IR 05000254/2023010

Comprehensive Engineering Team Inspection Report 05000254/2023010 and 05000265/2023010

ML23352A198
Person / Time
Site:	Quad Cities
Issue date:	12/20/2023
From:	Karla Stoedter NRC/RGN-III/DORS/RPB1
To:	Rhoades D Constellation Energy Generation, Constellation Nuclear
References
IR 2023010
Download: ML23352A198 (1)

Text

SUBJECT:

QUAD CITIES NUCLEAR POWER STATION - COMPREHENSIVE ENGINEERING TEAM INSPECTION REPORT 05000254/2023010 AND 05000265/2023010

Dear David P. Rhoades:

On November 16, 2023, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at Quad Cities Nuclear Power Station and discussed the results of this inspection with Brian Wake, Site Vice President, and other members of your staff. The results of this inspection are documented in the enclosed report.

Four findings of very low safety significance (Green) are documented in this report. Three 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 the 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 Quad Cities Nuclear Power Station.

If you disagree with a cross-cutting aspect assignment or a finding not associated with a regulatory requirement in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the U.S. Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region III; and the NRC Resident Inspector at Quad Cities Nuclear Power Station.December 20, 2023 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 Title 10 of the Code of Federal Regulations 2.390, Public Inspections, Exemptions, Requests for Withholding.

Sincerely, Karla K. Stoedter, Chief Engineering Branch 1 Division of Operating Reactor Safety Docket Nos. 05000254 and 05000265 License Nos. DPR-29 and DPR-30

Enclosure:

As stated

Inspection Report

Docket Numbers: 05000254 and 05000265

License Numbers: DPR-29 and DPR-30

Report Numbers: 05000254/2023010 and 05000265/2023010

Licensee: Constellation Nuclear

Facility: Quad Cities Nuclear Power Station

Location: Cordova, IL

Inspection Dates: October 16, 2023 to November 03, 2023

Inspectors: K. Barclay, Senior Reactor Inspector J. Bozga, Senior Reactor Inspector A. Dahbur, Senior Reactor Inspector M. Gangewere, Reactor Inspector I. Hafeez, Senior Reactor Inspector L. Rodriguez, Senior Reactor Inspector M. Siddiqui, Reactor Inspector

Approved By: Karla K. Stoedter, Chief Engineering Branch 1 Division of Operating Reactor Safety

Enclosure

SUMMARY

The U.S. Nuclear Regulatory Commission (NRC) continued monitoring the licensees performance by conducting a Comprehensive Engineering Team Inspection at Quad Cities Nuclear Power Station, 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

Failure to Determine and Document Operability Associated with Technical Specification 3.2 Power Distribution Limits Following a Failure of the HPCI Flow Controller Cornerstone Significance Cross-Cutting Report Aspect Section Barrier Integrity Green [P.2] - 71111.21M FIN 05000254,05000265/2023010-01 Evaluation Open/Closed The inspectors identified a finding of very low safety significance (Green) for the licensee's failure to determine and document operability associated with Technical Specification (TS)3.2, "Power Distribution Limits," following a failure of the high pressure coolant injection (HPCI) flow controller on September 15, 2023, as required by steps 4.1.5 and 4.1.6 of Procedure OP-AA-108-115, "Operability Determinations (CM-1)." Specifically, the licensee did not evaluate whether the limits in the core operating limits report incorporated in TS 3.2 and the assumptions of the inadvertent HPCI initiation transient analysis continued to be met after the flow controller failure.

Discrepancies Between 250 VDC Calculations and Design Basis Acceptance Criteria Used in Test Procedures Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green [H.14] - 71111.21M Systems NCV 05000254,05000265/2023010-02 Conservative Open/Closed Bias The inspectors identified a finding of very low safety significance (Green) and an associated non-cited violation (NCV) of Title 10 of the Code of Federal Regulations (10 CFR) Part 50,

Appendix B, Criterion III, "Design Control," for the licensees failure to ensure that values used in battery calculations were consistent with the design values specified in the updated final safety analysis report (UFSAR) and test procedures. Specifically, the licensee failed to: (1)incorporate the measured armature current values of direct current (DC) motors used in design basis Calculation QDC-8350-E-2348 into work orders and test procedures, and (2) use the design basis minimum required voltage value of 210 volts DC (VDC) specified in the UFSAR to perform the voltage drop calculation for the 250 VDC motor operated valves (MOVs) in Calculation QDC-8350-E-0717.

Failure to Follow Procedural Instructions for Battery Installation Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green [H.5] - Work 71111.21M Systems NCV 05000254,05000265/2023010-03 Management Open/Closed The inspectors identified a finding of very low safety significance (Green) and an associated NCV of 10 CFR 50, Appendix B, Criterion V, Instructions, Procedures, and Drawings, for the licensees failure to correctly install safety-related 125/250 VDC batteries in accordance with prescribed work instructions and drawings. Specifically, the licensee failed to: (1) install foam spacers for the unit 2 250 VDC battery as prescribed in work instructions when installing the battery to ensure the battery's seismic qualifications were maintained, and (2) install jumper cables for the unit 1 125 VDC battery as prescribed in a drawing to ensure the cable bend radii were greater than the minimum required to prevent damage to the cables over time.

Non-conservative Valve Factor Used to Demonstrate Motor Operated Valve 1-1001-23A Continued to be Capable of Performing its Design Basis Safety Functions Cornerstone Significance Cross-Cutting Report Aspect Section Barrier Integrity Green [P.5] - 71111.21M NCV 05000254,05000265/2023010-04 Operating Open/Closed Experience The inspectors identified a finding of very low safety significance (Green) and an associated NCV of 10 CFR 50.55a(b)(3)(ii) for the licensee's failure to establish a program that ensured MOVs continued to be capable of performing their design basis safety functions. Specifically, the licensee incorrectly used a non-conservative valve factor from industry testing as a design input to size and set-up MOV 1-1001-23A instead of using the bounding valve-specific, empirically determined valve factor.

Additional Tracking Items

None.

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 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.

REACTOR SAFETY

71111.21M - Comprehensive Engineering Team Inspection Structures, Systems, and Components (SSCs) (IP section 03.01)

For each SSC sample, the inspectors reviewed the licensing and design bases including: (1)the updated final safety analysis report (UFSAR),

(2) the technical specifications (TS)

(where applicable), and

(3) the technical requirements manual (where applicable). The inspectors also reviewed overall SSC health (including condition reports and operability evaluations, if any). The inspectors performed visual inspections of the accessible SSCs to identify potential hazards or signs of degradation. Additional SSC specific design attributes reviewed by the inspectors are listed below:

(1) Unit 2 Reactor Core Isolation Cooling (RCIC) Pump/Turbine (2-1302/2-1303)

• operating procedures

• environmental qualification

• mechanical design calculations and considerations o flow capacity o minimum flow o required submergence o hydraulic transients o gas intrusion and accumulation o pump cooling o steam supply admission o suppression pool water source temperature and level o turbine trip setpoints o room heat up and cooling

• test and inspection procedures, acceptance criteria, and recent results o pump in-service testing (IST)o TS instrument surveillance for RCIC high area temperature isolation o full of water verification at suction piping and discharge pipe venting

• electrical design calculations and considerations o minimum voltage for RCIC condensate pump

(2) Unit 2 RCIC Turbine Steam Supply Motor Operated Valve (MOV) (2-1301-61)

• operating procedures

• environmental qualification

• mechanical design calculations and considerations o weak link analysis o required thrust and torque o stroke time o maximum differential pressure

• test and inspection procedures, acceptance criteria, and recent results o IST o TS required surveillance

• motor power requirements o required minimum voltage o emergency power (battery)o breaker coordination

(3) 250 VDC Battery 2 (2-8350)

• modifications

• test and inspection procedures, acceptance criteria, and recent results o TS required surveillance o terminal corrosion resistance

• electrical design calculations and considerations o battery sizing o battery loading o short circuit calculation o minimum voltage

(4) Safe Shutdown Makeup Pump (SSMP) (0-2901)

• operating procedures

• maintenance effectiveness

• mechanical design calculations and considerations o flow capacity o minimum flow o required net positive suction head o pump cooling o room heat up and cooling

• test and inspection procedures, acceptance criteria, and recent results o IST o flow capacity test

• electrical design calculations and considerations o protective devices o cable ampacity o minimum voltage o control logic

(5) SSMP Unit 2 Reactor Injection MOV (2-2901-8)

• operating procedures

• maintenance effectiveness

• mechanical design calculations and considerations o weak link analysis o required thrust and torque o stroke time o maximum differential pressure

• test and inspection procedures, acceptance criteria, and recent results o IST

• motor power requirements o control logic o required minimum voltage o protective devices

(6) 125 VDC Turbine Building Reserve Bus 2B-1 (2-8301-2B1)

• modifications

• translation of vendor specifications

• test and inspection procedures, acceptance criteria, and recent results o relay calibration

• electrical design calculations and considerations o breaker coordination calculations o bus capacity o overcurrent protection o cable ampacity

(7) Emergency Diesel Generator (EDG) 2 (2-6601)

• maintenance effectiveness

• modifications

• mechanical design calculations and considerations o fuel oil available volume and consumption o fuel oil transfer design flow capacity net positive suction head o starting air system capacity

• test and inspection procedures, acceptance criteria, and recent results o TS 184 day fast start surveillance o fuel oil day tank level switch functionality o fuel oil transfer pump IST o starting air check valve IST

• electrical design calculations and considerations o fuel oil transfer pump circuitry o starting air circuitry

(8) Bus 24-1 (2-6706-24-1)

• operating procedures

• modifications

• protection against seismic event

• test and inspection procedures, acceptance criteria, and recent results o TS surveillance o relay calibration

