IR 05000498/2018002

NRC Integrated Inspection Report 05000498/2018002 and 0500499/2018002 and Independent Spent Fuel Storage Installation Inspection Report 07201041/2018001

ML18221A385
Person / Time
Site:	South Texas, 07201041
Issue date:	08/08/2018
From:	Nick Taylor NRC/RGN-IV/DRP/RPB-B
To:	Gerry Powell South Texas
References
IR 2018001
Download: ML18221A385 (34)

Text

August 8, 2018

SUBJECT:

SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION - NRC INTEGRATED INSPECTION REPORT 05000498/2018002 AND 0500499/2018002 AND INDEPENDENT SPENT FUEL STORAGE INSTALLATION INSPECTION REPORT 07201041/2018001

Dear Mr. Powell:

On June 30, 2018, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your South Texas Project Electric Generating Station Units 1 and 2. On July 26, 2018, 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.

No NRC-identified or self-revealing findings were identified during this inspection.

However, inspectors documented a licensee-identified violation which was determined to be of very low safety significance in this report. The NRC is treating this violation as non-cited violation (NCV) consistent with Section 2.3.2 of the Enforcement Policy

If you contest the violation or significance of the NCV, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the U.S. Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region IV; the Director, Office of Enforcement; and the NRC resident inspector at the South Texas Project. 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/

Nicholas H. Taylor, Branch Chief Project Branch B Division of Reactor Projects

Docket Nos. 50-498; 50-499, and 07201041 License Nos. NPF-76 and NPF-80

Enclosure:

Inspection Report 05000498/2018002, 05000499/2018002, and 07201041/2018001 w/Attachments:

1. Supplemental Information 2. Initial Request for Information 3. Notification of Inspection and Request for Information

Enclosure U.S. NUCLEAR REGULATORY COMMISSION

Inspection Report

Docket Number(s):

05000498; 05000499, and 07201041

License Number(s):

NPF-76 and NPF-80

Report Number(s):

05000498/2018002, 05000499/2018002, and 07201041/2018001

Enterprise Identifier: I-2018-002-0004 and I-2018-001-0090

Licensee:

STP Nuclear Operating Company

Facility:

South Texas Project Electric Generating Station, Units 1 and 2

Location:

Wadsworth, Texas

Inspection Dates:

April 1, 2018 to June 30, 2018

Inspectors:

A. Sanchez, Senior Resident Inspector

N. Hernandez, Resident Inspector

J. Choate, Resident Inspector

I. Anchondo, Reactor Inspector

L. Brookhart, Senior ISFSI Inspector, FCDB

E. Simpson, ISFSI Inspector, FCDB

Approved By:

Nicholas H. Taylor

Chief, Project Branch B

Division of Reactor Projects

SUMMARY

The U.S. Nuclear Regulatory Commission (NRC) continued monitoring the licensees performance by conducting a quarterly integrated inspection at South Texas Projects Units 1 and 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.

Licensee-identified non-cited violations are documented in report section: 71153.

Additional Tracking Items

Type Issue number Title Inspection Procedure Status LER 05000498/2017001-00 Unit 1 Failure of a Timing Relay During a Technical Specification Shutdown 71153 Closed

PLANT STATUS

Unit 1 began the inspection period at rated thermal power. On June 25, 2018, the unit was down powered to approximately 48 percent due to an excessive steam demand event. The excessive steam demand was the result of a failed circuit card that caused both main steam pegging valves to open and admit steam to the deaerator. The valves were isolated and the unit was returned to full power later that night. The unit remained at full power for the remainder of the inspection period.

Unit 2 began the inspection period in refueling outage 2RE19. The unit was returned to full percent thermal power on April 29, 2018, and remained there for the rest of the inspection period.

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

Seasonal Extreme Weather (1 Sample)

The inspectors evaluated readiness for seasonal extreme weather conditions prior to the onset of hurricane season.

71111.04 - Equipment Alignment

Partial Walkdown (5 Samples)

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

(1) Unit 2, train B emergency diesel generator on April 10, 2018.

(2) Unit 1, train B essential cooling water system on May 8, 2018

(3) Unit 2, train B essential chilled water system May 14, 2018

(4) Unit 1, train A and B emergency diesel generators on May 24, 2018

(5) Unit 2, train B emergency diesel generator on May 24, 2018

Complete Walkdown (1 Sample)

The inspectors evaluated system configurations during a complete walkdown of the Unit 2 train C essential cooling water system on June 28, 2018.

===71111.05AQFire Protection Annual/Quarterly

Quarterly Inspection===

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

(1) Unit 2, reactor containment building, southwest peripheral area, Room 308SW, Fire Area 63, Fire Zone Z207 on April 3, 2018

(2) Unit 1, technical support center diesel generator, Fire Area 99, Fire Zone Z912 on April 5, 2018

(3) Unit 1, train A essential cooling water pump room, Fire Area 53, Fire Zone Z600 on April 9, 2018

(4) Unit 2, turbine generator building, 55 foot elevation, Room 201A, Fire Area 90, Fire Zone Z712 on April 16, 2018

(5) Unit 2, mechanical auxiliary building, 41 foot elevation (radiological controlled area), Fire Area 03, Fire Zone Z147 on April 27, 2018

(6) Unit 2, essential cooling water intake structure pump rooms A, B and C, Fire Areas 56, 57 and 58, Fire Zones Z603, Z604 and Z605 on May 22, 2018

Annual Inspection (1 Sample)

The inspectors evaluated fire brigade performance for a simulated fire in the Unit 1 main turbine lube oil conditioner skid on January 24, 2018.

The inspectors evaluated fire brigade performance for a simulated fire in the Unit 2 technical support center diesel on May 23, 2018.

71111.07Heat Sink Performance Heat Sink

The inspectors inspected and evaluated the Unit 2, train C emergency diesel generator jacket water and lube oil heat exchangers physical condition on May 23, 2018.

