IR 05000341/2019003

Integrated Inspection Report 05000341/2019003

ML19310E673
Person / Time
Site:	Fermi
Issue date:	11/06/2019
From:	Eric Duncan Reactor Projects Region 3 Branch 4
To:	Peter Dietrich DTE Energy
References
IR 2019003
Download: ML19310E673 (31)

Text

ber 6, 2019

SUBJECT:

FERMI POWER PLANT, UNIT 2 - INTEGRATED INSPECTION REPORT 05000341/2019003

Dear Mr. Dietrich:

On September 30, 2019, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at Fermi Power Plant, Unit 2. On October 16, 2019, the NRC inspectors discussed the results of this inspection with you and other members of your staff. The results of this inspection are documented in the enclosed report.

Three findings of very low safety significance (Green) are documented in this report. Two of these findings involved violations of NRC requirements. We are treating these violations as non-cited violations (NCVs) consistent with Section 2.3.2 of the Enforcement Policy.

If you contest the violations or significance or severity of the violations documented in this inspection report, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the U.S. Nuclear Regulatory Commission, ATTN:

Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region III; the Director, Office of Enforcement; and the NRC Resident Inspector at Fermi.

If you disagree with a cross-cutting aspect assignment or a finding not associated with a regulatory requirement in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the U.S. Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region III; and the NRC Resident Inspector at Fermi. This letter, its enclosure, and your response (if any) will be made available for public inspection and copying at http://www.nrc.gov/reading-rm/adams.html and at the NRC Public Document Room in accordance with 10 CFR 2.390, Public Inspections, Exemptions, Requests for Withholding.

Sincerely,

/RA/

Eric R. Duncan, Chief Branch 4 Division of Reactor Projects Docket No. 05000341 License No. NPF-43

Enclosure:

As stated

Inspection Report

Docket Number: 05000341 License Number: NPF-43 Report Number: 05000341/2019003 Enterprise Identifier: I-2019-003-0058 Licensee: DTE Electric Company Facility: Fermi Power Plant, Unit 2 Location: Newport, MI Inspection Dates: July 01, 2019 to September 30, 2019 Inspectors: T. Briley, Senior Resident Inspector G. Edwards, Health Physicist J. Harvey, Resident Inspector L. Kozak, Senior Reactor Analyst R. Ng, Project Engineer T. Taylor, Resident Inspector Approved By: Eric R. Duncan, Chief Branch 4 Division of Reactor Projects Enclosure

SUMMARY

The U.S. Nuclear Regulatory Commission (NRC) continued monitoring the licensees performance by conducting an integrated inspection at Fermi Power Plant, Unit 2 in accordance with the Reactor Oversight Process. The Reactor Oversight Process is the NRCs program for overseeing the safe operation of commercial nuclear power reactors. Refer to https://www.nrc.gov/reactors/operating/oversight.html for more information.

List of Findings and Violations Incorrect Datum Used to Assess Lake Levels Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green None (NPP) 71111.01 Systems NCV 05000341/2019003-01 Open/Closed The inspectors identified a finding of very low safety significance (i.e., Green) and an associated Non-Cited Violation (NCV) of 10 CFR 50, Appendix B, Criterion III, Design Control, when licensee personnel failed to have appropriate measures in place to assess the impact of projected Lake Erie water levels on the site. As a result, actual lake level, including any predicted maximum lake level during a flood watch or warning, was determined to be 1.3' [feet] higher during a flooding event than what was calculated.

Inadequate Response to an Out-of-Service Diesel Fire Pump Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green [H.5] - Work 71111.18 Systems NCV 05000341/2019003-02 Management Open/Closed A self-revealed finding of very low safety significance (i.e., Green) and an associated Non-Cited Violation (NCV) of Fermi License Condition 2.C.(9) was identified when licensee personnel failed to take appropriate actions in response to an out-of-service diesel fire pump.

Specifically, a temporary diesel fire pump (DFP) used to restore system functionality failed to function as designed and the risk plan that was developed could not be implemented as written.

Failure to Properly Pre-Plan Work in Accordance with the Work Control Conduct Manual Cornerstone Significance Cross-Cutting Report Aspect Section Barrier Integrity Green [H.7] - 71153 FIN 05000341/2019003-03 Documentation Open/Closed A self-revealed finding of very low safety significance (i.e., Green) was identified when the licensee failed to properly pre-plan maintenance activities on the Feedwater Distributed Control System in accordance with the Work Control Conduct Manual. This resulted in an unplanned loss of the gland seal exhauster trip safety function.

Additional Tracking Items Type Issue Number Title Report Section Status LER 05000341/2019-001-00 LER 2019-001-00 for Fermi 71153 Closed Unit 2, Unplanned Loss of Safety Function of Gland Seal Exhauster Trip During Planned Maintenance Due to Inadequate Procedure.

PLANT STATUS

Unit 2 operated at or near rated thermal power during the entire inspection period with the exception of power changes to perform planned rod pattern adjustments.

INSPECTION SCOPES

Inspections were conducted using the appropriate portions of the inspection procedures (IPs) in effect at the beginning of the inspection unless otherwise noted. Currently approved IPs with their attached revision histories are located on the public website at http://www.nrc.gov/reading-rm/doc-collections/insp-manual/inspection-procedure/index.html. Samples were declared complete when the IP requirements most appropriate to the inspection activity were met consistent with Inspection Manual Chapter (IMC) 2515, Light-Water Reactor Inspection Program - Operations Phase. The inspectors performed plant status activities described in IMC 2515 Appendix D, Plant Status and conducted routine reviews using IP 71152, Problem Identification and Resolution. The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel to assess licensee performance and compliance with Commission rules and regulations, license conditions, site procedures, and standards.

71111.01 - Adverse Weather Protection External Flooding Sample (IP Section 03.04)

(1) The inspectors evaluated the licensee's readiness to cope with external flooding under the following conditions:

• High Lake Erie water level monthly averages

71111.04Q - Equipment Alignment Partial Walkdown Sample (IP Section 03.01)

The inspectors evaluated system configurations during partial walkdowns of the following systems/trains:

(1) Emergency Diesel Generator (EDG) 12 while Combustion Turbine Generator (CTG)11-1 was out of service for planned maintenance during the week ending September 14, 2019

(2) Electric Fire Pump while the Diesel Fire Pump and a Temporary Alternate Diesel Fire Pump were out of service for corrective maintenance during the week ending September 7, 2019

(3) Division 1 Core Spray (CS) while Division 2 CS was out of service for planned maintenance during the week ending September 21, 2019

(4) Division 2 Non-Interruptible Air System (NIAS) after planned maintenance during the week ending September 28, 2019

71111.04S - Equipment Alignment Complete Walkdown Sample (IP Section 03.02)

(1) The inspectors evaluated system configurations during a complete walkdown of the Emergency Equipment Cooling Water (EECW) system during the week ending September 28, 2019

71111.05Q - Fire Protection Quarterly Inspection (IP Section 03.01)

The inspectors evaluated fire protection program implementation in the following selected areas:

(1) General Service Water Pump House during the week ending August 31, 2019

(2) Auxiliary Building Sub-Basement and NIAS Room during the week ending September 28, 2019

(3) Auxiliary Building Fifth Floor, Division 1 and Division 2 Standby Gas Treatment Rooms during the week ending September 28, 2019

(4) Reactor Building Basement and Sub-Basement, Northeast Corner Room during the week ending September 28, 2019

71111.06 - Flood Protection Measures Inspection Activities - Internal Flooding (IP Section 02.02a.)