• electrical design calculations and considerations o breaker settings and ratings to prevent spurious tripping o breaker control voltage and logic o fast bus transfer scheme o protective devices and trip set points o voltage regulation o bus capacity o surge suppression

(9) Contaminated Condensate Storage Tank (CCST) A/B (0-3303-A/B)

• operating procedures

• maintenance effectiveness

• modifications

• protection against seismic event

• mechanical design calculations and considerations o available and required volume for a station blackout event o level set points o design pressure o overpressure protection o vacuum protection o temperature limits o heat tracing

• test and inspection procedures, acceptance criteria, and recent results o chemistry requirements o temperature o heat tracing o volume o TS surveillances

Modifications (IP section 03.02) (4 Samples)

(1) Engineering Change (EC) 621167, "RCIC Flow Indicating Controllers 1(2)-1340-1 Upgrade," Revision 0

(2) EC 627233, "EOC U-1 Replacement of Merlin Gerin Breakers in Bus 13," Revision 0

(3) EC 630019, "Appendix J Local Leak Rate Testing Scope Reduction for Core Spray, Residual Heat Removal, and Standby Liquid Control Systems - Owner's Acceptance Review," Revision 0

(4) EC 635312, "Minor Revision to QC-429-P-021 for Longer Flex Hose," Revision 0

10 CFR 50.59 Evaluations/Screening (IP section 03.03) (15 Samples)

(1) Evaluation QC-E-2021-001, "Modification to Install Alternate HPCI Signal Converter to Replace Functions of FY 1(2)-2386-A with FY 1(2)-2386-B," Revision 1

(2) Evaluation QC-E-2023-003, "Temporarily Install Alternative Pressure Control Valve Model on U2 EDG Starting Air," Revision 0

(3) Screening QC-S-2017-0081, "Installation and Use of Test Switches in the RCIC Primary Containment Isolation Valve Logic," Revision 0

(4) Screening QC-S-2019-0019, "Install Bypass Switches for -59" Group 1 Main Steam Isolation Valve Isolation," Revision 0

(5) Screening QC-S-2019-0024, "Revise TRM 3.7.b Discussion to Allow Option to Perform Analysis," Revision 0

(6) Screening QC-S-2019-0039, "Remove HPCI Signal Converter Local Meter Relay M1 Output to Main Control Room Annunciator," Revision 0

(7) Screening QC-S-2019-0049, "Install Closed Torque Switch Bypass (CTSB) and Motor Pinion Gear Change for MO 1-1001-23A to Increase S1 and S6 Margin," Revision 0

(8) Screening QC-S-2019-0055, "Temporary Power for the Unit 2 Alternate 125 VDC Charger," Revision 1

(9) Screening QC-S-2019-0060, "Temporary Power for Fuel Oil Level Indicators 0-5241-13A/B," Revision 1

(10) Screening QC-S-2020-0015, "125VDC and 250VDC Conversion Calculations from ELMS-DC to DC-ETAP," Revision 0

(11) Screening QC-S-2020-0057, "Revise Bases B 3.8.4 to Clarify the 250 VDC Battery Sizing Methodology," Revision 0

(12) Screening QC-S-2021-0020, "CCST Floor Replacement," Revision 0

(13) Screening QC-S-2021-0033, "U-2 Add Isolation Valve to the U-2 TO 1/2 Diesel Generator Cooling Water Piping Crosstie to the Emergency Core Cooling System Room Coolers," Revision 0

(14) Screening QC-S-2022-0014, "U-1 and U-1/2 Diesel Generator Cooling Water Piping Crosstie to the Emergency Core Cooling System Room Coolers with Isolation Valve,"

Revision 0

(15) Screening QC-S-2023-0008, "QCOP and QCOS 2300 Series Procedure Changes to Leave the HPCI Turning Gear in PULL TO STOP," Revision 1

Operating Experience Samples (IP section 03.04) (3 Samples)

(1) Information Notice (IN) 2018-07, "Pump/Turbine Bearing Oil Sight Glass Problems"

(2) IN 2021-01, "Lessons Learned From U.S Nuclear Regulatory Commission Inspections of Design-Basis Capability of Power-Operated Valves at Nuclear Power Plants"

(3) Regulatory Issue Summary (RIS) 2022-02, "Operational Leakage"

INSPECTION RESULTS

Failure to Determine and Document Operability Associated with Technical Specification 3.2 Power Distribution Limits Following a Failure of the HPCI Flow Controller Cornerstone Significance Cross-Cutting Report Aspect Section Barrier Integrity Green [P.2] - 71111.21M FIN 05000254,05000265/2023010-01 Evaluation Open/Closed The inspectors identified a finding of very low safety significance (Green) for the licensee's failure to determine and document operability associated with Technical Specification (TS)3.2, "Power Distribution Limits," following a failure of the high pressure coolant injection (HPCI) flow controller on September 15, 2023, as required by steps 4.1.5 and 4.1.6 of Procedure OP-AA-108-115, "Operability Determinations (CM-1)." Specifically, the licensee did not evaluate whether the limits in the core operating limits report incorporated in TS 3.2 and the assumptions of the inadvertent HPCI initiation transient analysis continued to be met after the flow controller failure.

Description:

The HPCI system at Quad Cities was an emergency core cooling system (ECCS) designed to pump 5,600 gallons per minute (gpm) of water into the reactor vessel under loss of coolant accident conditions which did not result in rapid depressurization of the pressure vessel. The system had a safety function to automatically start on either a low-low reactor vessel water level or high drywell pressure signal. TS Limiting Condition for Operation (LCO) 3.5.1, "ECCS-Operating," required the system to be operable in Mode 1 and Modes 2 and 3 when reactor steam dome pressure was greater than 150 psig.

UFSAR section 15.5.1, "Inadvertent Initiation of High Pressure Coolant Injection During Power Operation," analyzed an inadvertent HPCI startup event to ensure the minimum critical power ratio fuel cladding integrity safety limit was not violated during the occurrence of the transient. The inadvertent initiation of the HPCI system (IHPCI) was a potentially limiting event which was analyzed on a cycle-specific basis in the reload safety analysis report.

UFSAR section 15.5.1.3, "Core and System Performance," had a historical information section for the initial core which assumed a 5,600 gpm flow rate from the HPCI system during the IHPCI event. The current reload safety analysis report for Cycle 28 also assumed a 5,600 gpm flow rate from the HPCI system as documented in TODI NF220577, "Quad Cities Unit 1 Cycle 28 Completed OPL-3 Form," Revision 0. The results of the IHPCI documented in Global Nuclear Fuel Document 006N9309, "Supplemental Reload Licensing Report for Quad Cities Unit 1 Reload 27 Cycle 28," Revision 0, were an input to the core operating limits report (COLR) for Quad Cities Unit 1 Cycle 28. The limits in the COLR were referenced in TS 3.2, "Power Distribution Limits," TS 3.2.1, "Average Planar Linear Heat Generation Rate (APLHGR)," TS 3.2.2, "Minimum Critical Power Ratio (MCPR)," and TS 3.2.3, "Linear Heat Generation Rate (LHGR)," to ensure the fuel was adequately protected during plant operation at or above 25 percent rated thermal power.

On September 15, 2023, during performance of QCOS 2300-05, "HPCI Pump Operability Test," the HPCI flow controller (1-2340-1) failed to control HPCI flow as documented in Action Request (AR) 4702971, "HPCI MGU did not Respond as Expected During QCOS 2300-05."

Although the controller was set to automatic with a setpoint of 5,600 gpm, HPCI flow was observed to be approximately 6,950 gpm. No response in system flow was observed when the automatic setpoint was lowered or when the controller was cycled between automatic and manual. Field operators verified the motor gear unit (MGU) was at the high speed stop (HSS).

When the MGU control switch was taken to the "slow lower" position, the MGU came off its HSS and flow lowered, but the MGU returned to the HSS and flow returned to 6,950 gpm once the control switch was released. The test was then aborted and the HPCI system was placed in a standby lineup. The operable basis of AR 4702971 stated the following:

The Signal Converter failed in a manner that prevented automatic flow control but would not prevent HPCI from initiating and ramping to full flow (i.e., the turbine high speed stop). In this condition, HPCI would have met corresponding Technical Specifications flow requirements and Accident Analysis requirements.

HPCI would have performed its safety function. Therefore, with the Motor Gear Unit at the High Speed Stop HPCI remains operable.

The inspectors discussed with the licensee the operable basis provided in AR 4702971, and confirmed it only considered the HPCI system's capability to supply the minimum required flow in the accident analysis and TS 3.5.1. However, it did not consider compliance with the TS 3.2 LCO limits. The inspectors reviewed EC 639997, "Technical Evaluation for Quad Cities HPCI Elevated Flow Rate," Revision 0, which was completed approximately one month after the failure and interviewed licensee staff to understand the impacts of the HPCI flow controller failure on the TS 3.2 LCO limits. The EC concluded that during the period while the HPCI flow controller was unable to control HPCI flow, no adverse consequences to the nuclear fuel resulting from an IHPCI would have occurred. The time period evaluated was from discovery of the HPCI flow controller failure on September 15, 2023, to September 19, 2023, when repairs were completed.

The inspectors reviewed licensee Procedure OP-AA-108-115, "Operability Determinations (CM-1)," Revision 26, and determined the licensee failed to follow steps 4.1.5 and 4.1.6 when they failed to document compliance with TS 3.2 LCO limits in the corrective action program (CAP). The steps state the following:

Step 4.1.5 DETERMINE and DOCUMENT the as-found and current operability status of the affected SSC in accordance with the CAP. This includes documenting the Operable Yes / No attribute in the CAP database based on AS-FOUND condition. Attachment 4, Part A, may be used as guidance for how to document operability within CAP. LOG this information as specified in OP-AA-111-101¸ "Operating Narrative Logs and Records," section 4.3.5. The focus of operability is foremost on the capability to ensure safety. (Operations Shift Management)

Step 4.1.6 Immediately DETERMINE operability from a detailed examination of the deficient condition affecting an SSC. Operability should be determined immediately upon discovery that an SSC subject to TS is impacted by a condition which results in a substantive functional impact on the SSC that may affect its ability to perform its specified safety function. The determination should be made without delay and in a controlled manner using the best available information.