71111.08Inservice Inspection Activities

The inspectors evaluated pressurized water reactor non-destructive testing by reviewing the following examinations from March 26 to April 23, 2018:

The inspectors directly observed the following nondestructive examinations:

(1) Ultrasonic Testing a) Feedwater System, Weld 18-FW-2029-AA2, Record Number UT-2018-024 b) Feedwater System, Weld 18-FW-2030-AA2, Record Number UT-2018-025 c) Reactor Coolant System, Weld 4 on 4-RC-2320-BB1, Record Number UT-2018-025 d) Reactor Coolant System, Weld 5 on 4-RC-2320-BB1, Record Number UT-2018-030 e) Reactor Coolant System, Weld 11 on 4-RC-2320-BB1, Record Number UT-2018-022 The inspectors reviewed records for the following nondestructive examinations:

(2) Ultrasonic Testing a) Reactor Coolant System, Weld 10 on 4-RC-2320-BB1, Record Number UT-2018-021 b) Reactor Coolant System, Weld 6-RC-2012-BB1, Record Number UT-2018-055 c) Reactor Coolant System, Weld 16-RC-2412-NSS, Record Number UT-2018-065

Vessel Upper Head Penetration Inspection Activities

No vessel upper head inspections were performed during 2RE19 outage.

Boric Acid Corrosion Control Inspection Activities

The Inspectors evaluated the licensees boric acid control program performance.

Steam Generator Tube Inspection Activities

The inspectors reviewed the steam generator (SG) tube eddy current test (ECT) scope and expansion criteria to determine whether these criteria met technical specification requirements, Electric Power Research Institute (EPRI) guidelines, and commitments made to the NRC. The inspectors also reviewed whether the ECT inspection scope included areas of degradations that were known to represent potential ECT test challenges, such as the top of tube sheet, tube support plates (TSP), and U-bends. The inspectors confirmed that no repairs were required at the time of the inspection.

Steam Generator Inspection

The inspectors verified that the number and sizes of SG tube flaws/degradation identified were consistent with the licensees previous outage operational assessment predictions.

The inspectors verified that steam generator ECT scope and expansion criteria met technical specification requirements.

The inspectors verified that ECT probes and equipment configurations used to acquire data from the SG tubes were qualified to detect the known/expected types of SG tube degradation in accordance with Appendix H, Performance Demonstration for Eddy Current Examination, of EPRI Document 1013706.

The inspectors reviewed the licensees identification of the following tube degradation mechanisms:

• Tube wear at TSP intersections

• Pitting under hardened top of tubesheet sludge deposits The inspectors verified that the licensees ECT scope included the new degradation mechanism and fully enveloped the problem, and has taken appropriate corrective actions before plant start-up.

Secondary Side Inspections

The inspectors reviewed secondary side inspection results and verified the licensee took corrective actions in response to the observed degradation.

The inspectors reviewed the licensees actions in response to a dropped lithium-ion battery that was left in place at the tube bundle U-bend lodged between two tubes (Row 95/Column 119 and Row 96/Column 118). The inspectors reviewed the licensees loose part and chemical analysis and concluded that all the EPRI and regulatory requirements had been met.

Identification and Resolution of Problems (71111.08-02.05)

The inspectors reviewed 15 condition reports which dealt with inservice inspection activities and found the corrective actions for inservice inspection issues were appropriate.

71111.11Licensed Operator Requalification Program and Licensed Operator Performance Operator Requalification

The inspectors observed and evaluated Unit 2 crew simulator scenario involving a stuck open main steam safety valve, a small break loss-of-coolant event, and a faulted steam generator on June 26, 2018.

Operator Performance (1 Sample)

The inspectors observed and evaluated the performance of Unit 2 licensed control room operators during a period of heightened risk for mid-loop operations on April 17, 2018. The inspectors also observed and evaluated the performance of Unit 2 licensed control room operators during transition into Mode 4 on April 24, 2018.

The inspectors observed and evaluated the performance of Unit 1 licensed control room operators increasing reactor power from 48 percent to 63 percent following an unexpected reactor down power resulting from an excessive steam demand event on June 25, 2018.

71111.12Maintenance Effectiveness Routine Maintenance Effectiveness

The inspectors evaluated the effectiveness of routine maintenance activities associated with the following equipment and/or safety significant functions:

(1) Unit 1, train S solid state protection system power supply failure on May 20, 2018

71111.13Maintenance Risk Assessments and Emergent Work Control

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

(1) Unit 1 elevated risk due to planned maintenance on the 345kV North bus and standby transformer 1 on April 30, 2018

(2) Unit 1 elevated risk due to planned train C work week maintenance activities for the week of May 7-13, 2018

(3) Unit 2 elevated risk due to planned maintenance on train B essential chilled water going longer than planned for on May 8-11, 2018

(4) Unit 1 elevated risk due to an unplanned entry into the configuration risk management program for exceeding the train C emergency diesel generator 14 day limited condition for operations due to flood panel modification on May 21, 2018

(5) Unit 1 elevated risk due to an unplanned power supply maintenance for train S solid state protection system power supply replacement on May 22, 2018

(6) Units 1 and 2 elevated risk to unplanned diesel driven fire pump 2 that failed functionality test and the unplanned failure of the emergency transformer the week of June 25, 2018

71111.15Operability Determinations and Functionality Assessments

The inspectors evaluated the following operability determinations and functionality assessments:

(1) Unit 2, steam generator C and reactor coolant system integrity following the loss of a camera battery in the secondary side of the steam generator during an engineering inspection on April 18, 2018

(2) Unit 2, nuclear instrumentation, NI-32 following aberrant behavior on April 25, 2018

(3) Unit 1, train C emergency diesel generator following leakage through watertight flood panels on June 1, 2018

(4) Unit 2, hot leg B narrow range temperature element resistance thermocouple detector exceeding drift acceptance criteria on April 25, 2018

71111.18Plant Modifications

The inspectors evaluated the following temporary or permanent modifications:

(1) Unit 2, spent fuel pool cooling pump 2B temporary power supply on April 6, 2018

(2) Unit 1, train C emergency diesel generator flood panel permanent modification to seal them completely on June 25, 2018

71111.19Post Maintenance Testing

The inspectors evaluated the following post maintenance tests:

(1) Unit 2, train C essential cooling water pump following planned maintenance on April 8, 2018

(2) Unit 2, turbine-driven auxiliary feedwater pump following maintenance during refueling outage 2RE19 on April 25, 2018

(3) Unit 1, loop 1 delta-T and T-average channel following emergent circuit card replacement on April 26, 2018

(4) Unit 2, train A 125Vdc battery following the emergent ground circuit card failure of battery charger 2 on May 5, 2018

(5) Unit 2, train C emergency diesel generator following six year overhaul on May 25, 2018

(6) Diesel-driven fire pump 2 following maintenance on June 29, 2018

71111.20Refueling and Other Outage Activities

The inspectors evaluated refueling outage 2RE19 activities from April 1-27, 2018. The inspectors completed inspection procedure Sections 03.01.d, and 03.01.e. The Unit 2 refueling outage 2RE19 began March 24, 2018.