The inspectors evaluated internal flooding mitigation protections in the:

(1) Torus Room

71111.11Q - Licensed Operator Requalification Program and Licensed Operator Performance Licensed Operator Performance in the Actual Plant/Main Control Room (IP Section 03.01)

(1) The inspectors observed and evaluated licensed operator performance in the Control Room during power ascension following a planned down power for Main Steam Isolation Valve (MSIV) testing and a rod pattern adjustment on September 8, 2019 Licensed Operator Requalification Training/Examinations (IP Section 03.02) (2 Samples)

(1) The inspectors observed and evaluated an as-found simulator assessment during the week ending August 31, 2019

(2) The inspectors observed and evaluated an as-found simulator assessment during the week ending September 7, 2019

71111.13 - Maintenance Risk Assessments and Emergent Work Control Risk Assessment and Management Sample (IP Section 03.01)

The inspectors evaluated the risk assessments for the following planned and emergent work activities:

(1) Emergent maintenance on Mechanical Draft Cooling Tower Fan D during the week ending August 3, 2019

(2) Planned High Pressure Coolant Injection (HPCI) surveillance testing during the week ending August 24, 2019

(3) Planned CTG 11-1 maintenance, new CTG fuel oil storage tank installation, with an installed Alternate Diesel Fire Pump during the week ending September 14, 2019

71111.15 - Operability Determinations and Functionality Assessments Operability Determination or Functionality Assessment (IP Section 02.02)

The inspectors evaluated the following operability determinations and functionality assessments:

(1) Operability and functionality of the Standby Liquid Control (SLC) system following identification of a potential non-conservative Technical Specification associated with minimum SLC tank level, as documented in Condition Assessment Resolution Document (CARD) 19-21369

(2) Operability and functionality of the Suppression Chamber (Torus) structure following a missed Technical Requirements Manual (TRM) surveillance requirement to perform an exterior visual inspection, as documented in CARD 19-25694

(3) Functionality of the Diesel Fire Pump following identification of wear on the right angle drive anti-rotational clutch, as documented in CARD 19-26111

(4) Operability and functionality of the Reactor Core Isolation Cooling (RCIC) system following identification of an abnormal RCIC flow controller reading while the system was in a standby condition, as documented in CARDs 19-26174 and 19-26198

(5) Operability and functionality of the Division 2 Reactor Protection System (RPS),

Average Power Range Monitor (APRM), and Oscillation Power Range Monitor (OPRM) systems following abnormal light indications during a planned logic module functional test, as documented in CARD 19-26362

71111.18 - Plant Modifications Temporary Modifications and/or Permanent Modifications (IP Section 03.01 and/or 03.02)

The inspectors evaluated the following temporary or permanent modifications:

(1) Installation of an Alternate Diesel Fire Pump while the Diesel Fire Pump was out of service for an extended period (Temporary Modification)

(2) Installation of Gland Seal Exhauster trip function (Permanent Modification)

71111.19 - Post-Maintenance Testing Post-Maintenance Test Sample (IP Section 03.01)

The inspectors evaluated the following post maintenance tests:

(1) RPS Channel A2 Reactor Vessel Level 1 and 2 agastat relays following planned maintenance during the week ending July 13, 2019

(2) CTG 11-1 following planned maintenance during the week ending September 14, 2019

(3) Division 2 NIAS following planned maintenance during the week ending September 28, 2019

71111.22 - Surveillance Testing The inspectors evaluated the following surveillance tests: Surveillance Tests (other) (IP Section 03.01)

(1) Low Pressure Coolant Injection (LPCI) Loop Select 480 Volt Swing Bus (72CF)automatic throwover scheme operability test during the week ending July 8, 2019

(2) Emergency Diesel Generator (EDG) 14 24-hour run followed by hot fast restart during the week ending August 3, 2019

Inservice Testing (IP Section 03.01) (2 Samples)

(1) High Pressure Coolant Injection (HPCI) pump and valve operability test at 1025 pounds per square inch (psi) during the week ending August 24, 2019

(2) Division 2 LPCI and Suppression Pool Cooling/Spray pump and valve operability test during the week ending August 31,

71124.08 - Radioactive Solid Waste Processing and Radioactive Material Handling, Storage, and Transportation Radioactive Material Storage (IP Section 02.01)

The inspectors evaluated radioactive material storage.

(1) The inspectors toured the following areas:

• Fermi 2 Radioactive Waste Building Basement

• Fermi 2 Radioactive Waste Building Mezzanine

• Fermi 2 Radioactive Waste Building Main Floor

• Fermi 2 Radioactive Waste Onsite Storage Facility The inspectors performed a container check (e.g., swelling, leakage and deformation)on the following containers:

• 55 Gallon Drum 6512; Fermi 2 Radioactive Waste Onsite Storage Facility

• 55 Gallon Drum 6572; Fermi 2 Radioactive Waste Onsite Storage Facility

• 55 Gallon Drum 6577; Fermi 2 Radioactive Waste Onsite Storage Facility

• 55 Gallon Drum 6578; Fermi 2 Radioactive Waste Onsite Storage Facility

• 55 Gallon Drum 6225; Fermi 2 Radioactive Waste Onsite Storage Facility Radioactive Waste System Walkdown (IP Section 02.02) (1 Sample)

The inspectors evaluated the following radioactive waste processing systems and processes during plant walkdowns:

(1) Liquid or Solid Radioactive Waste Processing Systems

• Fermi 2 Spent Fuel Pool Cooling and Clean Up

• Fermi 2 Asphalt Solidification System

• Fermi 2 Floor Drain Collection System Radioactive Waste Resin and/or Sludge Discharges Processes

• Fermi 2 Spent Resin Tank

• Fermi 2 Primary Resin System

• Fermi 2 Resin Demineralizers Waste Characterization and Classification (IP Section 02.03) (1 Sample)

The inspectors evaluated the radioactive waste characterization and classification for the following waste streams:

(1)

• Fermi 2 Dry Active Waste

• Fermi 2 Condensate Resin System

Shipment Preparation (IP Section 02.04) (1 Sample)

The inspectors evaluated and observed the following radioactive material shipment preparation processes:

(1)

• EF2-19-051; UN (United Nations) 3321; Radioactive Material, LSA-II (Low Specific Activity-II), 7; 07/17/2019

Shipping Records (IP Section 02.05) (1 Sample)

The inspectors evaluated the following non-excepted package shipment records:

(1)

• EF2-17-136; Dewatered Resin Liner, LH-16-017; 01/12/2018

• EF2-18-007; Dewatered Resin Liner, LH-16-007; 01/19/2018

• EF2-18-009; Dewatered Resin Liner, LH-17-005; 02/12/2018

OTHER ACTIVITIES - BASELINE

===71151 - Performance Indicator Verification The inspectors verified licensee performance indicators submittals listed below:

MS08: Heat Removal Systems (IP Section 02.07) ===

(1) Unit 2 (July 1, 2018 - June 30, 2019)

MS09: Residual Heat Removal Systems (IP Section 02.08) (1 Sample)

(1) Unit 2 (July 1, 2018 - June 30, 2019)

MS10: Cooling Water Support Systems (IP Section 02.09) (1 Sample)

(1) Unit 2 (July 1, 2018 - June 30, 2019)

BI01: Reactor Coolant System (RCS) Specific Activity Sample (IP Section 02.10) (1 Sample)