The SRO should not postpone the determination until receiving the results of detailed evaluations. In most cases the decision can be made immediately and appropriately documented in the IR. (Operations Shift Management)

Contrary to Procedure OP-AA-108-115, on September 15, 2023, the licensee failed to determine and document operability associated with TS 3.2 LCO limits when the HPCI flow controller was unable to control HPCI flow at the rate assumed in the reload safety analysis report for the cycle. Specifically, since the HPCI flow rate during an IHPCI would have been 6,950 gpm versus the 5,600 gpm assumed in the transient analysis, the limits in the COLR for demonstrating compliance with TS 3.2 LCO were called into question.

Corrective Actions: The licensee entered the issue into their corrective action program (CAP)and planned to update the operability basis in AR 4702971 to document compliance with the TS 3.2 LCO limits for the HPCI flow controller failure. The licensee also planned to update procedures and lesson plans related to the HPCI system to ensure operability associated with TS 3.2 was addressed for HPCI flow controller failures.

Corrective Action References: AR 4711737 AR 4714113 AR 4714858

Performance Assessment:

Performance Deficiency: The licensee failed to determine and document operability associated with TS 3.2 following a failure of the HPCI flow controller on September 15, 2023, as required by steps 4.1.5 and 4.1.6 of OP-AA-108-115. Specifically, the licensee did not evaluate whether the limits in the COLR incorporated in TS 3.2 and the assumptions of the IHPCI transient analysis continued to be met after the flow controller failure.

Screening: The inspectors determined the performance deficiency was more than minor because it was associated with the Design Control attribute of the Barrier Integrity cornerstone and adversely affected the cornerstone objective to provide reasonable assurance that physical design barriers protect the public from radionuclide releases caused by accidents or events. Specifically, the failure to determine and document operability associated with TS 3.2, "Power Distribution Limits," following a failure of the HPCI flow controller adversely affected the cornerstone objective to provide reasonable assurance the fuel cladding barrier would protect the public from radionuclide releases caused by accidents or events.

Significance: The inspectors assessed the significance of the finding using IMC 0609 Appendix A, The Significance Determination Process (SDP) for Findings At-Power. The finding screened to Green because the inspectors answered "No" to all the exhibit 3, "Barrier Integrity Screening Questions," section A, "Fuel Cladding Integrity," screening questions.

Cross-Cutting Aspect: P.2 - Evaluation: The organization thoroughly evaluates issues to ensure that resolutions address causes and extent of conditions commensurate with their safety significance. Specifically, when the HPCI flow controller failed, the organization did not thoroughly evaluate the issue to ensure compliance with all applicable TSs.

Enforcement:

The inspectors did not identify a violation of regulatory requirements associated with this finding since the operability process is not required by any NRC regulation.

Discrepancies Between 250 VDC Calculations and Design Basis Acceptance Criteria Used in Test Procedures Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green [H.14] - 71111.21M Systems NCV 05000254,05000265/2023010-02 Conservative Open/Closed Bias The inspectors identified a finding of very low safety significance (Green) and an associated non-cited violation (NCV) of Title 10 of the Code of Federal Regulations (10 CFR) Part 50, Appendix B, Criterion III, "Design Control," for the licensees failure to ensure that values used in battery calculations were consistent with the design values specified in the updated final safety analysis report (UFSAR) and test procedures. Specifically, the licensee failed to:

(1) incorporate the measured armature current values of direct current (DC) motors used in design basis Calculation QDC-8350-E-2348 into work orders and test procedures, and (2)use the design basis minimum required voltage value of 210 volts DC (VDC) specified in the UFSAR to perform the voltage drop calculation for the 250 VDC motor operated valves (MOVs) in Calculation QDC-8350-E-0717.

Description:

During the inspectors review of the unit 2 250 VDC battery calculations, work orders, and surveillance tests, the inspectors identified two discrepancies between the values used in the direct current (DC) calculations and the acceptance criteria used in work orders and surveillance tests.

First, the inspectors reviewed Calculation QDC-8350-E-2348, "250 VDC System Analysis Using DC ETAP," Revision 0A, which analyzed the loading of the safety-related 250 VDC batteries. The inspectors noted the ETAP calculation used measured armature current values instead of the nameplate current values to model the DC motors in the analysis. Although motor currents were checked periodically during routine motor preventative maintenance activities, the testing incorrectly used the nameplate current values of the DC motors as the acceptance criteria instead of the armature current values used in the calculation. Therefore, the acceptance criteria for the periodic testing did not validate the inputs used in the design calculation.

A review of previous work orders identified two loads on the 250 VDC batteries that had higher tested currents than the armature current values used in Calculation QDC-8350-E-2348. The loads affected were the RCIC vacuum pumps and the RCIC condensate pumps. The RCIC vacuum pumps were modeled with a current value of 5.6 amps, but the running current measured during testing was 5.7 amps. Similarly, the RCIC condensate pumps were modeled with a current value of 5.5 amps, but the running current measured during testing was 7.8 amps. Since the testing contained incorrect acceptance criteria, the impacts of the higher tested current values on Calculation QDC-8350-E-2348 were never evaluated.

Second, the inspectors reviewed UFSAR section 8.3.2.1 and noted the design basis minimum required voltage at the battery terminals was 210 VDC. The inspectors confirmed battery surveillance tests used this value as the acceptance criteria during testing. However, the inspectors reviewed Calculation QDC-8350-E-0717, "DC MOV Voltage Drop Calculation,"

Revision 3, and noted it had not used the design basis 210 VDC value at the battery terminals to perform the voltage drop analysis for the 250 VDC MOVs. The calculation instead assumed a minimum voltage of 205 VDC at 250 VDC safety-related buses 1A, 1B, 2A, and 2B. A minimum voltage of 205 VDC at the safety-related buses translated to a voltage higher than the minimum design basis 210 VDC voltage at the battery terminals

(~213 VDC) since there was a voltage drop of approximately 8 VDC between the batteries and the safety-related buses as analyzed in the ETAP calculation. Therefore, the inspectors concluded the assumed minimum voltage at the safety-related buses of 205 VDC in Calculation QDC-8350-E-0717 was incorrect because it was higher than the available voltage

(~202 VDC) at the buses had the design basis minimum battery terminal voltage of 210 VDC and the approximately 8 VDC voltage drop between the batteries and safety-related buses been accounted for.

Corrective Actions: The licensee entered these issues into their CAP and assigned actions to their design engineering department to update the affected calculations and design basis documents. The licensee reviewed recent battery surveillance test results and determined the 250 VDC system remained capable of performing its safety function given the deficiencies identified due to the additional margins available.

Corrective Action References: AR 04711853 AR 04714548

Performance Assessment:

Performance Deficiency: The licensees failure to ensure that values used in battery calculations were consistent with the design values specified in UFSAR and test procedures was a performance deficiency and a violation of 10 CFR 50, Appendix B, Criterion III, "Design Control." Specifically, the licensee failed to:

(1) incorporate the measured armature current values of DC motors used in design basis calculations into work orders and test procedures, and

(2) the licensee failed to use the design basis minimum required voltage value of 210 VDC specified in the UFSAR to perform the voltage drop calculation for the 250 VDC MOVs.

Screening: The inspectors determined the performance deficiency was more than minor because it was associated with the Design Control 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 failure to ensure values used in battery calculations were consistent with design values specified in the UFSAR and test procedures adversely affected the cornerstone objective of ensuring the capability of the 250 VDC system to respond to initiating events to prevent undesirable consequences.

Significance: The inspectors assessed the significance of the finding using IMC 0609 Appendix A, The Significance Determination Process (SDP) for Findings At-Power. The inspectors determined this finding was of very low safety significance (Green) because although the finding was a deficiency affecting the design or qualification of a mitigating SSC, the SSC maintained its operability and PRA functionality.

Cross-Cutting Aspect: H.14 - Conservative Bias: Individuals use decision making-practices that emphasize prudent choices over those that are simply allowable. A proposed action is determined to be safe in order to proceed, rather than unsafe in order to stop. Specifically, the licensee incorrectly assumed the values used in design basis calculations were conservative without validating that was the case.

Enforcement:

Violation: Title 10 CFR 50, Appendix B, Criterion III, Design Control, requires, in part, that measures be established to assure that applicable regulatory requirements and the design basis are correctly translated into specifications, drawings, procedures, and instructions.

Design Calculation QDC-8350-E-2348, "250 VDC System Analysis Using DC ETAP,"

Revision 0A, which analyzed the loading of the safety-related 250 VDC batteries used measured armature current values instead of the nameplate current values to model the DC motors in the analysis.

UFSAR section 8.3.2.1, "250-V System," stated, in part, the capacity of each unit battery is adequate to supply expected essential loads following station trip and loss of all ac power without battery terminal voltage falling below the minimum discharge level (i.e., 210-V).

Contrary to the above, as of October 2023, the licensee failed to establish measures to assure that applicable regulatory requirements and the design basis were correctly translated into specifications, drawings, procedures, and instructions. Specifically, the licensee failed to:

(1) incorporate the measured armature current values of DC motors used in design basis Calculation QDC-8350-E-2348 into work orders and test procedures, and

(2) use the design basis minimum required voltage value of 210 VDC specified in the UFSAR to perform the voltage drop calculation for the 250 VDC MOVs in Calculation QDC-8350-E-0717.