===71111.22Surveillance Testing

The inspectors evaluated the following surveillance tests:

Routine===

(1) 0PSP03-DG-0016, Unit 2, train B emergency diesel generator twenty-four hour load test on April 10, 2018

(2) 0PSP03-RS-0001, Unit 1, control rod surveillance test on May 12, 2018

(3) 0PMP08-MS-0557, Unit 2, main steam pressure transmitter, PT506, calibration on June 20, 2018

Containment Isolation Valve (1 Sample)

(1) Unit 2, train A high head safety injection discharge local leak rate test on April 9, 2018

71114.06Drill Evaluation Emergency Planning Drill

The inspectors evaluated the licensees emergency response drill involving failed fuel, steam generator tube rupture and a stuck open main steam isolation valve which resulted in a general emergency on May 1,

OTHER ACTIVITIES - BASELINE

71151Performance Indicator Verification

The inspectors verified licensee performance indicators submittals listed below:

(1) MS05: Safety System Functional Failures (SSFFs) Sample (04/01/2017-03/31/2018)

(2) BI01: Reactor Coolant System (RCS) Specific Activity Sample (04/01/2017-03/31/2018)

(3) BI02: RCS Leak Rate Sample (04/01/2017- 03/31/2018)

71152Problem Identification and Resolution Semiannual Trend Review

The inspectors reviewed the licensees corrective action program for trends that might be indicative of a more significant safety issue.

Annual Follow-up of Selected Issues (1 Sample)

The inspectors reviewed the licensees implementation of its corrective action program related to the following issues:

(1) Auxiliary open loop cooling system pipe break, Condition Report 17-12892. Inspectors reviewed the apparent cause investigation, operability evaluation, and interviewed licensee personnel.

71153Follow-up of Events and Notices of Enforcement Discretion Licensee Event Reports

The inspectors evaluated the following licensee event reports which can be accessed at https://lersearch.inl.gov/LERSearchCriteria.aspx:

(1) Licensee Event Report (LER) 05000498/2017-001-00, Unit 1 Failure of a Timing Relay During a Technical Specification Shutdown, on May 11, 2017

Personnel Performance (1 Sample)

The inspectors evaluated operator performance for the failure of a circuit card that resulted in an excessive steam demand event that resulted in Unit 1 reactor down power to approximately 48 percent power on June 25,

OTHER ACTIVITIES

- TEMPORARY INSTRUCTIONS, INFREQUENT AND ABNORMAL

60854Preoperational Testing of an Independent Spent Fuel Storage Inspection (ISFSI)

An ISFSI inspection was conducted at the STP on February 5-8 and 19-23, 2018, by Region IV, Division of Nuclear Material Safety inspectors. Subsequently, an in-office review of additional documentation related to the licensees ISFSI preparations was performed through May 2018. The purpose of the inspections was to observe and evaluate the licensees pre-operational demonstrations required by the Holtec HI-STORM FW Certificate of Compliance (COC), which STP had selected to use under their general Part 72 license. The demonstrations were conducted in accordance with the conditions and requirements specified in the Holtec HI-STORM FW Storage System COC 1032 Amendment 2 and HI-STORM FW Final Safety Analysis Report (FSAR) Revision 5.

The License Condition No. 9 of the COC listed pre-operational testing and training exercises required to be completed by a general licensee. During the February inspection dates the NRC inspectors observed STP perform the following demonstrations: Multi-Purpose Canister (MPC)welding, Non-Destructive Examination (NDE) inspections, pressure testing, draining, and moisture removal using Forced Helium Dehydration (FHD), helium backfilling, and flooding the MPC cavity for unloading operations. The licensee had successfully completed the above listed operations and fully demonstrated that the procedures, programs, and training related to those dry cask storage operations had been successfully integrated into their site operations. The site still has a number of demonstrations that are required to be completed before the licensee can utilize the HI-STORM FW casks. Those demonstrations are projected to be performed in the winter 2018.

The ISFSI activities specifically reviewed during the on-site inspections and the subsequent in-office review included:

(1) Evaluated and observed dry run operations, listed above, associated with License Condition No. 9.

(2) Reviewed welder qualification program, welder performance qualifications, welding procedure specifications, and welding procedure qualification records.

(3) Reviewed NDE program procedure, NDE personnel certification records, the qualification program for visual test and liquid penetrant exams, liquid penetrant procedure, visual testing procedure, and helium leak testing procedure.

(4) Review Certified Material Test reports for liquid penetrant chemicals, welder filler metals, and helium purity certification records.

(5) Reviewed the licensees calibration program to ensure the following devices were adequately calibrated in accordance with the licensees quality assurance program:

hydrogen monitoring equipment, flow rate meters, canister pressure gauges, temperature gages, moisture gages for FHD, and pressure relief valves.

(6) Reviewed the licensees training qualification program for workers conducting activities on Important to Safety components.

(7) Evaluated and observed licensees implementation of hydrogen monitoring during welding operations.

(8) Evaluated and observed licensees radiation protection implementation during the dry run observations.

(9) Evaluated and observed licensees implementation of foreign material exclusion process during welding and fluid movement demonstrations.

(10) Reviewed licensees procedures to process the MPC regarding alternate cooling, pressure testing, drying, backfilling, canister gas sampling, and re-flooding.

The inspectors did not identify any issues of concerns requiring documentation.

INSPECTION RESULTS

Observations

71152 - Semiannual

Trend Review The inspectors identified a negative trend in the area of interdepartmental teamwork impacting station performance. Specifically, while inspecting serval different issues at the site, the inspectors concluded that there was a common theme of a lack of communication and coordination among the departments to resolve issues in a timely way. Some examples include:

• A 10 CFR 50.65(a)(4) violation (Condition Report 18-4707) for the failure to perform a risk assessment for planned maintenance (lack of coordination) that could have resulted in a reactor shutdown and was documented in NRC Inspection Report 05000498/2018001

• A 10 CFR Part 50, Appendix B, Criterion XVI violation (Condition Report 18-4708) for the failure to promptly identify and correct a condition adverse to quality associated with Unit 2 reactor containment fan cooler backdraft damper degradation (lack of coordination between, engineering, operations and maintenance) and was documented in NRC Inspection Report 05000498/2018001

• Lack of coordination and alignment on Unit 1, train C 125Vdc battery ventilation heater troubleshooting activities and the operability determination (Condition Reports 18-1931 and 18-6409)

• Lack of coordination, and communications for breaker relay calibrations on protected train during 345kV north bus and standby transformer 1 outage (Condition Report 18-6019)

The licensee has acknowledged the trend and entered the NRC identified trend into the corrective action program as Condition Report 18-6213.