(1) Unit 2 (July 1, 2018 - June 30, 2019)

OR01: Occupational Exposure Control Effectiveness Sample (IP Section 02.15) (1 Sample)

(1) Unit 2 (July 1, 2018 - June 30, 2019)

PR01: Radiological Effluent Technical Specifications/Offsite Dose Calculation Manual Radiological Effluent Occurrences (RETS/ODCM) Radiological Effluent Occurrences Sample (IP Section 02.16) (1 Sample)

(1) Unit 2 (July 1, 2018 - June 30, 2019)

71152 - Problem Identification and Resolution Semiannual Trend Review (IP Section 02.02)

(1) The inspectors reviewed the licensees corrective action program for potential adverse trends in the issuance of parts and storage of quality material that could be indicative of a more significant safety issue

71153 - Followup of Events and Notices of Enforcement Discretion Event Report (IP Section 03.02)

The inspectors evaluated the following Licensee Event Report (LER):

(1) LER 2019-001-00, Unplanned Loss of Safety Function of Gland Seal Exhauster Trip during Planned Maintenance Due to Inadequate Procedure (ADAMS Accession ML19060A290). The circumstances surrounding this LER are documented in the Results Section of this report.

INSPECTION RESULTS

Incorrect Datum Used to Assess Lake Levels Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green None (NPP) 71111.01 Systems NCV 05000341/2019003-01 Open/Closed The inspectors identified a finding of very low safety significance (i.e., Green) and an associated Non-Cited Violation (NCV) of 10 CFR 50, Appendix B, Criterion III, Design Control, when licensee personnel failed to have appropriate measures in place to assess the impact of projected Lake Erie water levels on the site. As a result, actual lake level, including any predicted maximum lake level during a flood watch or warning, was determined to be 1.3

[feet] higher during a flooding event than what was calculated.

Description:

As discussed in the Fermi Updated Final Safety Analysis Report (UFSAR), the determination of a mean Lake Erie water level reference point to ensure that safety-related structures, systems, and components (SSCs) are protected from flooding was based on 1935 New York Mean Tide (NYMT) lake level data. During this inspection period, the inspectors discovered that to calculate the maximum expected Lake Erie water level and assess site impact from potential flooding, the licensee utilized National Weather Service (NWS) data, which was based on 1985 International Great Lakes Datum (1985 IGLD) to determine the Lake Erie water level reference point. While inspecting the potential impacts of record high Lake Erie water levels, the inspectors discovered a non-conservative 1.3' difference between the two water level reference points.

The flooding design basis as described in the UFSAR ensured that safety-related SSCs would continue to be functional provided the Lake Erie water level was no higher than 575.3 using NYMT data. This accounted for a maximum postulated storm-induced wave surge and flooding to a level of 586.9 NYMT, or 3.9 above the site grade of 583.0. The inspectors reviewed NWS lake level data and discovered the current monthly mean level using 1985 IGLD data was 574.6, and was therefore less than the flooding design basis level of 575.3.

However, since the NYMT Lake Erie water level reference point was 1.3 lower than the NWS Lake Erie water level reference point, after adjusting for this difference, the actual maximum Lake Erie water level in the event of a storm-induced wave surging and flooding was 576.9 NYMT, which exceeded the maximum Lake Erie water level described in the UFSAR. The inspectors discussed the issue with licensee personnel, and the licensee subsequently performed evaluations to assess the actual impact on safety-related SSCs. In addition, the equipment and strategies assumed to be available for beyond-design-basis accidents (i.e.

FLEX equipment) were evaluated. Following these evaluations, and despite the high lake level and Lake Erie water level reference point difference, the licensee determined that safety-related SSCs would continue to be functional.

Regarding the licensees FLEX strategy, which relied upon adequate warning time from the NWS when certain flood levels were predicted, the licensee discovered that the NWS utilized a 1.5 uncertainty when performing lake level predictions. As a result, even with the difference in Lake Erie water level reference points, the plant would have received the prediction for extreme flood levels within a sufficient warning time to implement FLEX strategies.

As a result of the inspection, the licensee revised their Memorandum of Understanding (MOU) with the NWS to incorporate the difference between the datums. The licensee also implemented a monitoring program to ensure future Lake Erie water level increases were closely tracked.

Corrective Actions: The licensee entered this issue into their Corrective Action Program and established a formal monitoring plan to assess lake levels.

Corrective Action References: CARDs 19-25657, 19-25893, and 19-25820

Performance Assessment:

Performance Deficiency: The failure to develop appropriate measures to assess compliance with the flooding design and licensing basis, and to ensure an appropriate warning was received from the NWS to implement certain FLEX strategies was a performance deficiency.

Specifically, the difference in reference datum between site design documents and Lake Erie water level measurements was not accounted for.

Screening: The inspectors determined the performance deficiency was more than minor because if left uncorrected, it would have the potential to lead to a more significant safety concern. Specifically, a misunderstanding of current or predicted Lake Erie water level could result in the plant being in a condition outside its design and licensing basis, inoperable safety-related equipment, or an inability to perform response actions as planned for extreme flooding conditions. The inspectors consulted IMC 0612, Appendix E, Examples of Minor Issues, Examples 3j and 3k and the associated Note that followed these examples.

Specifically, when errors are discovered regarding design assumptions, if reasonable doubt exists as to the operability of safety-related SSCs (regardless if they are later determined operable), the issues can be considered more than minor. For this issue, reasonable doubt existed regarding safety-related SSCs because with the datum difference that existed in Lake Erie water level measurement the licensee was not within the design and licensing basis for flood protection.

Significance: The inspectors assessed the significance of the finding using Appendix A, The Significance Determination Process (SDP) for Findings At-Power. The inspectors also consulted Appendix O, Significance Determination Process for Mitigating Strategies and Spent Fuel Pool Instrumentation. Based on actual Lake Erie levels, the finding screened as having very low safety significance (i.e., Green), because there was no loss of safety function for any of the safety-related SSCs. Further, no issues with implementation of the licensees FLEX strategy were identified.

Cross-Cutting Aspect: Not Present Performance. No cross cutting aspect was assigned to this finding because the inspectors determined the finding did not reflect present licensee performance.

Enforcement:

Violation: Title 10 CFR 50, Appendix B, Criterion III, Design Control, requires, in part, that measures shall be established to assure that the applicable regulatory requirements and the design basis, as defined in Part 50.2 and as specified in the license application, for those SSCs to which this Appendix applies, are correctly translated into specifications, drawings, procedures, and instructions.

Contrary to the above, since issuance of the Fermi 2 Operating License on July 15, 1985, until July 12, 2019, the licensee failed to establish measures to assure that regulatory requirements and the design basis were correctly translated into specifications, procedures, or instructions. The licensee utilized information from the National Weather Service to receive notifications of flood watches and warnings that were inconsistent with the methodology used in the UFSAR flooding design basis, without compensation for the existing difference in Lake Erie water level reference points being used. As a result, actual Lake Erie water levels were identified to be 1.3 higher at the site than reported, which could challenge safety-related SSCs.

Enforcement Action: This violation is being treated as an non-cited violation, consistent with Section 2.3.2 of the Enforcement Policy.

Inadequate Response to an Out-of-Service Diesel Fire Pump Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green [H.5] - Work 71111.18 Systems NCV 05000341/2019003-02 Management Open/Closed A self-revealed finding of very low safety significance (i.e., Green) and an associated Non-Cited Violation (NCV) of Fermi License Condition 2.C.(9) was identified when licensee personnel failed to take appropriate actions in response to an out-of-service diesel fire pump.