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

Failure to Follow Procedural Instructions for Battery Installation Cornerstone Significance Cross-Cutting Report Aspect Section Mitigating Green [H.5] - Work 71111.21M Systems NCV 05000254,05000265/2023010-03 Management Open/Closed The inspectors identified a finding of very low safety significance (Green) and an associated NCV of 10 CFR 50, Appendix B, Criterion V, Instructions, Procedures, and Drawings, for the licensees failure to correctly install safety-related 125/250 VDC batteries in accordance with prescribed work instructions and drawings. Specifically, the licensee failed to:

(1) install foam spacers for the unit 2 250 VDC battery as prescribed in work instructions when installing the battery to ensure the battery's seismic qualifications were maintained, and

(2) install jumper cables for the unit 1 125 VDC battery as prescribed in a drawing to ensure the cable bend radii were greater than the minimum required to prevent damage to the cables over time.

Description:

The inspectors reviewed information associated with, and performed walkdowns of, the 125 VDC and 250 VDC batteries. The inspectors identified two deficiencies associated with the installation of the safety-related station batteries.

First, the inspectors reviewed QDC-8300-S-0673, "Review of Aged Battery Seismic Qualification Report," Revision 1, and noted the seismically tested and qualified configuration of the 125 VDC and 250 VDC battery cells was to have a gap no greater than 1/8 inch between the battery cells and the battery rack side or end support, with snug fitting crush-resistant foam spacers used as necessary. The inspectors also reviewed Procedure QCEM 0100-03, "125/250 VDC Battery Replacement (Out-of-Service)," Revision 19, and noted section 4.12.2 required gaps to be snug tight, which was defined as a gap less than or equal to 1/8 inch. The inspectors reviewed Work Order 05231566 for the unit 2 250 VDC replacement battery and noted the requirements of Procedure QCEM 0100-03 applied to the installation of the batteries.

During a walkdown of the unit 2 battery room, the inspectors identified a missing foam spacer on the unit 2 250 VDC battery between cell 66 and the steel partition plate adjacent to cell 67.

The inspectors also identified a foam spacer on the unit 2 125 VDC battery between cell 35 and the battery rack that was incorrectly installed. Specifically, the top of the foam spacer was wedged snug against the battery rack, but the bottom of the foam spacer was loose and not properly wedged. Based on the inspectors' observations, the licensee performed extent of condition walkdowns of the unit 1 and unit 2 125 VDC and 250 VDC batteries. The walkdowns identified additional deficiencies associated with the foam spacer installation on the batteries. The deficiencies included missing and loose foam spacers either between cells or between cells and the battery rack, with some instances where the gap was greater than the 1/8 inch acceptance criteria specified in Procedure QCEM 0100-03.

Second, the inspectors noted the unit 1 125 VDC battery was required to be installed in accordance with Drawing 4E-1067F, "Connection Layout 125V DC and 250V DC Battery Cells," Revision J, and Standard N-EM-0035, "Cable Standards," Revision 6. The standard specified a minimum static bend radius of four times the outside cable diameter for 350 MCM cables. The purpose of specifying a minimum required bend radius is to prevent damage over time to the cable jacket and insulation due to a tight bend of the cable.

During a walkdown of the unit 1 battery room, the inspectors observed tight bends on the inter-tier jumper cables of the 125 VDC and 250 VDC batteries. The inspectors questioned whether these bends met the minimum required bend radii for the cables. As a follow-up, the licensee performed field measurements of the bend radii on all the jumper cables and identified four cables with a bend radius below their minimum required. Specifically, the four paralleled 350 MCM cables at the north end of the unit 1 125 VDC battery had a 2.75 inch bend radius, which was below the minimum required bend radius for the cables specified in Standard N-EM-0035. These jumper cables connected the upper and lower tiers of the battery rack and were not in contact with anything other than the connections to the battery.

Preliminary inspection of the cables by the licensee did not indicate any signs of stress or cracking of the cable jacket or insulation.

Corrective Actions: The licensee entered these issues into their corrective action program and evaluated the as found condition of the batteries to ensure they remained capable of performing their safety function. The licensee planned to correct the foam deficiencies identified and to evaluate options to better secure the foam spacers in place. The licensee also planned to inspect the unit 1 125 VDC cables and replace them during the upcoming battery replacement.

Corrective Action References: AR 4710719 AR 4710720 AR 4711901 AR 4712437 AR 4712444 AR 4712448 AR 4712450 AR 4711264

Performance Assessment:

Performance Deficiency: The licensees failure to ensure that 125/250 VDC station safety-related batteries were correctly installed as prescribed in work instructions and drawings was a performance deficiency and a violation of 10 CFR 50, Appendix B, Criterion V, Instructions, Procedures, and Drawings. Specifically, the licensee failed to:

(1) install foam spacers for the unit 2 250 VDC battery as prescribed in work instructions when installing the battery to ensure the battery's seismic qualifications were maintained, and

(2) install jumper cables for the unit 1 125 VDC battery as prescribed in a drawing to ensure the cable bend radii were greater than the minimum required to prevent damage to the cables over time.

Screening: The inspectors determined the performance deficiency was more than minor because it was associated with the Design Control 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 failure to correctly install safety-related 125/250 VDC batteries to ensure design requirements were met adversely affected the cornerstone objective of ensuring the availability, reliability, and capability of the batteries to respond to initiating events to prevent undesirable consequences.

Significance: The inspectors assessed the significance of the finding using IMC 0609 Appendix A, The Significance Determination Process (SDP) for Findings At-Power. The inspectors determined this finding was of very low safety significance (Green) because although the finding was a deficiency affecting the design or qualification of a mitigating SSC, the SSC maintained its operability and PRA functionality.

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 failed to control and execute the 125/250 VDC battery installation activities to ensure the risk of installation errors was appropriately precluded.

Enforcement:

Violation: Title 10 CFR 50, Appendix B, Criterion V, Instructions, Procedures, and Drawings, requires, in part, that activities affecting quality be prescribed by documented instructions, procedures, or drawings of a type appropriate to the circumstances and be accomplished in accordance with those instructions, procedures, or drawings.

The licensee established Work Order 05231566 as the implementing instruction for installing the unit 2 250 VDC battery. Work Order 05231566 steps 3.45, 3.82, and 3.117 required Ethafoam material spacers to be installed in accordance with QCEM 0100-03.

QCEM 0100-03, step 4.12.2, required, in part, that battery cells not be in contact with the rack steel (i.e., cells be restrained front and rear by "snug fitting" Ethafoam material) and that cells also be restrained sideways by "snug fitting" Ethafoam material. The note in step 4.12.2 defined snug tight as being a gap less than or equal to 1/8 inch.

The licensee established Drawing 4E-1067F as the implementing drawing for the 125 VDC battery connection layout. Drawing 4E-1067F referenced Standard N-EM-0035 for cable requirements. Standard N-EM-0035 required the minimum static bend radius of 350 MCM cable to be four times the outside cable diameter.

Contrary to the above, as of October 2023, the licensee failed to accomplish activities affecting quality as prescribed in work instructions and drawings. Specifically, the licensee failed to:

(1) install foam spacers for the unit 2 250 VDC battery snug tight with a gap less than or equal to 1/8 inch as prescribed in Work Order 05231566 and QCEM 0100-03 to ensure the battery's seismic qualifications were maintained, and

(2) install 350 MCM jumper cables for the unit 1 125 VDC battery as prescribed in Drawing 4E-1067F and Standard N-EM-0035 with a minimum bend radius of four times the outside cable diameter to prevent damage to the cables over time.

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

Non-conservative Valve Factor Used to Demonstrate Motor Operated Valve 1-1001-23A Continued to be Capable of Performing its Design Basis Safety Functions Cornerstone Significance Cross-Cutting Report Aspect Section Barrier Integrity Green [P.5] - 71111.21M NCV 05000254,05000265/2023010-04 Operating Open/Closed Experience The inspectors identified a finding of very low safety significance (Green) and an associated NCV of 10 CFR 50.55a(b)(3)(ii) for the licensee's failure to establish a program that ensured MOVs continued to be capable of performing their design basis safety functions. Specifically, the licensee incorrectly used a non-conservative valve factor from industry testing as a design input to size and set-up MOV 1-1001-23A instead of using the bounding valve-specific, empirically determined valve factor.

Description:

The inspectors reviewed 50.59 Screening QC-S-2019-0049, which installed a closed torque switch bypass (CTSB) and performed a gearing change on the residual heat removal (RHR)

A loop drywell spray outboard primary containment isolation valve (1-1001-23A) to increase the available performance margin of the valve. The 1-1001-23A MOV was a normally closed valve and had a safety function to open to provide a flow path from the RHR system to the drywell to allow operation of the drywell spray subsystem. The valve also had a safety function to close to isolate containment from the RHR system and to terminate drywell spray operation when required.

The inspectors also reviewed IN 2021-01, Lessons Learned from US Nuclear Regulatory Commission Inspections of Design-Basis Capability of Power-Operated Valves at Nuclear Power Plants. The IN stated, the valve friction coefficients determined for MOVs as part of the Joint Owners Group (JOG) MOV Program do not represent a database of valve friction coefficients that can be applied in general to calculate the thrust and torque required to operate various MOVs under design-basis conditions.

As part of the 50.59 screening review, the inspectors reviewed Calculation QUA-1-1001-23A, MIDACALC Results QUA-1-1001-23A (QUA-1), Revision 10, which was updated after the CTSB modification. The calculation was used by the licensee to perform MOV sizing and set-up window evaluations of the 1-1001-23A MOV to ensure the valve had sufficient thrust and torque to perform its design basis safety functions. The inspectors noted the reference provided for the valve factors used in the calculation came from licensee Procedure ER-AA-302-1009, Final JOG MOV Periodic Verification Program Implementation. The inspectors requested the basis for the valve factors used in the calculation since the procedure only captured the results of the JOG valve factor degradation study and was not an appropriate source for selecting design basis valve factors.