Corrective Action Reference: Condition Report 18-6213

Licensee-Identified Non-Cited Violation 71153 - Licensee Event Reports

This violation of very low safety significance was identified by the licensee, has been entered into the licensees corrective action program and is being treated as a Non-Cited Violation, consistent with Section 2.3.2 of the Enforcement Policy.

Violation: Technical Specification 6.8.1.a requires that, Written procedures shall be established, implemented, and maintained covering the activities referenced below: The applicable procedures recommended in Appendix A of Regulatory Guide 1.33, Revision 2, February 1978. Section 9.a, Procedures for Performing Maintenance, states, in part, that Maintenance that can affect the performance of safety-related equipment should be properly preplanned and performed in accordance with written procedures, documented instructions, or drawings appropriate to the circumstances. The licensee established Procedure COM-0001, Conduct of Maintenance, to guide maintenance craft on what to do if a condition or issue arises during a maintenance activity. Specifically, Section 1.4 Supervisor Responsibilities, states, in part, that, If we cannot find the problem with the component or piece of equipment, the issue must be raised to the Division Manager/General Supervisor BEFORE we close the work control document AND return the equipment to operations.

Contrary to the above, on March 10, 2017, Unit 1 E1B undervoltage relay was found outside the technical specification acceptance criteria, and was retested until the relay it was back in tolerance and placed back into service (declared operable) instead of raising the issue up to the division manager for further evaluation. The issue was discussed with the electrical maintenance supervisor and the findings were documented in Condition Report 17-12616.

The relay was declared operable and placed back into service. Subsequently, after review of the condition report, approximately 99 hours0.00115 days <br />0.0275 hours <br />1.636905e-4 weeks <br />3.76695e-5 months <br /> after the relay was declared inoperable, the relay was replaced, and the system declared operable.

Significance/Severity Level: The inspectors determined the performance deficiency was more than minor because it adversely affected the equipment performance attribute of the Mitigating Systems Cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences (i.e., core damage). Specifically, the undervoltage relay was outside its tolerance and placed back into service without correcting the cause of being outside its tolerance. The inspectors assessed the significance of the finding using Exhibit 2, Mitigating Systems Screening Questions, of Inspection Manual Chapter 0609, Appendix A, Significance Determination Process (SDP) for Findings At-Power, issued June 19, 2012, and determined this finding is not a deficiency affecting the design or qualification of a mitigating structure, system, and component that maintained its operability or functionality; the finding does not represent a loss of system and/or function; the finding does not represent an actual loss of function of at least a single train for greater than its Technical Specification-allowed outage time; and the finding does not represent an actual loss of function of one or more non-Technical Specification trains of equipment designated as high safety-significant. Therefore, the inspectors determined the finding was of very low safety significance (Green).

Corrective Action Reference: Condition Report 17-12616

Observations 71153 - Follow-up of Events

Unit 1 Excessive Steam Demand Event on June 25, 2018

Event

On June 25, at 2:12 a.m., Unit 1 experienced a transient when the main steam pegging valves opened and pressurized the deaerator (DA) to the point that caused the relief to open (the DA relief valve set point is 235 psig and operated as designed). The DA supplies net positive suction to the feedwater booster pumps and is pressurized to approximately 168 psig at full power. Extraction steam is the normal source of pressurization. During startup, the pressurization of the DA is supplied by the main steam pegging valves. According to the main equipment database, the pegging valves serve no safety function and would fail closed in the event of a loss of instrument air, a loss of extraction steam or reactor trip.

Operators took immediate action to reduce reactor power, and observed a peak thermal power of 102.9 percent. Operations entered the excessive steam demand off-normal procedure and stabilized power at approximately 62 percent power by securing the main steam pegging valves using the switch on the main control board, thus isolating the pressurization source and ending the excessive steam demand event. The quadrant power tilt ratio (QPTR) reached 1.025, exceeding the technical specification limit of 1.02 and the licensee was required by technical specifications to reduce the HI power flux trip to 100 percent from 109 percent within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or reduce power to below 50 percent power.

Due to lack of instrumentation and control resources, operators instead reduced power to approximately 49 percent power and exited the mode of applicability for technical specification 3.2.4. The only other component that failed was one of the condenser steam dumps (PV-7485). The valve was found stuck at 20 percent open due to a broken air line, and operators manually isolated the failed steam dump valve.

The event was run on the simulator and no significant or complicating anomalies were identified in operator or plant performance during the event. Engineering walked the secondary side of the plant and did not identify any other plant issues. The licensee decided to increase reactor power following tagging the main steam pegging valves closed. Reactor engineering provided a reactivity plan and briefed the control room operators. The inspectors observed the activities and power ascension of power from 48 percent to 63 percent power and had no concerns with operator performance. The reactor was restored to 100 percent power on June 25, 2018. Troubleshooting on the controlling channel for the pegging valve discovered a circuit card with a failed high output (which would have driven the pegging valves full open). The card was replaced and the pegging valves have been subsequently been returned to the auto position with no issues.

Engineering concluded that the card failure was random. Engineering is evaluating their classification of important and critical circuit cards in their protective and trip cabinets (7300 system) and, if necessary, will make corrections or make design changes to make the systems more fault tolerant. The inspectors did not identify any performance deficiencies.

Personnel Performance Assessment

Reactor operator performance was timely and appropriate and operators operated the plant in a manner that preserved reactor safety for the excessive steam demand.

Corrective Action Reference: Condition Report 18-7925

EXIT MEETINGS AND DEBRIEFS

On July 26, 2018, the inspector presented the quarterly resident inspector, inspection results to G. Powell, and other members of the licensee staff.

On April 23, 2018, the inspector presented the in-service inspection results to Mr. G. Powell, President and CEO, and other members of the licensee staff.

On May 23, 2018, the inspectors presented the results from the pre-operational ISFSI inspections to Mr. M. Glover, Acting General Manager of Projects, and other members of the licensee staff. Licensee personnel acknowledged the information presented. In all three exit meetings, the inspectors confirmed that proprietary information was controlled to protect from public disclosure.