Specifically, a temporary diesel fire pump (DFP) used to restore system functionality failed to function as designed and the risk plan that was developed could not be implemented as written.

Description:

On August 13, 2019, the licensee entered Technical Requirements Manual (TRM) Action 3.12.2 A.1 due to planned maintenance on the DFP. The TRM required either the pump to be restored or an alternate pump to be installed within 14 days. Upon discovery of extensive wear on components associated with the DFP right angle drive, the licensee concluded that the DFP would not likely be restored within 14 days. The licensee initiated actions to procure an alternate DFP to comply with the TRM requirements and restore full system capabilities. The licensee received and installed a temporary diesel-driven fire pump and exited the TRM action within the 14 day action requirement on August 27, 2019. On September 3, 2019, the licensee initiated a weekly test to operate the temporary DFP.

Approximately 10 minutes after the pump was started, pump coolant was observed to be leaking from the temporary fire pump. The pump was immediately shut down by the operators. Upon investigation, the licensee believed either the coolant had been overfilled and/or the engine had overheated. It was also noted that during the test the pump had been running with no system demand (i.e. dead-headed) during test preparations. After consulting with the vendor, the licensee determined that the pump should have had a minimum flow line installed to prevent damage from overheating under low-demand conditions. While the temporary pump did include a relief valve on the pump discharge, the system did not function in the same manner as the relief valve on the permanent pump, which provided both relief and minimum flow functions during pump operation.

In addition, the licensees risk plan to operate with a single electric pump available (pending re-design/re-work of the temporary DFP following this issue) relied upon power being available from the Combustion Turbine Generators (CTGs) in the event of a loss of offsite power. However, the licensee had removed all CTGs from service for planned maintenance.

As a result of these issues, the licensee coordinated with the temporary pump vendor to enable its relief valve to also function as a minimum flow line. Additionally, the licensee revised the risk plan to incorporate other strategies while the CTGs were out of service.

Corrective Actions: The licensee added a functional minimum flow line and revised the risk plan to ensure all elements of the plan could be performed.

Corrective Action References: CARDs 19-26837, 19-26615, and 19-26603

Performance Assessment:

Performance Deficiency: The failure to take necessary actions to minimize fire risk and perform repairs as soon as practical when fire equipment was taken out of service, as required by the fire protection program, was a performance deficiency. Specifically, fire risk was not minimized, and restoration of system capability was not timely when a temporary fire pump was installed with an inadequate design. Further, fire risk was not minimized when the risk plan that was developed could not be implemented as written due to credited backup power not being available.

Screening: The inspectors determined the performance deficiency was more than minor because it was associated with the Protection Against External Factors attribute of the Mitigating Systems cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, the availability, reliability, and capability of the fire protection system was adversely impacted by the installation of a temporary DFP that could not function as designed. Further, although normal power was available, the risk plan also relied upon a backup source of power that was not available had it been needed.

Significance: The inspectors assessed the significance of the finding using Appendix F, Fire Protection and Post - Fire Safe Shutdown SDP. The finding screened as having very low safety significance (i.e., Green) based on answering Yes to Question 1.4.3-A, which asked whether or not adequate fire water capacity still existed for equipment important for safe shutdown. In this case, the electric fire pump was still functional with normal power available.

Cross-Cutting Aspect: H.5 - Work Management: The organization implements a process of planning, controlling, and executing work activities such that nuclear safety is the overriding priority. The work process includes the identification and management of risk commensurate to the work and the need for coordination with different groups or job activities. Specifically, the licensee did not coordinate with the pump vendor to ensure all necessary plant technical requirements were incorporated into the design of the temporary fire pump. Further, site personnel with expertise in engineering modifications were not initially involved to ensure all technical requirements were incorporated into the design of the temporary fire pump.

Enforcement:

Violation: Fermi License Condition 2.C.(9) requires, in part, that the licensee shall maintain in effect all provisions of the approved fire protection program as described in the UFSAR. Section 9A.1.3.2.i of the Fermi UFSAR described the components of the fire protection program and required, in part, that assurance will exist that, actions are taken to minimize fire risk and repairs are made as soon as practical when fire equipment is taken out of service.

Contrary to the above, from August 27, 2019, until September 17, 2019, actions were not taken to minimize fire risk, nor were repairs made as soon as practical when the permanent diesel fire pump was out of service as required by Fermi License Condition 2.C.(9) as specified in UFSAR Section 9A.1.3.2.i. Specifically, a temporary diesel fire pump was installed that lacked a functional minimum flow line, which resulted in the pump failing its first weekly surveillance. This required extensive re-design, during which time the plant fire response capability was reduced to a single fire pump. Additionally, fire risk was not minimized because the fire risk plan that was developed for operating with only a single fire pump could not be implemented as written since backup power that was credited in the fire risk plan was not available.

Enforcement Action: This violation is being treated as an non-cited violation, consistent with Section 2.3.2 of the Enforcement Policy.

Observation: Trend in Incorrect Parts Issued or Ordered 71152 During a semi-annual trend review, the inspectors noted that a large number of CARDs initiated since January 2019 identified incorrect parts that had been ordered or issued for work. The inspectors shared this observation with licensee staff who agreed that it appeared a trend existed. The licensee initiated CARD 19-27102 as a result of the inspectors observations to document five recent issues. During further discussions with the licensee, the inspectors noted that 12 additional CARDs dating back to January 2019 also identified issues with incorrect parts. Within this group of CARDs, and upon further review, the licensee discovered a potential adverse trend within one particular department. In reviewing the CARDs, the inspectors also noted an inconsistent use of cause-codes within the CARDS to describe the various parts issues. In some cases, no cause-codes were assigned at all.

As such, the failure to utilize a consistent method of assigning cause codes to CARDs could result in plant personnel missing opportunities to identify trends before they become larger concerns. At the end of the inspection period, the licensee planned to further assess this issue.

Observation: Failure to Address a Trend in the Storage of Quality Material 71152 During a semi-annual trend review, the inspectors reviewed Elevation CARD 19-21685 from the sites Nuclear Quality Assurance (NQA) organization regarding the storage and staging of parts. The inspectors had also noted what appeared to be a number of CARDS written throughout the year that addressed the improper storage and handling of materials. The NQA Elevation CARD documented numerous recurring issues with the storage and handling of quality material that dated back to 2015, along with some more recent issues. The inspectors reviewed several of the actions that resulted from the Elevation CARD and from previous NQA audits. One of the primary issues was the discovery that quality and non-quality material were not being stored in accordance with plant procedures. In particular, parts had been issued, not used, and then not properly returned to the warehouse within the procedurally required timeframe, which increased the likelihood that material traceability could be lost and/or parts could be stored in an uncontrolled environment. From an NQA audit finding identified in CARD 15-22778, the licensee implemented a corrective action which established a recurring activity to periodically inspect areas of the plant where improperly stored material was being found (i.e., PST [Performance Scheduling and Tracking] events). The inspectors discovered that while the PSTs were being performed and generally found no issues, NQA continued to identify that parts were stored inappropriately, which eventually resulted in the Elevation CARD. While discussing the PST events with the inspectors, the licensee also identified that there was an allowance for the return of improperly stored material to the warehouse of up to 60 days, contrary to the site procedural requirements of 7 days (online work) or 30 days (outage work). Further, the licensee identified that the PST events did not require a check of non-quality material being stored improperly, which had also been identified as an issue. The licensee initiated a CARD to address the issues with how the PSTs were written.