In response to the inspectors questions, the licensee determined they were incorrectly using non-conservative valve factors from the JOG study in the calculation. Procedure ER-AA-302-1001, MOV Rising Stem Motor Operated Valve Thrust and Torque Sizing and Set-Up Window Determination Methodology, Revision 14, was the licensee procedure established to properly size and set-up MOVs to ensure they were capable of performing their design basis safety functions. Step 4.1.5.2.B stated, in part, where possible it is expected MOV program valve calculations will use the highest applicable GL 89-10, JOG, or valve specific, empirically determined, stable valve factor." It also stated, "at no time is it acceptable to utilize a valve factor determined via grouping or industry data if valid, valve-specific test data or current qualifying basis (i.e. GL 89-10 closeout) demonstrate a higher valve factor is applicable.

The licensee determined a higher valve-specific valve factor was applicable to the 1-1001-23A MOV, as described in NES-MS-06.6, MOV Valve Factors, which was a licensee Generic Letter (GL) 89-10, "Safety-Related MOV Testing and Surveillance," closeout document. Therefore, since the licensee used a non-conservative valve factor to size and set-up the 1-1001-23A MOV, the licensee failed to establish a program that ensured the MOV continued to be capable of performing its design basis safety function.

In December 2022, the licensee was made aware of the use of non-conservative valve factors at another fleet site. The issue was entered into the CAP at that time, and actions were assigned to review the applicability of the operating experience to Quad Cities (AR 4540308 action items 2 through 6). As part of the review, the licensee had only sampled 44 percent of the valves in the MOV program, which did not include the 1-1001-23A MOV.

Corrective Actions: The licensee entered this issue into their CAP and re-analyzed the design basis capability of the 1-1001-23A MOV using the higher bounding valve factor. Although appreciable margin in the closed direction was lost, the licensee was able to demonstrate the valve was still capable of performing its design basis functions by removing conservatism in the MOV calculation. The licensee planned to perform an extent of condition review of the remaining MOV program valves to ensure appropriate valve factors were used in calculations.

Corrective Action References: AR 4714457 AR 4715113

Performance Assessment:

Performance Deficiency: The failure to ensure the 1-1001-23A MOV continued to be capable of performing its design basis safety function was contrary to 10 CFR 50.55a(b)(3)(ii) and was a performance deficiency. Specifically, the licensee incorrectly used a non-conservative valve factor from industry testing as a design input to size and set-up the 1-1001-23A MOV, instead of using the bounding valve-specific, empirically determined valve factor.

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 failure to ensure the 1-1001-23A MOV was capable of closing during a design basis event adversely affected the objective of the containment barrier to protect the public from radionuclide releases caused by accidents or events. Similar to example 3.l of IMC 0612 Appendix E, "Examples of Minor Issues," this issue was also more than minor because licensee had to re-analyze the design basis capability of the MOV and they were procedurally required to perform additional testing and maintenance on the valve due to the loss in MOV performance margin.

Significance: The inspectors assessed the significance of the finding using IMC 0609 Appendix A, The Significance Determination Process (SDP) for Findings At-Power. The inspectors determined the finding was of very low safety significance (Green) because they answered "No" to all exhibit 3, "Barrier Integrity Screening Questions," section C, "Reactor Containment," screening questions.

Cross-Cutting Aspect: P.5 - Operating Experience: The organization systematically and effectively collects, evaluates, and implements relevant internal and external operating experience in a timely manner. Specifically, the licensee was aware of recent operating experience related to the use of non-conservative valve factors in design basis calculations but failed to review all the valves in their MOV program when addressing the operating experience.

Enforcement:

Violation: Title 10 CFR 50.55a(b)(3)(ii) states, in part, the licensees must establish a program to ensure that MOVs continue to be capable of performing their design basis safety functions.

Procedure ER-AA-302-1001, MOV Rising Stem Motor Operated Valve Thrust and Torque Sizing and Set-Up Window Determination Methodology, Revision 14, is a licensee procedure established to properly size and set-up MOVs to ensure the valves are capable of performing their design basis safety function. Step 4.1.5.2.B states, in part, Where possible, it is expected MOV program valve calculations will use the highest applicable GL 89-10, JOG, or valve specific, empirically determined, stable valve factor." The procedure step also states, "At no time is it acceptable to utilize a valve factor determined via grouping or industry data if valid, valve-specific test data or current qualifying basis (i.e. GL 89-10 closeout) demonstrate a higher valve factor is applicable.

Contrary to the above, as of November 1, 2023, the licensee failed to establish a program that ensured MOVs continued to be capable of performing their design basis safety functions.

Specifically, the licensee failed to use the highest applicable GL 89-10, JOG, or valve-specific, empirically determined, stable valve factor as a design input to properly size and set-up the 1-1001-23A valve. The licensee incorrectly used a non-conservative valve factor to size and set-up the MOV, which failed to ensure the MOV continued to be capable of performing its design basis safety function.

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

Very Low Safety Significance Issue Resolution Process: Removal of 10 CFR 50, 71111.21 Appendix J, Leak Rate Testing Requirements from Containment Isolation Valves M This issue is a current licensing basis question and inspection effort is being discontinued in accordance with the Very Low Safety Significance Issue Resolution (VLSSIR) process. No further evaluation is required.

Description:

Quad Cities was required to have a TS 5.5.12, Primary Containment Leakage Rate Testing Program, to meet the requirements of 10 CFR 50, Appendix J, Primary Reactor Containment Leakage Testing For Water-Cooled Power Reactors. This program was required to follow the guidelines contained in NEI 94-01, Industry Guideline for Implementing Performance-Based Option of 10 CFR 50, Appendix J, Revision 3-A, and the conditions and limitations specified in NEI 94-01, Revision 2-A. The site-specific program implementing procedure was QCTP 0130-01, Primary Containment Leakrate Testing Program, Revision 31.

As a modification sample, the inspectors reviewed EC 630019, Appendix J Local Leak Rate Testing Scope Reduction for CS, RHR, and SBLC Systems - Owners Acceptance Review, Revision 0. This EC approved a vendor report that identified potential components for exclusion from the local leak rate test (LLRT) requirements of TS 5.5.12 and Appendix J. The EC evaluated the core spray (CS) and residual heat removal (RHR) systems against the criteria described in ANSI/ANS 56.2-1984, Containment Isolation Provisions for Fluid Systems after a LOCA, section 3.6.7, Criteria for Closed Systems Outside Containment.

The evaluation concluded the systems met the closed system outside containment criteria, and therefore did not constitute a potential primary containment atmospheric pathway during and following a design basis accident (DBA). Since section 6, General Requirements, of NEI 94-01, Revision 3-A, did not require an LLRT for boundaries that did not constitute a potential atmospheric pathway, the evaluation excluded CS valves MO (1)-1402-25A/B and MO (1)-1402-24A/B, and RHR valves MO 1(2)-1001-34A/B, from the LLRT requirements of TS 5.5.12 and Appendix J.

During the inspection, the inspectors asked questions regarding the application of the criteria contained in NEI 94-01 and ANSI/ANS 56.2-1984. ANSI/ANS 56.2-1984, section 3.6.7, stated, in part, If a closed system outside containment is used as one of the two containment isolation barriers for an engineered safety feature or engineered safety feature related system, the closed system shall:

(8) Be protected against loss of function from missiles. The EC referenced UFSAR, section 3.5.2, Internally Generated Missiles, which described the segregated component arrangements (separation) and redundant features such that a failure of one engineered safety system would not cause the failure of the other. The inspectors questioned whether the UFSAR statements supported the change because it appeared the licensing basis allowed for failures of the piping systems due to missile impacts, which would not meet the missile protection requirement to credit the closed systems outside of containment as the containment isolation barriers. Prior to the modification, containment isolation occurred at the credited containment isolation valves. Since the EC removed the LLRT requirements of these valves, and the licensing basis appeared to allow for failures of the closed systems outside of containment due to missile impacts, the inspectors questioned whether the change was acceptable from a containment isolation perspective.

The inspectors were also concerned the site removed LLRT requirements from the CS and RHR containment isolation valves without evaluating the impact of an internally generated missile on either system in accordance with the applied industry standards. For example, since the containment isolation function appeared to be extended to the closed system outside of containment for each system, the inspectors questioned whether the CS system could withstand a turbine generated missile from the RCIC turbine. The RCIC turbine shares a common room and is near a portion of the CS system. Given the change to the isolation barrier, it was unclear if the plants current licensing basis still appropriately accounted for the impact of internally generated missiles on safety related systems.

As described above, the inspectors had an issue of concern that LLRT requirements for the CS and RHR containment isolation valves had been removed without an appropriate evaluation of the CS and RHR closed systems outside of containment against missile hazards.

Licensing Basis: The licensee generated a white paper to respond to the inspectors concerns. They reviewed the sites licensing basis in UFSAR sections 3.5.3 and 3.1.7.4, and available industry guidance in NEI 94-01 Revision 3A, ANSI/ANS 56.2-1984, and ANSI/ANS 56.8-2002, Containment System Leakage Testing Requirements. The licensee stated, in part, the bounding missile outside the drywell is the main turbine, and referenced a missile protection discussion in UFSAR section 3.1.7.4 which states, in part, Components of the ESF which are required to function after design basis accidents or incidents are designed to withstand the most severe forces and environmental effects, including missiles from plant equipment failures anticipated from the events. Based on these statements, the licensee concluded that additional equipment failures that result in missile generation, in addition to a DBA, are not postulated in the licensing basis. The licensee stated, in part, As no specific guidelines that constitute protection against missiles are provided in ANSI/ANS 56.2-1984, the site has utilized its existing design and licensing basis for missile protection to demonstrate criterion 8 is met. Upon further review, the inspectors found there was industry guidance referenced in ANSI/ANS 56.2-1984 that discussed protection against internally generated missiles from non-safety systems. Specifically, ANSI/ANS 56.2-1984 section 4.5.1, Missile, Pipe Whip, and Jet Force Protection, referenced ANS 58.1, Proposed American National Standard for Plant Design Against Missiles, which was incorporated in ANSI 58.3-1992, Physical Protection for Nuclear Safety-Related Systems and Components, and ANSI/ANS 52.1-1983, Nuclear Safety Criteria for the Design of Stationary Boiling Water Reactor Plants. Although this guidance was available at the time the EC was performed, without further research, it was unclear to the inspectors whether it was applicable to Quad Cities.