DOCUMENTS REVIEWED

71111.04Q - Partial Equipment Alignment

Condition Reports (CRs)

18-6254

18-6257

Procedures

Number

Title

Revision

0POP02EW-0001

Essential Cooling Water Operations

71111.04S - Complete Equipment Alignment

Condition Reports (CRs)

18-0110

18-2374

18-5810

Drawings

Number

Title

Revision

5R289F05038

Essential Cooling Water System Train 2C

5R289F05039

Essential Cooling Water System

9-E-PKAC-01

4.16 KV Class 1E Switchgear E2C

Procedures

Number

Title

Revision

0POP02-EQ-0001

Essential Cooling Water System

71111.05A - Annual Fire Drill

Procedures

Number

Title

Revision

0PGP03-ZF-0011

STPEGS Fire Brigade

Fire Drill No.

18-01-02

71111.05Q - Fire Protection Quarterly

Procedures

Number

Title

Revision

0RCB63-FP-0207

Fire Preplan Reactor Containment Building SW Peripheral

Area

1ECW53-FP-0600

Fire Preplan Essential Cooling Water Intake Structure Pump

Room Train A

0TGB90-FP-0712

Fire Preplan Turbine Generator Building Northeast 55

Elevation

0TSC99-FP-0912

Fire Preplan Technical Support Center Diesel Generator

71111.07A - Heat Sink

Coating Permit

34686157

Procedures

Number

Title

Revision

0PGP03-ZE-0080

Essential Cooling Water System Reliability Program

Work Authorization Number (WAN)

501777

501778

71111.08 - Inservice Inspection Activities

Condition Reports (CRs)

05-01321

16-12322

16-12668

16-12979

16-13429

16-13916

16-13977

17-11607

17-14164

17-15237

17-17005

17-20673

17-20674

17-21429

18-04320

Procedures

Number

Title

Revision/Date

PDI-UT-1

Generic Procedure for the Ultrasonic Examination of Ferritic

Pipe Wells

G

PDI-UT-2

Generic Procedure for the Ultrasonic Examination of

Austenitic Pipe Wells

H

PDI-UT-8

Similar and Dissimilar Metal Welds

H

Procedures

Number

Title

Revision/Date

0PSP11-CS-0006

Containment Spray System Rain 1A/2A - Containment

System Leakage Test

0PGP03-ZE-0133

Boric Acid Corrosion Control Program

SG-SGMP-13-22

Steam Generator Cycle 16 Condition Monitoring and

Cycles 17, 18 and 19 Operational Assessment

SG-SGMP-13-3

South Texas Project Electric Generating Station 2R16

Steam Generator Degradation Assessment

LTR-CODE-14-61

2RE16 Secondary Side Integrity Plan

MRS-GEN-1127

Guideline for Steam Generator Eddy Current Data Quality

Requirements

SG-SGMP-18-6

Steam Generator Cycle 19 Condition Monitoring and

Cycles 20,21, and 22 Preliminary Operational Assessment

EVAL-18-12

South Texas Project Electric Generating Station, Unit 2

Steam Generator Secondary Side Lithium-ion Battery Loose

Part

LTR-SGMP-18-13

Evaluation of Lithium-Ion Battery in the Secondary Side of

the South Texas Project Electric Generating Station, Unit 2

Steam Generator - Spring 2018 Refueling Outage (2RE19)

April 17, 2018

TR-CECO-18-004

Chemistry Evaluation of the Lithium-Ion Battery

Loose Part in the South Texas Project Electric Generating

Station, Unit 2 Steam Generator C

April 17, 2018

OPEP10-ZA-004

General Ultrasonic Examination

SG-SGMP-17-31

South Texas Project Electric Generating Station 2RE19

Steam Generator Degradation Assessment

Inservice Testing Program Unit 1 and 2 Pump and Value -

Inservice Test Plan Third 10-Year Interval

Examination Plan for 2E19 ASME Section XI Inservice

Inspection Programs at South Texas Project Electric

Generating Station, Unit 2

March 19,

2018

71111.11Q - Licensed Operator Requalification

Procedures

Number

Title

Revision

0POP03-ZG-0009

Mid-Loop Operations

71111.12 - Maintenance Effectiveness

Condition Reports (CRs)

18-6680

Work Authorization Number (WAN)

589068

71111.13 - Maintenance Risk Assessments and Emergent Work Control

Condition Reports (CRs)

18-6807

Procedures

Number

Title

Revision

0PGP03-ZG-RMTS

Risk-Managed Technical Specifications Program

0POP01-ZO-0006

Risk Managed Actions

0PGP03-ZA-0091

Configuration Risk Management Program

0PGP03-ZO-0055

Protected Components

0POP07-SP-0006S

SSPS Logic Train S Removal from Service and Restoration

(Mode 1-4)

Work Authorization Number (WAN)

23443

589068

Work Activity Risk (WAR)

2774

71111.15 - Operability Evaluations

Condition Reports (CRs)

18-5652

71111.18 - Modifications

Condition Reports (CRs)

18-4610

18-4611

Procedures

Number

Title

Revision

0PMP09-PM-00C

Temporary Configuration Changes to Support Class 1E

Train C MCC Outages

Work Authorization Number (WAN)

579417

560095

71111.19 - Post Maintenance Testing

Condition Reports (CRs)

18-6928

Procedures

Number

Title

Revision

0PSP03-SP-0019D

Turbine Driven Auxiliary Feedwater Actuation and

Response Time Test

0POP07-AM-001

AMSAC Actuation Test Trains A, B, C, & D

0PSP03-AF-0007

Auxiliary Feedwater Pump 12(24) Inservice Test

0PEP07-AF-0001

Auxiliary Feedwater Turbine Overspeed Trip Test

0POP02-DG-0003

Emergency Diesel Generator 13(23)

0OOI01-OL-0005

Operations Logs - Diesel Generator

71111.20 - Outage

Procedures

Number

Title

Revision

0POP03-ZG-0010 Refueling Operations

0POP03-ZG-0009 Mid-Loop Operation

0POP03-ZG-0001 Plant Heatup

0POP08-FH-0009

Core Refueling

Miscellaneous

Title

Date

STP 2RE19/U2C20 Low Power Physics Tests Summary

April 2018

71111.22 - Surveillance

Condition Reports (CRs)

2-22362

18-02240

18-6928

Procedures

Number

Title

Revision

0PMP08-MS-0557 Steam Generator Header Pressure to Steam Dump Control

Calibration

0PSP03-DG-0016 Standby Diesel 11(21) Twenty-Four Hour Load Test

Work Authorization Number (WAN)

455544

4OA5.1 Other Activities (IP 60854)

Condition Reports (CRs)