The inspectors also reviewed an Interim Effectiveness Review (IER) that the licensee performed to support closure of the NQA Elevation CARD. This IER was completed on August 30, 2019, and concluded that actions associated with the Elevation CARD had been performed satisfactorily. However, on August 14, 2019, NQA denied a request to close the CARD based on the identification of continuing issues with the storage of material and the failure to correctly follow the appropriate process for closing NQA Elevations. As of October 3, 2019, the inspectors noted there had been no additional actions created to address the failure to close the NQA Elevation CARD, or develop a revised action plan to measure the effectiveness given the apparent discrepancy between the conclusion of the IER and NQAs assessment regarding the effectiveness of the corrective actions that had been performed.

Failure to Properly Pre-Plan Work in Accordance with the Work Control Conduct Manual Cornerstone Significance Cross-Cutting Report Aspect Section Barrier Integrity Green [H.7] - 71153 FIN 05000341/2019003-03 Documentation Open/Closed A self-revealed finding of very low safety significance (i.e., Green) was identified when the licensee failed to properly pre-plan maintenance activities on the Feedwater Distributed Control System in accordance with the Work Control Conduct Manual. This resulted in an unplanned loss of the gland seal exhauster trip safety function.

Description:

On January 1, 2019, during reactor startup and at approximately 5 percent rated thermal power, the licensee began a planned maintenance activity to correct a failed main steam line flow indication associated with the digital Feedwater Distributed Control System (FW DCS).

This maintenance included performing a full system reboot of FW DCS. Before the maintenance was performed, the licensee attached an impact statement to the work order, as required by Work Control Conduct Manual (MWC) 10, Revision 39. Specifically, Step 4.40.1 of the MWC required, in part, In Maximo [the work order system software], under the safety/impact tab for Work Order, and under the impact statement section, provide the following: affected modes, Technical Specifications, technical requirements, expected alarms, precautions including system component status, any requirements prior to tagging, prohibited parallel work, trips/actions including trip(s) and action(s) to prevent, indications/actuations including indication(s) and actuation(s), system impact/PMT [post maintenance testing]

including plant system impact, system impact. However, the licensee failed to include information regarding the rod worth minimizer (RWM) and the turbine gland seal exhauster (GSE) trip in the impact statement that should have been included. When reviewing the work order prior to performing the maintenance activity, the Operations crew on shift noted the impact statement was missing a reference to the Technical Specifications for the RWM. As a result, the licensee was able to be prepared for the impact of the work on the RWM and enter the appropriate Technical Specification (TS) Limiting Condition for Operation (LCO).

However, the licensee failed to identify that the GSE trip function was also impacted, and therefore during the maintenance activity did not enter the associated TS LCO required action.

The GSE trip function is relied upon between 0 and 10 percent rated thermal power to ensure that dose limits do not exceed regulatory limits during a control rod drop accident. The impact to the GSE trip function when resetting the FW DCS resulted from a modification that was installed during the most recent refueling outage in October 2018. Therefore, resetting the FW DCS would not have previously impacted the GSE trip.

When FW DCS was reset, annunciator 4D32, MSL [Main Steam Line] Radn [Radiation] Mon

[Monitor] GS [Gland Seal] STM [Steam] EXHS [Exhaust] Trip Enabled, cleared and unexpectedly re-alarmed in the control room. Operators subsequently determined that the GSE trip function was disabled during the reset of FW DCS, which lasted approximately 1 minute and 19 seconds. As a result, the licensee submitted (EN) 53811 pursuant to 10 CFR 50.72(b)(3)(v)(C) and 10 CFR 50.72(b)(3)(v)(D) as 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: 1) control the release of radioactive material, and 2) mitigate the consequences of an accident, respectively. On March 1, 2019, the licensee submitted Licensee Event Report (LER) 05000341/2019-001-00 for this event.

The licensee performed a causal evaluation and determined that the cause of the event was that the Failure Modes Effect and Analysis (FMEA) discussion in the engineering modification package did not specifically identify a loss of FW DCS as a failure mode for the GSE trip. In addition, the inspectors noted that Section 4.40, Work Order Safety/Impact Section Completion, of MWC 10 did not include suggested reference documentation for Operations personnel to review. As a result, the inspectors questioned the licensee as to what documentation was reviewed when generating the impact statement. The licensee stated a review of previous FW DCS work orders and impact statements, and the applicable FW DCS procedures was completed. Additionally, when reviewing corrective actions, the inspectors questioned whether all relevant documents were fully updated and if any additional failure modes were evaluated. Upon further review, the licensee determined additional documents were required to be updated to include information regarding the impact of the FW DCS on the GSE trip function. Also, the licensee determined there was a lack of alignment between the causal evaluation and correction actions, such that a review of additional failure modes was not performed to address the FMEA gap that was identified.

Corrective Actions: The licensee entered the issues into their Corrective Action Program.

Planned corrective actions included updating additional applicable procedures and design documents with the relevant GSE trip information and evaluating the lack of alignment between the causal statement and corrective actions.

Corrective Action References: CARDs 19-27084 and 19-26836

Performance Assessment:

Performance Deficiency: The licensees failure to properly pre-plan maintenance activities on the FW DCS in accordance with the Work Control Conduct Manual was a performance deficiency. Specifically, the licensee failed to evaluate the impact of FW DCS on the GSE trip instrumentation, which resulted in the unplanned loss of the GSE trip safety function.

Screening: The inspectors determined the performance deficiency was more than minor because it was associated with the SSC and Barrier Performance attribute of the Barrier Integrity cornerstone and adversely affected the cornerstone objective to provide reasonable assurance that physical design barriers protect the public from radionuclide releases caused by accidents or events.

Specifically, the licensee disabled the GSE trip when the function was required. Without mitigating actions, the failure to trip the GSEs could have resulted in a dose above regulatory requirements if a control rod drop accident had occurred. Therefore, the required barrier was adversely impacted.

Significance: The inspectors assessed the significance of the finding using Appendix A, The Significance Determination Process (SDP) for Findings At-Power. The inspectors determined that the performance deficiency affected the Barrier Integrity cornerstone. The finding was determined to be of very low safety significance (i.e., Green), because the inspectors answered Yes to the question, Does the finding only represent a degradation of the radiological barrier function provided for the control room, or auxiliary building, or spent fuel pool, or SBGT [Standby Gas Treatment ] system (BWR)? in Exhibit 3, Barrier Integrity Screening Questions.

Cross-Cutting Aspect: H.7 - Documentation: The organization creates and maintains complete, accurate and up-to-date documentation. The licensee failed to create and maintain complete, accurate and up-to-date documentation. Specifically, the licensees engineering design change document failed to completely identify all failure modes. Additionally, the licensee failed to update documentation associated with the FW DCS and GSE systems when implementing the plant modification in 2018, which could have aided in the licensees system impact evaluation.

Enforcement:

Because the Work Control Conduct Manual was not subject to the requirements of 10 CFR 50, Appendix B, Quality Assurance Criteria for Nuclear Power Plants and Fuel Processing Plant, the inspectors did not identify a violation of regulatory requirements associated with this finding.

EXIT MEETINGS AND DEBRIEFS

The inspectors verified no proprietary information was retained or documented in this report.