Additionally, the licensee stated, in part, While the technical evaluation utilized ANSI/ANS 56.2-1984 and interpreted the missile protection required by that standard, it should be noted that the station is not committed to ANSI/ANS 56.2, and any evaluation performed using that standard is being done under the auspices of the stations program that is committed to NEI-94-01. Neither NEI 94-01 or ANSI/ANS 56.8-2002 require the assumption of an additional missile in addition to a DBA and the requirements for local leak rate testing in NEI 94-01 are clear that its concerned with potential atmospheric pathways following a design basis accident. The inspectors determined that significant additional research into the sites specific commitments for missile protection would be required to validate the licensee's statements.

Based on the discussion above, at the conclusion of the inspection, the inspectors were unable to determine whether the issue of concern was part of the plant's current licensing basis. As a result, the inspectors determined the issue should be evaluated using the VLSSIR process because the resources required to resolve the current licensing basis question would not effectively and efficiently serve the agency's mission.

Significance: For the purpose of the VLSSIR process, the inspectors screened the issue of concern through IMC 0609, Appendix A, "The Significance Determination Process for Findings At-Power." The inspectors determined the issue of concern would likely be of very low safety significance (Green) had a performance deficiency been identified because they answered No to all the exhibit 3, Barrier Integrity Screening Questions," section C, "Reactor Containment," screening questions.

Corrective Action Reference: AR 4717895, "NRC CETI EC 630019 Has an Incomplete Discussion of Missiles"

EXIT MEETINGS AND DEBRIEFS

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

• On November 16, 2023, the inspectors presented the Comprehensive Engineering Team Inspection results to Brian Wake, Site Vice President, and other members of the licensee staff.

• On November 3, 2023, the inspectors presented the interim inspection results to Drew Griffiths, Plant Manager, and other members of the licensee staff.

DOCUMENTS REVIEWED

Inspection Type Designation Description or Title Revision or

Procedure Date

71111.21M Calculations 004-E-005-1301 Unit 2 RCIC MOV Terminal Voltage Calculation 7

0591-171-008 Diesel Fuel Oil Consumption 2, 2A

0591-215-01 EDG Fuel Oil Transfer Pump NPSH and Return Line Sizing 2

2-3954-R106 Pipe Support Qualification 2A

(67)/Q2-DGSW-

01B(C)

20-03-20 125 VDC System Analysis Using DC ETAP 0

28.0201.0331 RCIC Pump Suction - Computer Output Listing, Math Model 2

Q1.03

3C3-1084-001 RCIC Pump Cubicle Temperature Transient During LOOP 1

and Loss of Cubicle Cooler

BSA-Q-00-01 Quad Cities RHR Room Thermal Behavior in Mode 4/5 0, 0A

Operation with Loss of Room Cooler

BSA-Q-95-09 Effects of a RCIC Steamline Break on the HPCI Room 0, 0A

C-8051-4 CCST Tank Analysis 0

GE-NE-A22-Project Task Report Dresden and Quad Cities Extended 0

00103-75-02 Power Uprate Task T0903 Station Blackout (Quad Cities)

HSBO-03 RCIC Room Average Temperature Following Station 0

Blackout

M-1030D-105/Q2-Pipe Support Modification 2A, 2B

DGSW-01B(C)

M-1030D-123/Q2-Pipe Support Modification 1A, 1B

DGSW-01B(C)

M-1030D-205/Q1-Pipe Support Modification 2A

DGSW-01B(C)

M-1030D-206/Q1-Pipe Support Modification 2A

DGSW-01B(C)

M-1030D-54/Q2-Pipe Support Qualification, Node Point C09A 3A, 3B

DGSW-01B(C)

M-1030D-624/Q2-Evaluation of Pipe Support M-1030D-624 0, 0A

DGSW-01B(C)

71111.21M Calculations M-1030D-625/Q2-Evaluation of Pipe Support M-1030D-625 0, 0A

DGSW-01B(C)

M-1030D-626/Q2-Evaluation of Pipe Support M-1030D-626 0, 0A

DGSW-01B(C)

M-1030D-627/Q2-Evaluation of Pipe Support M-1030D-627 0, 0A

DGSW-01B(C)

M-1030D-629/Q2-Evaluation of Pipe Support M-1030D-629 1

DGSW-01B(C)

M-1030D-69/Q2-Pipe Support Modification 2A, 2B

DGSW-01B

M-3144-S7/Q2-Evaluation of Pipe Support M-3144-S7 0, 0A

DGSW-01B(C)

M-998D-596/Q1-Pipe Support Modification 0A

DGSW-01B(C)

M-998D-636/Q2-Evaluation of Pipe Support M-998D-636 0, 0A

DGSW-01B(C)

M-998D-PEN/Q1-Evaluation of H-Wall Penetration Anchor M-998D-PEN 0

DGSW-02B(C)

NED-I-EIC-0048 RCIC Turbine Area High Temperature Isolation Setpoint 2

Error at Normal Operating Conditions

NED-I-EIC-0139 Reactor Core Isolation Cooling (RCIC) System Pump 3

Discharge Flow Setpoint Error Analysis

NED-I-EIC-0227 RCIC Steam Line Flow Setpoint Error Analysis at Normal 2

Operating Conditions

OTC-328 Crane-Aloyco Valve Report 1

Q1-DGSW-Diesel Generator Service Water Piping Analysis 12C

2B(C)/ANALYSIS

Q1-S-B655/Q1-Pipe Support Qualification 1A

DGSW-01B(C)

Q1-S-B660/Q1-Pipe Support Qualification, Node Point 163 1A, 1B

DGSW-01B(C)

Q2-DGSW-Piping Analysis for System Q2-DGSW-01B(C) 11D

01B(C)/ANALYSIS

QC-030-M-001 Pressure/Temperature Transient Analysis for HPCI Steam 2

Line Break in Torus Compartment

71111.21M Calculations QC-429-M-007 Flow Evaluation for Safe Shutdown Makeup Pump Room 0

Cooler Piping

QC-429-P-021 Stress Analysis for Diesel Fuel Oil Line Nos. 1-5206-2";-1";-1, 1A

3/4"-G

QC-716-M-001 Maximum Room Temperature For Core Spray and RHR 3, 3A, 3B

Corner Pump Rooms Following a Postulated Event Outside

These Rooms and Verification of Adequacy of Room

Coolers in These Rooms

QDC-1000-M-Flow Model of Emergency Core Cooling System (ECCS) 2

0419 Suction Piping with Core Spray and Residual Heat Removal

(RHR) System Discharge Piping

QDC-1000-M-RHR/CS Vortexing and NPSH Analysis for Suction from 3A

0592 CCSTs

QDC-1000-M-Safe Shutdown NPSH Evaluation for RCIC and RHR 0B, 0C

27 Pumps

QDC-1300-M-RCIC NPSH Limits for EOPs 1

0589

QDC-1300-M-Pressure Drop Through RCIC Discharge Piping to Reactor 1

0800 Vessel

QDC-1300-M-Reactor Core Isolation Cooling System Combined DBD and 0, 0B

20 DP Calculation

QDC-2300-I-0964 HPCI / RCIC CCST Level Switch Setpoint Error Analysis 0, 0A

QDC-2900-I-0329 Safe Shutdown Makeup Pump (SSMP) Discharge Flow 0, 0A

Indicator Error Analysis

QDC-2900-M-Torque Required to Close the Safe Shutdown Makeup 0, 0A

0341 Pump (SSMP) MOVs 1/2-2901-7, 1-2901-8, and 2-2901-8

QDC-2900-M-Determination of Pressure Required at PI-1/2-2941-8 for 1, 1A,1B

0472 Safe Shutdown Makeup Pump System Injection Under Safe

Shutdown Conditions

QDC-2900-M-NPSH Analysis for Safe Shutdown Make-Up Pump 0A

21

QDC-3300-M-Heat Transfer Calculation for A & B Contaminated 0

0110 Condensate Storage Tanks (CCST) for Engineering

Request No. ER9600008

QDC-3300-M-Heat Transfer Calculation to Determine the Number of 0

28 Heaters Required for A & B Contaminated Condensate

Storage Tanks (CCSTs) When Full.