18-51

18-1461

18-1609

18-1621

18-1625

18-1651

18-1738

Design Basis Documents Drawings

Number

Title

Revision

ISFSI FSAR

HI-STORM FW ISFSI Final Safety Analysis Report

COC 1032

COC and Technical Specifications for HI-STORM FW

Amendment 2

Procedures

Number

Title

Revision

GQP 9.0

PCI Training, Qualification, Examination, and Certification of

NDE Personnel

GQP 9.1

PCI Training, Qualification, Examination, and Certification of

Inspection and Testing Personnel

GQP 9.2

PCI High Temperature Liquid Penetrant Examination and

Acceptance Standards for Welds

GQP 9.6

PCI Visual Examination of Welds

WCP-2

Welder/Welding Operator Performance Qualification

MSLT-MPC Holtec

3665

LTS Helium Mass Spectrometer Leak Test Procedure MPC

0PRP07-ZR-0036

Dry Cask Storage of Spent Fuel

Procedures

Number

Title

Revision

0DCS03-ZO-0004

MPC-37 Closure Operations (Sealing, Drying, and

Backfilling)

0c

0DCS03-ZO-0007

MPC Unloading

0a

PI-CNSTR-STP-H-01 PCI Closure Welding of Holtec MPC

0PGP03-ZT-0138

Contractor Augmentation Training and Qualification

Program

Miscellaneous Documents

Procedures

Number

Title

Revision/Date

Q-16

Leak Test Specialists Certificate of Qualification Package for

numerous individuals

2017-2018

SAP No. 77754

PCI NDE VT/PT Level II Personnel Certificate

June 19,

2017

CMTRs

Sherwin Certification for D-100, D-350, KO-17, KO-19

Liquid Penetrant materials

March 1,

2016

PC-912784

Certificate of Conformance for weld material

January 3,

2018

PCI-WPQs

Welder Performance Qualification Records for numerous

individuals

February

2018

MN-GTAW

PCI Welding Procedure Specification for Manual Gas

Tungsten Arc Welding

MC-GTAW

PCI Welding Procedure Specification Machine Gas

Tungsten Arc Welding

PQR-62

PCI Procedure Qualification Record for WPS 8

PQR-63

PCI Procedure Qualification Record for Manual GTAW

PQR-600

PCI Procedure Qualification Record for Machine GTAW

RWP 2018-0-0152

Radiation Work Plan for Dry Cask Storage Welding and

Helium Dehydration

ARP - 2018

STP ALARA Review Package, First DCS Campaign

Draft

71-0028RK

PCI Instruction Manual Eagle Series, Hydrogen Detector

G

2-5201RK

Engineering Products and Controls Calibration Certification

for Eagle Monitors E11X068, E11X069

April 3, 2017

85-401049784-1

Airgas Certificate of Batch Analysis for high purity helium

November 6,

2017

Procedures

Number

Title

Revision/Date

STPNOC

STP Metrology Laboratory Calibration Form for pressure,

temperature, and due sensor gages

2017-2018

Holtec TCF

Holtec Technician Certification Form for numerous

individuals

February

2018

Initial Request for Information

Integrated Inspection Report 2018-002

South Texas Project

Inspection Report:

05000498/2018002; 05000499/2018002

Inspection Dates:

April 1 - June 30, 2018

Inspection Procedure:

Baseline Inspection Procedures

Lead Inspector:

Alfred Sanchez, Senior Resident Inspector

Information Due Date: April 24, 2018

System of Interest:

Essential Cooling Water (ECW)

The following information should be provided in electronic format (Certrec IMS preferred), to the

attention of Alfred Sanchez by April 24, 2018. The specific items selected from the lists shall be

available and ready for review on the day indicated in this request. *Please provide requested

documentation electronically in pdf files, Excel, or other searchable formats, if possible. The

information should contain descriptive names, and be indexed and hyperlinked to facilitate ease

of use. Information in lists should contain enough information to be easily understood by

someone who has knowledge of pressurized water reactor technology. If requested documents

are large and/or only hard copy formats are available, please inform me and provide subject

documentation.

1.

A list of Essential Cooling Water (ECW) system engineering contacts with phone

numbers.

2.

Any pre-existing evaluation or list of ECW system components and associated

calculations with low design margins.

3.

A list of ECW system related operating experience evaluations for the last 3 years.

4.

A list of all ECW system time-critical operator actions in procedures.

5.

Copies of the initial operator licensed operators training materials.

6.

List of drawings for the system (P&ID)-number and title

7.

ECW maintenance work windows schedules (all trains-both Units) and a summary of

the work to be performed in those windows.

8.

List and schedule of surveillance tests scheduled for the quarter

9.

Complete copies of normal operating, abnormal operating, emergency operating,

surveillance, and alarm response procedures associated with the ECW system

10.

A list of permanent and temporary modifications related to the ECW system sorted

by component for the last 3 years

11.

A list of current ECW system related operator work arounds/burdens.

2.

A list of the ECW system design calculations, which provide the design margin

information for components.

13.

Flooding calculations for the ECW area (Essential Cooling Water Intake Structure),

component cooling water heat exchanger rooms, and common return areas in the

mechanical auxiliary building (including essential chilled water and component cooling

water pump areas)

14.

List of ECW system root cause evaluations associated with component failures

or design issues initiated/completed in the last 5 years.

15.

A list of any ECW system common-cause failures of components in the last 3 years.

16.

A list of condition reports (with descriptions) for the last 2 years

17.

An electronic copy of the ECW system Design Bases Documents and any open,

pending, or recently completed changes. Please include any open, pending, or recently

completed changes to emergency operating, abnormal operating, normal operating,

alarm response, system alignment, surveillance, or other procedure.

18.

An electronic copy of the System Health Report for the ECW system.

19.

A copy of ECW system related audits completed in the last 3 years.

20.

A list of ECW system motor operated valves (MOVs) in the program, design

margin, and risk ranking.

21.

A list of ECW system air operated valves (AOVs) in the valve program, design

margin, and risk ranking.

2.

ECW system structure, system, and components maintenance rule category,

scoping, functional failure evaluations, (a)(1) determinations, (a)(1) goals, and any

supporting basis documentation.

23.

ECW system unavailability and unreliability raw data, and CDE sheets for the last 18

months

24.

A list of high risk ECW system maintenance rule systems/components and functions,

based on engineering or expert panel judgement.

25.

Copies of surveillance packages (last four performances) for all three trains of ECW

systems on both Units.

26.

An Excel spreadsheet of ECW system related probabilistic risk assessment (PRA)

human action basic events or risk ranking of operator actions from your site specific

PSA sorted by risk achievement worth (RAW) and Fussell-Vesely (FV). Provide

copies of your human reliability worksheets for these items.