• On October 16, 2019, the inspectors presented the integrated inspection results to Mr. P. Dietrich, Senior VP and Chief Nuclear Officer, and other members of the licensee staff.

• On July 18, 2019, the inspectors presented the Radiaton Protection inspection results to Mr. M. Caragher, Executive Director - Nuclear Production, and other members of the licensee staff.

DOCUMENTS REVIEWED

Inspection Type Designation Description or Title Revision or

Procedure Date

71111.01 Corrective Action 19-25280 NRC Identified: Local Lake Level Indication Reads Higher 07/12/2019

Documents than UFSAR Assumed Maximum Starting Level for Flood

19-25458 Determine Impact of CARD 19-25280 and EFA-A30-19-007 07/18/2019

on FLEX and Hardened Vent Required Equipment in MOP25

19-25657 AOP 20.000.01 MOU for Flooding is Not Specific in Datum 07/29/2019

Reference

19-25893 Flood Analysis Past Functionality of FLEX Strategy in 08/05/2019

Reverence to CARD 19-25657

Miscellaneous Adverse Lake Erie Water Level Elevation

Condition

Monitoring Plan

ACMP 19-016

IGLD 1985 Brochure on the International Great Lakes Datum 1985 01/1992

NARP-18-0277 Letter of Agreement Between Fermi 2 and NOAA - National 11/19/2018

Weather Service

NARP-19-0140 Letter of Agreement Between Fermi 2 and NOAA - National 07/31/2019

Weather Service

National Ocean History and Theory of Datum Planes of the Great Lakes

Survey, Detroit,

Michigan

TE-K11-19-039 Impact of Incorrect Datum Reference Used for Design 0

Maximum Flood Level on Past Functionality of FLEX/HCVS

(CARD 19-25657)

Procedures 20.000.01 Acts of Nature 0, 48, 49, 54

29.400.01 FLEX 3

ARP 7D22 General Service H2O Screen a H2O Level High/Low 21

MOP01-200 Severe Weather Guidelines 2

MOP25 Beyond-Design-Basis Event Coping Strategies Program 5

Document

Work Orders 38560633 Lube and Inspect Reactor/Auxiliary Building Water Tight 07/16/2014

Doors

Inspection Type Designation Description or Title Revision or

Procedure Date

71111.04Q Corrective Action 05-24306 Add Electric Fire Pump to DC-6105, Dedicated Shutdown for 07/20/2005

Documents Appendix R Loads

18-28658 Discharge Pressure Above Normal Parameters 10/23/2018

Drawings 6M721-2034 Diagram Core Spray System C.S.S. Reactor Building AS

6M721-5707 Core Spray System Functional Operating Sketch AG

6M721-5730-3 Non-Interruptible Control Air System Division I & II AL

Functional Operating Sketch

6M721-5734 Emergency Diesel Generator System Functional Operating BH

Sketch

6M721N-2046 P&ID Diesel Generator System Division I RHR Complex AF

6M721N-2048 P&ID Diesel Fuel Oil System and Lube Oil System Division I AL

RHR Complex

Miscellaneous T13019 Temporary Change Notice - Fire Water Suppression System 61

Procedures 23.129 NIAS Divisions 1 and 2 Control Air Startup 117

23.203 Core Spray System 64

23.307 Emergency Diesel Generator System 127

28.504.03 Fire Suppression Water System Simulated Automatic 28

Activation Test

Work Orders 49771706 Perform 28.504.09 Electric Fire Pump Monthly Operability 07/02/2019

Test

50002740 Perform 28.504.09 Electric Fire Pump Monthly Operability 07/30/2019

Test

71111.04S Drawings 6M721-5357 Emergency Equipment Cooling Water System Division II BU

6M721-5444 Emergency Equipment Cooling Water System Division I CC

Procedures 23.127 Reactor Building Closed Cooling Water/Emergency 145

Equipment Cooling Water System

71111.05Q Corrective Action 19-24505 2019 Fire Protection Self-Assessment Deficiency - 06/13/2019

Documents Investigate GSW Fire Rated Assemblies to be Included into

TRM 3.12.8

19-26383 Diesel Fire Pump Room Fire Doors were Found Blocked 08/23/2019

Open Without a Fire Impairment

19-26426 Need DCR for Diesel Fire Pump Procedures to Address Log 08/26/2019

Entry while Fire Doors to Diesel are Open

Fire Plans FB-AB-5-16b Auxiliary Building, South Standby Gas Treatment System 3

Inspection Type Designation Description or Title Revision or

Procedure Date

(SGTS) Room, Zone 16, EL. 6776

FP-AB-5-16a Auxiliary Building North Standby Gas Treatment (SGTS) 4

Room, Zone 16, Elevation 6776

FP-AB-5-16b Auxiliary Building, South Standby Gas Treatment System 3

(SGTS) Room, Zone 16, Elevation 6776

Miscellaneous 9A.4-44 Fermi 2 UFSAR 22

TR 3.12.8 Fire Protection Fire Rated Assemblies 78

Procedures 28.502.02 CO2 System Valve Lineup Verification 8

35.000.242 Barrier Identification/Classification 57

FP-AB-BMT-4 Control Air Compressor Room, Zone 4 Elevation 5510 4

FP-GSW-1-31 General Service Water Pumphouse Zone 31 8

FP-RB-B-5b Reactor Building Basement Northeast Corner Room Zone 5, 4

Elevation 5620

FP-RB-SB-5a Reactor Building Sub-Basement Northeast Corner Room, 6

Zone 5, Elevation 5400

Work Orders 47714949 Perform 28.502.18 Division 1 SGTS CO2 Actuation Test 12/13/2018

48565671 Perform 28.502.18 Division 2 SGTS CO2 Actuation Test 01/31/2019

71111.06 Calculations DC-5426 PBOC - High and Moderate Energy Line Break Evaluation D

Corrective Action 19-23894 NRC Identified Concern: Housekeeping in Torus 05/21/2019

Documents

Drawings 29.100.01 SH 5 Secondary Containment and Radiation Release 12

6A721-2000-01 Reactor Building Sub-Basement Plan Elevation 5400 Scale M

1/8=1-0

6A721-2000-02 Reactor Building Basement Plan Elevation 6520 N

6M721-2032 Sump Pump Diagram Radwaste System BR

6M721-2224 Diagram Floor Drains All Floors Auxiliary and Reactor AA

Buildings

7M721-2218 Floor and Equipment Drains Sub-Basement Plan Reactor Y

Building

Procedures ARP 2D82 Reactor Building Torus Sump Level Hi-Hi/Lo-Lo 11

ARP 2D83 Reactor Building Leakage to Torus Sump High 7

71111.11Q Miscellaneous Reactivity September 2019 RPA 0

Maneuvering Plan

Inspection Type Designation Description or Title Revision or

Procedure Date

SS-OP-904-1903 Evaluation Scenario 0

Procedures MOP19 Operations Conduct Manual, Reactivity Management 26A

71111.13 Corrective Action 19-26718 Minimum Flow Line for Alternate Diesel Fire Pump Detached 09/07/2019

Documents from Pump Discharge Line

19-26837 CTG Black Start Capability Removed When Relied Upon for 09/11/2019

FPEE-19-0003

Drawings 6M721-5444 Emergency Equipment Cooling Water Division 1 CC

Miscellaneous EF2-PRA-005.11 High Pressure Coolant Injection (HPCI) System - System 3

