997291
Section 4OA1: Performance Indicator (PI) Verification
Procedures:
FAQ for NEI 99-02 Regulatory Assessment Performance Indicators as of February 9, 2015
NEI 99-02 Regulatory Assessment Performance Indicator Guideline, Rev 7
Unit 1, 2, and 3 MSPI Basis Documents, Rev 17, 16, 15 respectively
Other Documents:
HPCI Maintenance Rule Availability and Reliability data
RCIC Maintenance Rule Availability and Reliability data
Gaseous Radioactive Waste Release Permit no. 160312.030.017.G
Gaseous Radioactive Waste Release Permit no. 160277.031.015.G
Liquid Radioactive Waste Release Permit no. 160001.002.001.L
Semiannual Radioactive Effluent Release Report 2016 - Gaseous Effluents, 05/31/16
Section 4OA2: Identification and Resolution of Problems
Procedures:
NPG SPP 07.3, Work Activity, Risk Management Process, Revision 15
NPG-SPP-03.5, Regulatory Reporting Requirements, Rev 12
NPG-SPP-07.7, NPG CTS Role and Oversight of Supplemental Personnel
NPG-SPP-19.4, Refueling and Steam Generator Alliance Services
NPG-SPP-22.201, Oversight of the Human Performance Program
NUREG 1022, Event Reporting Guidelines: 10 CFR 50.72 and 50.73, Rev 3
11
Drawings:
2-45E714-2 Wiring Diagram 250V DC Reactor MOV Board 2A Schematic Diagram, Rev 30
Other Documents:
AZZ Nuclear Technical Bulletin TB-12-007, Revision 0 Masterpact Breakers Fail to Close
NLI-QA-3500 Report of potential 10 CFR Part 21 Condition, Masterpact Replacement Breaker
Fail to Close Operation, Rev 1
River Bend Station Special Inspection Report 05000458/2015010
CR 1142808 CR 1146299 CR 1151321 CR 1153334 CR 1160196 CR 1165557
CR 1185268
Past Operability Evaluation for 1153334
WO 117679885 WO 115366028 WO 1153068 WO 115366078
WO 115372045
Section 4OA3: Event Follow-up
Procedures:
2-POI-74-1, RHR System Piping Flushes, Rev 23
Other Documents:
CR 1126697
EACE for CR 1126697
POE for CR 1126697
Section 4OA5: Other Activities
Procedures:
HPP-2245-100 & 200, BFN Hi-STORM FX/MPC Pre-Operation Inspection, Revision 7
HPP-2245-300, MPC Sealing, Revision 7
HPP-2245-400, MPC Transfer, Revision 5
HPP-2245-500, Hi-STORM FW Site Transportation, Revision 5
MSI 0-079-DCS035, Dry Cask Storage Campaign Guidelines, Revision 17
MSI 0-079-DCS043, Dry Cask Campaign Review Program, Revision 8
OPDP-1 Conduct of Operations Rev. 0031 & 0035
Other Documents:
Current Campaign MPC Loading Maps - MPCFW-021, 022, 023, 024, 025, 026 & 027.
Independent Spent Fuel Storage Installation Certificate of Compliance, 72.1014
Independent Spent Fuel Storage Installation Manual
Condition Report CR 1058728, Foreign Material found in fuel assemble JLB423
Previous Campaign (July 2015): MPC Loading Maps - MPCFW- 020, 019, 018, 107, 016, -
015, 003, 014, 013, 004, 002, 001.
Special Nuclear Material Inventories for MPC February 23, 2016
Condition Reports: 790109, 896301, 925914, 838977, 838972, 988162, 838977, 935471,
988162, 925914, 838977, 907411, 901307, 863323
115881677 Commitment Completion Form (R20 140718 053).
115881648 Commitment Completion Form (R20 141203 102).
115864926 Commitment Completion Form (R20 140718 052).
115864910 Commitment Completion Form (R20 140825 065).
115864896 Commitment Completion Form (R20 141022 091).
115849901 Commitment Completion Form (R20 160119 001)
12
115849821 Commitment Completion Form (R20 150710 100).
115849804 Commitment Completion Form (R20 150213 027).
115849791 Commitment Completion Form (R20 150720 103).
115849754 Commitment Closure Form (R20 151204 110).
115839725 Commitment Completion Form (R20 141003 088).
LIST OF ACRONYMS
ADAMS - Agencywide Document Access and Management System
ADS - Automatic Depressurization System
ARM - area radiation monitor
CAD - containment air dilution
CAP - corrective action program
CCW - condenser circulating water
CFR - Code of Federal Regulations
COC - certificate of compliance
CR - condition report
CRD - control rod drive
CS - core spray
DCN - design change notice
EECW - emergency equipment cooling water
ED Electronic dosimeter
EDG - emergency diesel generator
FE - functional evaluation
FPR - Fire Protection Report
FSAR - Final Safety Analysis Report
HPCI - high pressure coolant injection
IP Inspection Procedure
IMC - Inspection Manual Chapter
LHRA Locked High Radiation Area
LER - licensee event report
NCV - non-cited violation
NEI Nuclear Energy Institute
NIST National Institute of Standards and Technology
NRC - U.S. Nuclear Regulatory Commission
NSTS National Source Tracking System
ODCM - Off-Site Dose Calculation Manual
OSLD Optically Stimulated Luminescence Dosimeter
PCM Personnel Contamination Monitor
PER - problem evaluation report
PCIV - primary containment isolation valve
PI - performance indicator
QA Quality Assurance
Radwaste Radioactive Waste
RCA Radiologically Controlled Area
RCE - Root Cause Evaluation
RCIC - reactor core isolation cooling
RCW - Raw Cooling Water
REMP - Radiological Environmental Monitoring Program
RG - Regulatory Guide
RHRSW - residual heat removal service water
RPT Radiation Protection Technician
RS Radiation Safety
RTP - rated thermal power
2
RPS - reactor protection system
RWP - radiation work permit
SAM Small Article Monitor
SDP - significance determination process
SBGT - standby gas treatment
SNM - special nuclear material
SR - service request
SSC - structure, system, or component
TI - Temporary Instruction
TIP - transverse in-core probe
TRM - Technical Requirements Manual
TS - Technical Specification(s)
UFSAR - Updated Final Safety Analysis Report
URI - unresolved item
VHRA Very High Radiation Area
WO - work order