27.

In so far as there are recent or pending changes, please provide an Excel

spreadsheet of ECW system related equipment basic events (with definitions),

including importance measures sorted by RAW and FV from your internal events

PRA. Include basic events with RAW value of 1.3 or greater.

Information Request

January 23, 2018

Notification of Inspection and Request for Information

South Texas Generating Station, Unit 2

NRC Inspection Report 05000499/2018002

INSERVICE INSPECTION DOCUMENT REQUEST

A. Information Requested for the In-Office Preparation Week

The following information should be sent to the Region IV office in hard copy or electronic

format (ims.certrec.com preferred), in care of Isaac Anchondo, by March 26, 2018, to

facilitate the selection of specific items that will be reviewed during the onsite inspection

week. The inspector will select specific items from the information requested below and then

request from your staff additional documents needed during the onsite inspection week

(Section B of this enclosure). We ask that the specific items selected from the lists be

available and ready for review on the first day of inspection. Please provide requested

documentation electronically if possible. If requested documents are large and only hard

copy formats are available, please inform the inspector(s), and provide subject

documentation during the first day of the onsite inspection.

If you have any questions regarding this information request, please call the inspector as

soon as possible.

On April 9, 2018, a reactor inspector from the Nuclear Regulatory Commissions (NRC)

Region IV office will perform the baseline inservice inspection at South Texas Generating

Station, Unit 2, using NRC Inspection Procedure 71111.08, "Inservice Inspection Activities.

Experience has shown that this inspection is a resource intensive inspection both for the

NRC inspector and your staff. The date of this inspection may change dependent on the

outage schedule you provide. In order to minimize the impact to your onsite resources and

to ensure a productive inspection, we have enclosed a request for documents needed for

this inspection. These documents have been divided into two groups. The first group

(Section A of the enclosure) identified information to be provided prior to the inspection to

ensure that the inspector is adequately prepared. The second group (Section B of the

enclosure) identifies the information the inspector will need upon arrival at the site. It is

important that all of these documents are up to date and complete in order to minimize the

number of additional documents requested during the preparation and/or the onsite portions

of the inspection.

We have discussed the schedule for these inspection activities with your staff and

understand that our regulatory contact for this inspection will be Rafael Gonzales of your

licensing organization. The tentative inspection schedule is as follows:

Preparation week: March 26, 2018

Onsite weeks: April 9-13 (1st week), TBD (week 2), 2018

Our inspection dates are subject to change based on your updated schedule of outage

activities. If there are any questions about this inspection or the material requested, please

contact Isaac Anchondo at (817) 200-1152 (Email to Isaac.Anchondo@nrc.gov).

A.1

ISI/Welding Programs and Schedule Information

1. A detailed schedule (including preliminary dates) of:

1.1. Nondestructive examinations planned for ASME Code Class Components

performed as part of your ASME Section XI, risk informed (if applicable), and

augmented inservice inspection programs during the upcoming outage.

1.2. Examinations planned for Alloy 82/182/600 components that are not included in

the Section XI scope (If applicable)

1.3. Examinations planned as part of your boric acid corrosion control program

(Mode 3 walkdowns, bolted connection walkdowns, etc.)

1.4. Welding activities that are scheduled to be completed during the upcoming

outage (ASME Class 1, 2, or 3 structures, systems, or components)

2. A copy of ASME Section XI Code Relief Requests and associated NRC safety

evaluations applicable to the examinations identified above.

2.1. A list of ASME Code Cases currently being used to include the system and/or

component the Code Case is being applied to.

3. A list of nondestructive examination reports which have identified recordable or

rejectable indications on any ASME Code Class components since the beginning of

the last refueling outage. This should include the previousSection XI pressure

test(s) conducted during start up and any evaluations associated with the results of

the pressure tests.

4. A list including a brief description (e.g., system, code class, weld category,

nondestructive examination performed) associated with the repair/replacement

activities of any ASME Code Class component since the beginning of the last outage

and/or planned this refueling outage.

5. If reactor vessel weld examinations required by the ASME Code are scheduled to

occur during the upcoming outage, provide a detailed description of the welds to be

examined and the extent of the planned examination. Please also provide reference

numbers for applicable procedures that will be used to conduct these examinations.

6. Copy of any 10 CFR Part 21 reports applicable to structures, systems, or

components within the scope of Section XI of the ASME Code that have been

identified since the beginning of the last refueling outage.

7. A list of any temporary non-code repairs in service (e.g., pinhole leaks).

8. Please provide copies of the most recent self-assessments for the inservice

inspection, welding, and Alloy 600 programs.

9. Copy of the procedures for welding techniques, and NDE that will be used during the

outage.

A.2

Boric Acid Corrosion Control Program

1. Copy of the procedures that govern the scope, equipment, and implementation of the

inspections required to identify boric acid leakage and the procedures for boric acid

leakage/corrosion evaluation.

2. Please provide a list of leaks (including code class of the components) that have

been identified since the last refueling outage and associated corrective action

documentation. If during the last cycle, the unit was shutdown, please provide

documentation of containment walkdown inspections performed as part of the boric

acid corrosion control program.

A.3

Steam Generator Tube Inspections

1. A detailed schedule of:

Steam generator tube inspection, data analyses, and repair activities for the

upcoming outage (if occurring).

Steam generator secondary side inspection activities for the upcoming outage

(if occurring).

2. Copy of SG history documentation given to vendors performing eddy current (ET)

testing of the SGs during the upcoming outage.

3. Copy of procedure containing screening criteria used for selecting tubes for in-situ

pressure testing and the procedure to be used for in-situ pressure testing.

4. Copy of previous outage SG tube operational assessment. Also include a copy of

the following documents as they become available:

Degradation assessment

Condition monitoring assessment

5. Copy of the document defining the planned SG ET scope (e.g., 100 percent of

unrepaired tubes with bobbin probe and 20 percent sample of hot leg expansion

transition regions with rotating probe) and identify the scope expansion criteria,

which will be applied. Also identify and describe any deviations in this scope or

expansion criteria from the EPRI Guidelines.

6. Copy of the document describing the ET acquisition equipment to be applied

including ET probe types. Also identify the extent of planned tube examination

coverage with each probe type (e.g. rotating probe -0.080 inches, 0.115 inches

pancake coils and mid-range +point coil applied at the top-of-tube-sheet plus 3

inches to minus 12 inches).