Information Notebook

MMR12 Equipment Out of Service Risk Management 20

ODE-20 Protected Equipment 24

Procedures 20.300.120kV Loss of 120kV 19

20.300.SBP Loss of Offsite and Onsite Power 28

23.202 High Pressure Coolant Injection System 116

23.206 Reactor Core Isolation Cooling System 103

23.208 RHR Complex Service Water Systems 126

23.501.01 Fire Water Suppression System 61

MMR App H On-Line Core Damage Risk Management Guidelines 15

MMR12 Equipment Out of Service Risk Management 20

MOP05-100 Protected Equipment 2C

ODE-20 Protected Equipment 24

71111.15 Calculations DC-0623 Standby Liquid Control System Design Calculations A

DC-4997 Standby Liquid Control Instrumentation Surveillance D

Calibration

DC-4997 SLC Design Value Changes to Meet Power Uprate/Higher 0

Energy Cycles

DC-5961 WS01 Boron Injection Variables 0

DC-5962 WS01A Boron Weight Equivalents 0

Corrective Action 16-26260 Diesel Fire Pump Angle Drive Inspection Findings 08/09/2016

Documents 19-21369 Tech Spec 3.1.7 Figure 1 SLC Tank Level Limits Potentially 02/21/2019

Non-Conservative

19-24615 Diesel Fire Pump Engine SWI>Action Level B 06/18/2019

Inspection Type Designation Description or Title Revision or

Procedure Date

19-25694 TRM Surveillance Requirement 3.6.1.1 Not Referenced in 07/29/2019

Procedure or SST Event and Potentially Not Performed in

RF19

19-26111 Condition of the DFP Right Angle Anti-Rotational Clutch 08/13/2019

19-26174 RCIC Flow Controller Issue Unable to be Resolved Under 08/15/2019

WO 53945247

19-26186 Lack of Follow-Through on a Known Component Degraded 08/16/2019

Condition

19-26198 RCIC Flow Issue 08/16/2019

19-26237 Missing Bolts in DFP Right Angle Drive 08/19/2019

19-26362 While Performing 44.010.143 Division 2 RPS Two Out of 08/22/2019

Four Logic Module Functional Test on APRM 2 OPRM Trip

Light Did Not Come On Nor Did RPS Test Box Light Come

On (Both Acceptance Criteria)

19-27084 Review and Address CARD Quality Issues with CARD 19- 09/20/2019

20002

Drawings 107E5901WH C5100, C51R809A & B 0

107E5901WH Two-Out-Of-Four Logic Module 1

29.100.01 SH 1A RPV Control - ATWS 16

29.100.01 SH 3A RPV Flooding & Emergency Depressurization - ATWS 16

6I721-2145-18 Schematic Diagram Power Range Neutron Monitoring H

Reactor Protection System Outputs

6I721-2155-04 Schematic Diagram Reactor Protection System Relay X

Tabulation

6I721-2155-07 Schematic Diagram Reactor Protection System Trip System X

B System Relays

6I721-2155-08 Schematic Diagram Reactor Protection System Trip System M

A Scram Trip Logic

6I721-2155-10 Schematic Diagram Reactor Protection System Scram N

Solenoids

6I721-2235 RCIC System Instrumentation Loop W

6I72102155009 Schematic Diagram Reactor Protection System Trip System M

B Scram Trip Logic

6M721-2034 Core Spray System C.S.S. Reactor Building AS

Inspection Type Designation Description or Title Revision or

Procedure Date

6M721-2044 Reactor Core Isolation Cooling System BE

6M721-2045 Reactor Core Isolation Cooling (RCIC) System Barometric AS

Condenser

Miscellaneous MQA13-100 Quality Assurance Conduct Manual, Trend Condition 7

Evaluation Report

TE-P80-19-035 Condition of the Diesel Fire Pump Right Angle Drive 0

Procedures 44.110.004 Remote Shutdown RCIC Flow Indication Calibration 39

Work Orders 53945247 RCIC Pump Discharge Flow Transmitter Elec

71111.18 Corrective Action 19-27387 Alternate Diesel Fire Pump Trip during Weekly Surveillance 09/30/2019

Documents Run

Drawings 6I721-2080-51 Visual Annunciator & Sequence Recorder Alarm Schematic V

6I721-2125-06 Control System Feedwater (DCS-FW) External Connections H

6I721-2331-07 Schematic Diagram Gland Sealing Steam Exhauster (E&W) G

6M721-5733-1 Fire Protection Functional Operating Sketch BX

Engineering 19-0014 Alternate Diesel Fire Pump (ADFP) C

Changes

Engineering FPEE-19-003 TR LCO 3.0.3 Evaluation for the Non-Functional Diesel Fire 1

Evaluations Pump TRM Section TR3.12.2

Miscellaneous EDP-37673 EDP Continuation Sheet - Scope of Work 0

Fermi 2 UFSAR Other Auxiliary Systems 22

LRN-01-0410, Letter to NRC from PSEG Nuclear LLC, Request for Change 01/04/2002

LCR H01-03 to Technical Specifications Mechanical Vacuum Pump Trip

Instrumentation Hope Creek Generating Station Facility

Operating License NPF-57 Docket No. 50-354

Work Request PMT and TRSR Verification for TM 10-0014, Revision E 1

Revision

55179348

Procedures 28.504.03 Fire Suppression Water System Simulated Automatic 28

Actuation Test

Work Orders 54828250 TM 19-0014, Install Alternate Diesel Fire Pump at Pump 08/16/2019

House

54938127 Perform Temporary Diesel Fire Pump Weekly Operability 09/12/2019

Test

71111.19 Corrective Action 19-25181 Schedule Adherence A Work Not Completed as Scheduled 07/09/2019

Inspection Type Designation Description or Title Revision or

Procedure Date

Documents 19-26850 CTG 11-1 Lube Oil Leak 09/12/2019

19-26876 CTG 11-1 DC Power Supply Failure Alarm During SOP Run 09/12/2019

Drawings 6I721-2095-14 Schematic Diagram Nuclear Steam Supply Shut Off System O

Trip System A

6I721-2095-18 Schematic Diagram NSSS System Main Steam Line S

Outboard Isolation Valves B2103F028A, B, C, D

6I721-2155-22 Schematic Diagram Reactor Protection System Testability L

Modification

Engineering 70056 CTG 11 Fuel Oil Tank Replacement C

Changes

Miscellaneous Fermi 2 Archived Operator Log 09/24/2019 -

09/26/2019

NRC-02-0036 Letter from Detroit Edison to NRC: Proposed Technical 05/23/2002

Specification Change (License Amendment) - Response

Time Testing

Procedures 23.324 Supervisory Control-120 KV Switchyard and CTG 11 99

Generators

23.601 Instrument Trip Sheets 39

35.318.017 Inspection and Testing of Multi-Contact Auxiliary Relays 52

44.020.011 Response Time Test of B21-N081A Reactor Vessel Low 46

Water Level 1 Transmitter

Work Orders 45299261 Replace RPS Channel A2 Reactor Vessel Level 1 and 2 07/09/2019