QDC-3300-M-Design Basis Analysis of CCST Standpipe Line Nos. 1/2-1A

0484 3345, 6, 8, 9 - 10" for HPCI Level Switches 1/2-2350A, B, C

and D

QDC-3300-M-Useable Water Volume of Contaminated Condensate 3, 3A

0489 Storage Tanks for HPCI and RCIC, Including Vortexing

Considerations

QDC-3300-M-CCST Heat Loss 0, 0A, 0B

0872

QDC-3300-M-Evaluation of Instrument PI 2-1360-20 as a Means of 0

1763 Establishing the Level in the CCST Tanks

QDC-3300-S-1830 Structural Evaluations Associated With the CCST Piping 0

Re-Route

QDC-3900-M-Seismic Qualification of Velan 6 Inch Gate Valve 0

2380

QDC-3900-S-2113 Evaluation of New Support for Unit 2 DGSW Piping 1A, 1B

Associated with RCIC Room Ventilation

FLEX Modification

QDC-4600-M-Design Review of Emergency Diesel Generator Starting Air 0, 0A

1112 System Capability

QDC-5700-M-Emergency Core Cooling System (ECCS) Room Cooler 1, 1H

0806 Performance Calculation Under Design Basis and Degraded

Conditions

QDC-8300-E-2347 125 VDC System Analysis Using DC ETAP 0

QDC-8300-S-0673 Review of Aged Battery Seismic Qualification Report 0

QDC-8350-E-0196 HMCP Breaker Sizing and Setting for Unit 2 DC Motors 0

QDC-8350-E-0717 DC MOV Voltage Drop Calculation 3

QUA-1-1001-23A MIDACALC Results QUA-1001-23A (QUA-1) 9A

QUA-1-1001-23A MIDACALC Results QUA-1001-23A (QUA-1) 10

QUA-2-1301-61 DC Motor Operated GL96-05 Globe Valve 10

QUA-2-2901-8 MIDAS Calculation: MOV 2-2901-8 1

RAL-7336 Limiting Component Analysis; MOV-2-2901-8 0

VT-03 Safe Shutdown Makeup Pump (SSMP) Room HVAC 3B

Cooling Load Calculation

Calibration TS 2-5703-175 Instrument Calibration Data 11/24/2014

Records

Corrective Action 367859 Tank Bolts on the 1/2 A CCST are Bent 08/29/2005

Documents 367861 Tank Bolts on the 1/2 B CCST are Bent 08/29/2005

370284-04 Review of 1(2)-2901-10 Valve Performance and Impact on 10/27/2005

HPCI Operability

4074482 OPEX Review 4061005 Finds IN 2017-06 is Applicable to 11/14/2017

Quad

4156632 NRC IN 2018-07: Pump/Turbine Bearing Oil Sight-glass 06/13/2018

Problems

232272 TRM 3.7.B, DGCW System - Shutdown Requires Revision 03/23/2019

23071 NRC IN 2021-01: Design Bases LLed Power Operated 05/11/2021

Valves

4472779 1B RHRSW Pump Low Oil Level on Start 01/19/2022

23962 U2 EDG Failed to Start 09/22/2022

24461 EO ID: U2 E2 RCIC Turbine Oil Sight Glass Leak 09/25/2022

4536886 NRC RIS 2022-02 Op Leakage inconsistent with Op Eval 11/14/2022

Proc

4539894 2-1301-81, U2 ECCS Keep Fill to U2 RCIC is Broken 11/30/2022

4558106 HPCI Signal Converter MGU Drive Signal (Auto) 02/28/2023

4669589 Q1R27 HPCI Servo Amplifier Noise Troubleshooting 04/12/2023

4687507 High Running Current on MOV 2-2901-8 06/29/2023

4696801 U2 250 VDC Battery Below Minimum Required Voltage 08/16/2023

4702971 HPCI MGU Did Not Response as Expected During QCOS 09/15/2023

2300-05

Corrective Action 4709969 NRC CETI-UFSAR Contains Incorrect 250 VDC Load Shed 10/16/2023

Documents Time

Resulting from 4710371 NRC CETI - U2 EDG Exhaust Insulation Blanket 10/17/2023

Inspection 4710383 NRC CETI: SSMP Room Cooler Loose Screws and Panel 10/17/2023

Ajar

4710385 NRC CETI: Oil Underneath Safe Shutdown Makeup Pump 10/17/2023

4710389 NRC CETI: Inactive Oil Leak on U2 EDG Fuel Prime Pump 10/17/2023

Outlet

4710694 NRC CETI: Grease on RCIC Discharge Line 2-1305-4" 10/18/2023

4710696 NRC CETI: Hanging Drops on 2-1301-43 10/18/2023

4710698 NRC CETI: 2B CS Motor Lower Oil Level 10/18/2023

4710700 NRC CETI: Scaffold Clamp on U2 RCIC Room Cooler 10/18/2023

Support

4710718 NRC CETI: U1 & U2 Battery Room Housekeeping Items 10/18/2023

4710719 NRC CETI: U2 SR 250VDC Battery Cell Foam Spacer 10/18/2023

Missing

4710720 NRC CETI: U2 SR 125VDC Battery Cell Foam Spacer 10/18/2023

4710868 NRC CETI: U2 EDG Gap Underneath Bolt 10/19/2023

4711264 NRC CETI 2023 - U1 125 VDC Battery Jumper Bend 10/20/2023

Radius

4711300 NRC CETI: U1 Battery Room Paint Flakes 10/20/2023

4711737 NRC CETI: Discrepancy in HPCI Lesson Plan 10/23/2023

4711809 NRC CETI Incorrect Test Instructions During Diagnostic 10/23/2023

Test

4711853 NRC CETI - 250 VDC Battery Loading 10/23/2023

4711901 NRC CETI: Unit 1 and 2 125 and 250 VDC Battery Foam 10/23/2023

Spacers

4712437 NRC CETI: WR - U1 125 VDC Alternate Battery Rack Foam 10/25/2023

Spacer

4712444 NRC CETI: WR - U1 250 VDC Battery Rack Foam Spacer 10/25/2023

4712448 NRC CETI: WR - U2 125 VDC Alternate Battery Rack Foam 10/25/2023

Spacer

4712450 NRC CETI: WR - U2 250 VDC Battery Rack Foam Spacers 10/25/2023

4712457 NRC CETI: NED-I-EIC-0048 Incorrect Design Inputs 10/25/2023

4712794 NRC CETI Surface Cracking on CCST Pipe Flange Rubber 10/26/2023

Washers

4713731 NRC CETI ID: Editorial Error in IST Program Plan 10/30/2023

4713953 NRC CETI ID: Vendor Oil Sample Silicon Levels 10/31/2023

Discrepancy

4714008 NRC CETI ID: U2 EDG 9-7-2023 Oil Sample in 'Alert' 10/31/2023

4714088 NRC CETI: NED-I-EIC-0227 Outdated Design Input 10/31/2023

4714113 NRC CETI: Discrepancy Identified in HPCI Procedures 10/31/2023

4714408 NRC CETI ID: Discrepancy Between QCIS 1300-03 and 11/01/2023

TS 3.3.6.1

4714417 NRC CETI ID: Motor Terminal Voltage Discrepancy 11/01/2023

4714457 NRC CETI: MOV Valve Factor Below Basis Value 11/01/2023

4714523 NRC CETI: UFSAR Section 5.4.6.3 Phrasing 11/01/2023

4714548 NRC CETI 250 VDC Voltage Drop Calculation 11/01/2023

4714568 NRC CETI ID: Coating Absent on Fuel Oil Piping 11/01/2023

4714785 NRC CETI Question on Previous Op Eval Statement 11/02/2023

4714858 NRC CETI ID: IR 04702971 Missing Operability Discussion 11/02/2023

4714913 NRC CETI ID: Lube Oil Analysis AMP Not Followed 11/02/2023

4714916 NRC CETI: IR Not Initiated for WO 04892430 As-Left 11/02/2023

Results

4715113 NRC CETI: Differential Pressure Across MO 1(2)-1001-11/03/2023

23A/B

4715140 NRC CETI ID: HPCI Steam Line Break UFSAR Basis 11/03/2023

4715983 NRC CETI ID U2 RCIC/Core Spray Operability w/ 2-1301-11/07/2023

Open

4716467 NRC CETI: Drawing M-78 Line Continuation Discrepancy 11/09/2023

4717895 NRC CETI EC 630019 Has an Incomplete Discussion of 11/15/2023

Missiles

Drawings 4E-1653A Wiring Diagram 4160V Switchgear Bus 13 Cubicle 1, 2, 3, AG

4, 5 and 6

4E-2350A Schematic Diagram Engine Control and Generator AG

Excitation Standby Diesel-Generator 2

4E-685 Schematic Diagram 4160-480V XFMR Feed BRK Max F

Recycle Radwaste Sys.

Figure 3.3-1 Fire Zones Elevation 554'-0" 20

K-6580 900 lb. Cast Steel Globe Valves B

M-29; Sheet 2 Diagram of Diesel Generator Fuel Oil Piping AE

M-40 Diagram of Standby Liquid Control Piping AZ

M-4A Environmental Zone Map (Basement Floor Plan) Elevation B

554'-0" Figure 1

M-62; Sheet 1 Diagram of Reactor Feed Piping BV

M-70 Diagram of Safe Shutdown Make-Up Pump System AC

M-72; Sheet 2 Diagram of Service Air Piping Diesel Generator Air Start N

M-78 Diagram of Core Spray Piping BM

M-81 Diagram of Residual Heat Removal Piping CA

M-87; Sheet 1 Diagram of High Pressure Coolant Injection - HPCI Piping BO

71111.21M Drawings M-877 Fire Protection Modification Safe Shutdown Make-Up N

Addition

M-879 Fire Protection Modification Safe Shutdown Make-Up Pump E

Addition

M-89; Sheet 1 Diagram of Reactor Core Isolation Cooling RCIC Piping BJ

Engineering 354887 Issue Major Revision to Calculation NED-I-EIC-0139 to Set 0

Changes the Status to Historical

365384 HPCI Turning Gear Performance on HPCI System 0

Operability

381655 Evaluation of Gouges on CCST Walls 0

27233 EOC U-1 Replacement of Merlin Gerin Breakers in Bus 13 0

630019 Appendix J Local Leak Rate Testing Scope Reduction for 0

CS, RHR, and SBLC Systems - Owner's Acceptance

Review

631230 U-1 and U 1-2 DGCW Piping Crosstie to the Piping to the 0

ECCS Room Coolers with Isolation Valve

631231 U-2 Add Isolation Valve to the U-2 to 1/2 DGCW Piping 0

Crosstie to the ECCS Room Coolers

633788 CCST Floor Replacement 0

638169 2-1301-81 Evaluation of Alternate Valve Operating Method 0

639997 Technical Evaluation for Quad Cities HPCI Elevated Flow 0

Rate

Miscellaneous SSMP - System Health Report 10/06/2023

U2 EDG (2-6601CR) Oil Sample Result Summary 10/02/2023

(2019-2023)