7. Identify and quantify any SG tube leakage experienced during the previous operating

cycle. Also provide documentation identifying which SG was leaking and corrective

actions completed and planned for this condition.

8. Copy of steam generator eddy current data analyst guidelines and site validated

eddy current technique specification sheets. Additionally, please provide a copy of

EPRI Appendix H, Examination Technique Specification Sheets, qualification

records.

9. Provide past history of the condition and issues pertaining to the secondary side of

the steam generators (including items such as loose parts, fouling, top of tube sheet

condition, crud removal amounts, etc.).

Indicate where the primary, secondary, and resolution analyses are scheduled to

take place.

A.4

Additional Information Related to all Inservice Inspection Activities

1. A list with a brief description of inservice inspection, and boric acid corrosion control

program related issues (e.g., PVAR) entered into your corrective action program

since the beginning of the last refueling outage. For example, a list based upon data

base searches using key words related to piping such as: inservice inspection,

ASME Code,Section XI, NDE, cracks, wear, thinning, leakage, rust, corrosion, boric

acid, or errors in piping examinations.

2. Provide training (e.g. Scaffolding, Fall Protection, FME, Confined Space) if they are

required for the activities described in A.1 through A.3.

3. Please provide names and phone numbers for the following program leads:

Inservice inspection (examination, planning)

Containment exams

Reactor pressure vessel head exams

Snubbers and supports

Repair and replacement program

Licensing

Site welding engineer

Boric acid corrosion control program

Steam generator inspection activities (site lead and vendor contact)

B.

Information to be Provided Onsite to the Inspector(s) at the Entrance Meeting (April 9,

2018):

B.1

Inservice Inspection / Welding Programs and Schedule Information

1. Updated schedules for inservice inspection/nondestructive examination activities,

including planned welding activities, and schedule showing contingency repair

plans, if available.

2. For ASME Code Class welds selected by the inspector from the lists provided from

section A of this enclosure, please provide copies of the following documentation for

each subject weld:

Weld data sheet (traveler).

• Weld configuration and system location.

Applicable Code Edition and Addenda for weldment.

Applicable Code Edition and Addenda for welding procedures.

Applicable welding procedures used to fabricate the welds.

Copies of procedure qualification records (PQRs) supporting the weld

procedures from B.1.b.v.

Copies of welders performance qualification records (WPQ).

Copies of the nonconformance reports for the selected welds (If

applicable).

Radiographs of the selected welds and access to equipment to allow

viewing radiographs (if radiographic testing was performed).

Copies of the preservice examination records for the selected welds.

Readily accessible copies of nondestructive examination personnel

qualifications records for reviewing.

3. For the inservice inspection related corrective action issues selected by the inspector

from section A of this enclosure, provide a copy of the corrective actions and

supporting documentation.

4. For the nondestructive examination reports with relevant conditions on an ASME Code

Class components selected by the inspector from Section A above, provide a copy of

the examination records, examiner qualification records, and associated corrective

action documents.

5. A copy of (or ready access to) most current revision of the inservice inspection

program manual and plan for the current interval.

6. For the nondestructive examinations selected by the inspector from section A of this

enclosure, provide a copy of the nondestructive examination procedures used to

perform the examinations (including calibration and flaw characterization/sizing

procedures). For ultrasonic examination procedures qualified in accordance with

ASME Code,Section XI, Appendix VIII, provide documentation supporting the

procedure qualification (e.g. the EPRI performance demonstration qualification

summary sheets). Also, include qualification documentation of the specific equipment

to be used (e.g., ultrasonic unit, cables, and transducers including serial numbers) and

nondestructive examination personnel qualification records.

B.2

Boric Acid Corrosion Control Program

1. Please provide boric acid walk down inspection results, an updated list of boric acid

leaks identified so far this outage, associated corrective action documentation, and

overall status of planned boric acid inspections.

2. Please provide any engineering evaluations completed for boric acid leaks identified

since the end of the last refueling outage. Please include a status of corrective actions

to repair and/or clean these boric acid leaks. Please identify specifically which known

leaks, if any, have remained in service or will remain in service as active leaks.

B.3

Steam Generator Tube Inspections

1. Copies of the Examination Technique Specification Sheets and associated

justification for any revisions.

2. Please provide a copy of the eddy current testing procedures used to perform the

steam generator tube inspections (specifically calibration and flaw

characterization/sizing procedures, etc.).

3. Copy of the guidance to be followed if a loose part or foreign material is identified in

the steam generators.

4. Identify the types of SG tube repair processes which will be implemented for defective

SG tubes (including any NRC reviews/evaluations/approvals of this repair process).

Provide the flaw depth sizing criteria to be applied for ET indications identified in the

SG tubes.

5. Copy of documents describing actions to be taken if a new SG tube degradation

mechanism is identified.

6. Provide procedures with guidance/instructions for identifying (e.g. physically locating

the tubes that require plugging) and plugging SG tubes.

7. List of corrective action documents generated by the vendor and/or site with respect

to steam generator inspection activities.

B.4

Codes and Standards

1. Ready access to (i.e., copies provided to the inspector(s) for use during the inspection

at the onsite inspection location, or room number and location where available):

2. Copy of the performance demonstration initiative (PDI) generic procedures with the

latest applicable revisions that support site qualified ultrasonic examinations of piping

welds and components (e.g., PDI-UT-1, PDI-UT-2, PDI-UT-3, PDI-UT-10, etc.).

3. Boric Acid Corrosion Guidebook Revision 1 - EPRI Technical Report 1000975.

ML18221A385

SUNSI Review

ADAMS:

Non-Publicly Available

Non-Sensitive

Keyword:

By: NTaylor

Yes No

Publicly Available

Sensitive

NRC-002

OFFICE

SRI:DRP/B

RI:DRP/B

RI:DRP/B

C:DRS/PSB2

C:DNMS/FCD

C:DRS/OB

NAME

ASanchez

NHernandez

JChoate

HGepford

JKatanic

VGaddy

SIGNATURE

AAS

NAH

JMC

hjg

JFK

vgg

DATE

08/06/2018

8/7/18

08/01/18

07/26/18

7/31/18

7/26/18

OFFICE

C:DRS/IPAT

C:DRS/EB1

SPE:DRP/B

C:DRS/EB2

BC:DRP/B

NAME

GGeorge

TFarnholtz

DProulx

JDrake

NTaylor

SIGNATURE

HAF for

TRF

DLP

JFD

NHT

DATE

07/31/18

07/27/2018

8/2/18

7/31/18

8/8/18