Agastat Relays

46187487 Replace Desiccant in Division 2 NIAS Dryer 09/24/2019

244081 Change Crankcase Oil, Inspect Belts, Lube Motor Bearings, 09/12/2019

and Clean Exterior

50349443 Clean and Inspect CTG 11-1 Water Cooler and Inspect 04/02/2018

Cooler Belts

50349457 Calibrate 63HR Hydraulic Ratched Pressure Switch on CTG 04/02/2018

11-1

50349598 Semi-Annual Inspection of CTG 11-1 04/02/2018

50452150 Piping Tie In (FOST) 04/15/2018

54721898 CTG 11-1 Liquid Fuel Pump Bypass Servo Valve is Leaking 08/06/2019

Fuel Oil While CTG is Operating

Inspection Type Designation Description or Title Revision or

Procedure Date

55165181 Repair CTG 11-1 Lube Oil Leak 09/12/2019

71111.22 Corrective Action 17-26455 Procedure Revision for LPCI Swing Bus Surveillance 08/01/2017

Documents 24.321.07

19-26353 HPCI Barometric Condenser Vacuum Pump Flashing Amps 08/22/2019

Drawings 6I721-2573-11 Schematic Diagram 480V Essential Bus 72C Position 3C & Q

MCC 72C-F Position 1C

6M721-2035 High Pressure Coolant Injection System (HPCI) Reactor BN

Building

6M721-2043 High Pressure Coolant Injection System Barometric AJ

Condenser (HPCI) Reactor Building

6M721-2083 Residual Heat Removal (RHR) Division 2 CB

6SD721-2510-01 One Line Diagram 480V Essential Bus 72B, 72C, 72E, and BA

2F

Miscellaneous DC-0367 Pump Curves and Requirements, Volume 1 Q

Procedures 23.307 Emergency Diesel Generator System 126

24.202.01 HPCI Pump and Valve Operability Test at 1025 PSI 119

24.204.06 Division 2 LPCI and Suppression Pool Cooling/Spray Pump 79

and Valve Operability Test

24.307.33 Emergency Diesel Generator No. 14-24 Hour Run Followed 41

by Hot Fast Restart

Work Orders 48747466 Perform 24.404.06 Division 2 LPCI and Torus Cooling/Spray 03/01/2019

Pump and Valve Operability Test

49471252 Perform 24.204.06 Division 2 LPCI and Torus Cooling/Spray 05/30/2019

Pump and Valve Operability Test

49759149 Perform 24.321.07 480V Swing Bus 72 CF Automatic 07/08/2019

Throw-Over Scheme Operability

244112 Perform 24.202.01 HPCI Pump/Flow Test and Valve Stroke 08/20/2019

at 1025 PSIG

298122 Perform 24.204.06 Division 2 LPCI and Torus Cooling/Spray 08/21/2019

Pump and Valve Operability Test

71124.08 Corrective Action CARD 18-21171 Dose Estimate Exceeded When Loading 8-120 Liner for 02/12/2018

Documents Transportation

CARD 18-22666 Vendor Box Arrived on Site as a Non-Radioactive Shipment 03/30/2018

With a RAM Tag

Inspection Type Designation Description or Title Revision or

Procedure Date

CARD 18-23247 Telepole Failed Source Check Following RAM Shipment 04/22/2018

Receipt

Corrective Action CARD 19-25399 NRC Identified - Repairs to Spent Resin Tank Required 07/17/2019

Documents

Resulting from

Inspection

Miscellaneous NPRP-19-0016 Scaling Factors Report Dated February 4, 2019 02/14/2019

Procedures 65000.506 Shipping Low Specific Activity (LSA) Radioactive Material 22

65000.509 Shipping Greater Than A1, A2 Quantities of Radioactive 20

Material

65000.510 Shipping Limited Quantity of Radioactive Material 25

65000.610 Shipping Cask USA/9168/B(U) 22

Shipping Records EF2-17-136 Dewatered Resin Liner, LH-16-017 01/12/2018

EF2-18-003 Dewatered Resin Liner, LH-16-007 01/19/2018

EF2-18-009 Dewatered Resin Liner, LH-17-005 02/12/2018

71151 Corrective Action 19-27175 NRC Identified Typographical Error in RCIC Monthly 09/24/2019

Documents Performance Indicator

Resulting from

Inspection

Miscellaneous MSPI Derivation Report - Cooling Water System- 06/30/2019

Unavailability Index

Fermi 2 RHR Performance Indicators 08/01/2018 -

07/31/2019

MSPI Derivation Report - Residual Heat Removal System- 06/30/2019

Unreliability Index

MSPI Derivation Report - Residual Heat Removal System- 06/30/2019

Unavailability Index

Fermi 2 RCIC Performance Indicators 07/01/2018 -

06/30/2019

MSPI Derivation Report - Heat Removal Systems- 06/30/2019

Unreliability Index

N/A Monthly Performance Indicator Submittal to the NRC for 07/01/2018 -

Occupational Exposure Control Effectiveness 06/01/2019

N/A Monthly Performance Indicator Submittal to the NRC for 07/01/2018 -

Inspection Type Designation Description or Title Revision or

Procedure Date

RETS/ODCM Radiological Effluent Occurrences 06/01/2019

N/A Monthly Performance Indicator Submittal to the NRC for 07/01/2018 -

RCS Specific Activity 06/01/2019

71152 Corrective Action CARD Search Results, Keyword=Incorrect Part 01/01/2019 -

Documents 09/13/2019

19-21685 NQA Elevation - Leaders Actions Have Been Insufficient in 03/05/2019

Correcting Fundamental Worker Behaviors for the Control

and Traceability of Safety-Related Material, Parts, and

Components

19-21750 OSC Cognitive Trend in Supply Chain Performance Issues 03/06/2019

19-23431 Cognitive Trend: Non-Maintenance Related Rework Events 05/03/2019

Due to Inadequate Engineering Parts Evaluations

19-25682 Late Adds - Material Being Added to Work Orders Inside of 07/29/2019

T10 (Adverse Trends per OSC)

19-27524 NRC Identified Trend - Parts Issues 10/03/2019

Miscellaneous NPMA-16-0040 Effectiveness Review for CARD 15-22778: NQA Audit 04/05/2016

Finding - Safety Related (QA1) and Non-Safety (NQ) Spare

Parts Improperly Maintained

Work Orders 44401214 PM: ME76; Perform MRTW of Unused Q Material from MEP 05/20/2017

Buildings

44477754 PM: ME77; Perform MRTW of Unused Q Material from MOV 05/19/2017

Shop and Building 49

71153 Corrective Action 18-30364 MSL B Flowrate Meter Downscale 12/25/2018

Documents 19-20002 4D32 MSL RADN MON GS STM EXHS Trip Enabled 01/01/2019

Cleared with Power Less Than 10 Percent

19-24865 19-20002-08 Performance Gap Analysis Tracking 06/28/2019

19-26836 NRC Identified 45.618.003 Reactor Feedwater System 09/11/2019

Bailey DCS Maintenance Incomplete Information

19-27084 Review and Address CARD Quality Issues with CARD 19- 09/20/2019

20002

Procedures 20.000.07 Fuel Cladding Failure 25

23.107 Reactor Feedwater and Condensate Systems 149

45.618.003 Reactor Feedwater System Bailey DCS Maintenance 11

ARP 3D82 Main Steam Line CH A/B/C/D Radiation Monitor Hi-Hi 15

Inspection Type Designation Description or Title Revision or

Procedure Date

MES90-119 Preparation and Control of Engineering Design Packages 2

MWC10 Work Control Conduct Manual-Chapter 10, Work Package 39

Preparation

Work Orders 52849877 Main Steam Line Flow Failed for Steam Lines on DCS Flat 01/1/2019

Panel Display, Halt/Restart Both FW DCS Processors

28