19-R16-012 Changes due to Appendix J Local Leak Rate Testing Scope 03/09/2020

Reduction for CS, RHR, and SBLC Systems

ES1800018 Engineering Safety Analysis Transmittal of Design 0

Information - Quad Cities Unit 1 Cycle 26 Plant Parameters

Document

IST-QDC-BDOC-Quad Cities - Inservice Testing Basis Document 03/05/2019

IST-QDC-PLAN Quad Cities Station Units 1 & 2, Inservice Testing Program 0

Plan Sixth Ten-Year Interval

IST-QDC-PLAN Quad Cities Station Units 1& 2, Inservice Testing Program 6

Plan Fifth Ten-Year Interval

71111.21M Miscellaneous QC-E-2021-001 50.59 Evaluation for Modification to Install Alternate HPCI 1

Signal Converter to Replace Functions of FY 1(2)-2386-A

with FY 1(2)-2386-B

QC-S-2020-0048 Add EDG Overload Ratings to UFSAR Table 8.3-1 and 0

Revised Bases B3.8.1

QC-S-2020-0057 50.59 Evaluation to Revise Bases B 3.8.4 to Clarify the 250 0

VDC Battery Sizing Methodology

QC-S-2021-0019 50.59 Evaluation for TMOD to Crosstie the Non-ESS 250 3

VDC Batteries to Support U1 and U2 Battery Replacements

QC-S-2023-0008 QCOP and QCOS 2300 Series Procedure Changes to 1

Leave the HPCI Turning Gear in PULL TO STOP

QC-TRM-19-006 Technical Requirements Manual QC-TRM-19-006 Change 03/23/2019

Package - New TS 3.5.2 Implemented Under Amendment

273 and 268 Requires a Single ECCS Pump to Be Operable

in Modes 4 and 5

QR-017002-6 Qualification Report GNB N-Series Flooded Stationary 1

Battery Cells

Quad Cities 5th Interval Valve Basis Report 04/26/2023

Inservice Testing

Program

Specification R-Specification for Miscellaneous Erected Tanks 09/25/1967

2379

Temporary HPCI Pump Operability Test 91a

Procedure

Change #3697

Operability 639697 U2 EDG - Pressure Control Valve 0

Evaluations

Procedures CY-AB-120-200 Storage Tanks Chemistry 15

ER-AA-302-1003 MOV Margin Analysis and Periodic Verification Test 11

Intervals

ER-AA-302-1009 Final JOG MOV Periodic Verification Program 3

Implementation

ER-QC-330-1003 4.1.7 Reactor Core Isolation Cooling System 2

MA-AA-723-300 Diagnostic Testing of Motor Operated Valves 14

MA-AA-734-400 Constant Level Oiler and Sight-Glass Maintenance 2

MA-QC-722-023 CCST Level Switch Calibration Surveillance 4

MA-QC-IM-1-Unit 1 Low Reactor Pressure Isolation Calibration and 6

201 Channel Functional Test

OP-AA-108-115 Operability Determinations (CM-1) 26

QCA 100 RPV Control 13

QCAP 0400-17 Station Lubrication Program 48

QCEM 0100-03 125/250 VDC Battery Replacement (Out-of-Service) 19

QCIS 1300-05 RCIC Turbine Area High Temperature Isolation Calibration 11

and Functional Test

QCOP 2300-15 Unit 1 HPCI Preparation For Standby Operation 16, 18

QCOP 2900-01 Safe Shutdown Makeup Pump System Preparation for 42

Standby Operation

QCOP 2900-02 Safe Shutdown Makeup Pump System Preparation for Start 32

Up

QCOP 6500-07 Racking in a 4160 Volt Horizontal Type AMHG, G26 or 44

GEHR Circuit Breaker

QCOS 0010-04 Operations Master Lubrication List 61

QCOS 0020-02 Safety System Monthly Manual Valve Position Verification22

QCOS 0100-17 RHR Containment Spray Line Isolation Valve Local Leak 1

Rate Test MO 1(2)-1001-26A/B

QCOS 1100-14 Standby Liquid Control System Outage Surveillance 10

QCOS 1300-05 RCIC Pump Operability Test 65

QCOS 1300-11 RCIC Valve Position Verification 11

QCOS 1300-21 RCIC Keep Fill Valve Lineup Verification 6

QCOS 2300-05 HPCI Pump Operability Test 92

QCOS 6900-02 Station Safety Related Battery Quarterly Surveillance 46

QCTP 0130-01 Primary Containment Leakrate Testing Program 31

QIP 0100-19 Calibration of IST Instruments Used by Operating 31

Department in Performing Operating Department

Surveillance Requirements

QOP 5750-17 ECCS Room Coolers 18, 20

Work Orders 01518269 Recommend Spring Pack Change on MO-2-1301-61 01/02/2018

01700989-01 Adjust Limits On 2-2901-8 After Valve Manually Torqued 06/03/2014

01714376 (LR) B CCST External Inspection 08/16/2015

01714377 (LR) A CCST External Inspection 08/16/2015

01956964 RCIC Turbine Area High Temp Isolation Cal/Func Test 12/11/2017

01960064 RCIC LP Flow Rate Test 04/07/2018

01960181 RCIC Man Init / Auto Injection (IST) 04/08/2018

04759622 Prog Mechanical Inspection and Stem Lube (MOV) 12/23/2019

04778347-01 (LR) Inspect EDG Start Air Flex Hoses 11/02/2020

04798543 RCIC Turbine Area High Temp Isolation Cal/Func Test 12/18/2019

04798931 RCIC LP Flow Rate Test 04/14/2020

04846830 Attachment 1 HX Inspection Report - 2B Core Spray Room 06/09/2020

Cooler

04846830-01 2B Core Spray Air/Water Side Room CLR CLN/INSP 06/05/2020

04888780 (LR) B CCST External Inspection 09/15/2020

04888781 (LR) A CCST External Inspection 09/15/2020

04892430 Install Close Torque Switch Bypass and Change Gearing 02/18/2021

EC 404721

04919053-01 (LR) Replace EDG Lube Oil Flex Hoses 11/04/2021

04970364 RCIC Flow Controller FIC 2-1340-1 Upgrade EC 621167 05/07/2020

04970694-01 (LR) Replace EDG Fuel Oil Flex Hoses 11/02/2020

05047372-01 SSMP Flow Rate Test Comprehensive Test (IST) 11/24/2021

05073932 250 VDC Battery Modified Performance Service Test 03/30/2022

05073932-03 Intercell Resistance Readings 03/27/2022

05075199 Prog Stem Lube Only (MOV) 12/12/2021

05075202 RCIC Turbine Area High Temp Isolation Cal/Func Test 03/26/2022

05079887 RCIC Flow Rate Test Comprehensive Test (IST) 12/14/2021

05146149 MM Replace A CCST External Weather Sealant 10/29/2021

05152377-01 DG Fuel Oil Transfer Pump Comprehensive Test IST 11/03/2022

05158752-01 Safe Shutdown Make-Up Pump Performance Test 02/23/2023

05162263-01 EM Perform Diagnostic Test On MOV-2-2901-8 IST 10Y 01/30/2023

231566 EM Replacement for U2 250V SR Battery 06/16/2023

238566 RCIC Vent Verification 09/07/2022

238571 RCIC System UT Vent Verification 09/06/2022

249745-01 Diesel Generator Timed Start (IST) 09/23/2022

252397 RCIC Flow Rate Test Comprehensive Test (IST) 04/23/2022

254370-01 (LR) Diesel Generator Load Test (IST) 05/04/2022

269381 RCIC Valve Timing Test (IST) 09/06/2022

289768-01 SSMP Valve Operability (IST) 11/23/2022

289769 SSMP Flow Rate Test (IST) 11/23/2022

290894 RCIC System UT Vent Verification 03/06/2023

291250 RCIC Vent Verification 03/07/2023

292140 (IST) (NEIL) RCIC Pump Operability 12/16/2022

292142 RCIC Valve Timing Test (IST) 12/09/2022

299284 MM Replace Caulk 0-3303-A Foundation 10/21/2022

05300175-01 Diesel Generator Timed Start (IST) 03/27/2023

05301267-02 Clean Corrosion from Safety-Related Batteries 11/14/2022

05308154-01 Diesel Generator Air Compressor Operability (IST) 01/30/2023

05309405-01 DG Fuel Oil Transfer Pump Flow Rate 01/30/2023

05315322-01 SSMP Flow Rate Test (IST) 02/23/2023

05315323-01 SSMP Valve Operability (IST) 02/23/2023

05320903 RCIC Valve Timing Test (IST) 03/06/2023

05324503 (IST) (NEIL) RCIC Pump Operability 03/07/2023

05342544 RCIC System UT Vent Verification 09/18/2023

05342876 RCIC Vent Verification 09/06/2023

05372764 CCST/Torus Level Switch Functional Test 09/13/2023

05372765 CCST/Torus Level Switch Functional Test 09/13/2023

05375541 (IST) (NEIL) RCIC Pump Operability 09/08/2023

05393546 ECCS Room and DGCWP Cubicle CLR DP Test 09/07/2023

05399737 ECCS Room and DGCWP Cubicle CLR DP Test 10/12/2023

05400461 HPCI MGU Did Not Respond as Expected During QCOS 09/19/2023

2300-05

05407837 Operations Department Summary of Daily Surveillance 10/14/2023

33