IR 05000445/2012005

IR 05000445-12-005, 05000446-12-005; 09/27/2012 - 12/31/2012; Comanche Peak Nuclear Power Plant, Units 1 and 2 Integrated Resident and Reigional Report; Operability Evaluations

ML13042A290
Person / Time
Site:	Comanche Peak
Issue date:	02/11/2013
From:	Walker W C NRC/RGN-IV/DRP/RPB-A
To:	Flores R Luminant Generation Co
Walker W
References
IR-12-005
Download: ML13042A290 (71)

Text

February 11, 2013

Rafael Flores, Senior Vice President and Chief Nuclear Officer Luminant Generation Company, LLC Comanche Peak Nuclear Power Plant P.O. Box 1002 Glen Rose, TX 76043 Subject: COMANCHE PEAK NUCLEAR POWER PLANT - NRC INTEGRATED INSPECTION REPORT 05000445/2012005 AND 05000446/2012005

Dear Mr. Flores:

On December 31, 2012, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at your Comanche Peak Nuclear Power Plant, Units 1 and 2, facility. The enclosed inspection report documents the inspection results which were discussed on January 15, 2013, with Mr. K. Peters, Site Vice President, and other members of your staff. The inspection examined activities conducted under your license as they relate to safety and The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. One self-revealing finding of very low safety significance (Green) was identified during this inspection. This finding was determined to involve a violation of NRC requirements. The NRC is treating this violation as a non-cited violation (NCV), consistent with Section 2.3.2 of the Enforcement Policy. If you contest the non-cited violation, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region IV; the Director, Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident Inspector at the Comanche Peak Nuclear Power Plant, Units 1 and 2. If you disagree with a cross-cutting aspect assignment in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the Regional Administrator, Region IV; and the NRC Resident Inspector at the Comanche Peak Nuclear Power Plant, Units 1 and 2. In accordance with 10 CFR its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of Agencywide Document Access and Management System (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,/RA/ Wayne C. Walker, Chief Project Branch A Division of Reactor Projects Docket Nos.: 05000445:05000446 License Nos.: NPF-87; NPF-89

Enclosure:

Inspection Report 05000445/2012005 and 05000446/2012005

w/Attachments:

1. Supplemental Information 2. Request for Information for the Occupational Radiation Safety Inspection 3. Request for Information for the Inservice Inspection 4. Request for Information for the Occupational Radiation Safety Inspection cc w/encl: Electronic Distribution

SUMMARY OF FINDINGS

IR 05000445/2012005, 05000446/2012005; 9/27/2012 - 12/31/2012; Comanche Peak Nuclear Power Plant, Units 1 and 2 Integrated Resident and Regional Report; Operability Evaluations. The report covered a 3-month period of inspection by resident inspectors and announced baseline inspections by region-based inspectors. One Green non-cited violation was identified. The significance of most findings is indicated by their color (Green, White, Yellow, or Red) using Inspection Manual Chapter The cross-the Cross- Findings for which the significance determination process does not apply may be Green or be assigned a severity level after NRC management review. The NRC's program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG- 4, dated December 2006.

Cornerstone: Mitigating Systems

Green.

The inspectors reviewed a self-revealing non-cited violation of Technical Specification 5.4.1.a for the failure of the licensee to follow procedure and properly replace diesel generator governor oil. As a result, foreign material was introduced into the governor and caused a diesel generator start failure. The licensee replaced the governor to correct the problem. The licensee entered the finding into the corrective action program as Condition Report CR-2012-006280. follow procedure and properly replace the diesel generator governor oil was a performance deficiency which resulted in a diesel generator start failure. The finding was more than minor because it was associated with the human performance attribute of the Mitigating Systems Cornerstone and adversely affected the cornerstone objective to ensure the reliability of systems that respond to initiating events to prevent undesirable consequences. Using NRC Inspection Manual Chapter Significance Determination Process (SDP) for Findings At-screened to a detailed risk evaluation because it represented an actual loss of function of a single train for greater than its technical specification allowed outage time. A senior reactor analyst evaluated the risk and determined that the risk was of very low safety significance. The finding has a human performance cross-cutting aspect associated with work control, in that, the job site conditions impacted the human performance of the work activity H.3b]. (Section 1R15)

B. Licensee-Identified Violations

None.

REPORT DETAILS

Summary of Plant Status Unit 1 began the inspection period at approximately 100 percent power. On November 2, 2012, operators initiated a manual reactor trip as a result of a reactor coolant pump 4 lower motor bearing high temperature. The unit was cooled to Mode 5 to repair the motor bearing. On November 11, 2012, operators performed a reactor startup and closed the main generator output breakers, placing Unit 1 on the grid. On November 12, 2012, the unit returned to approximately 100 percent power and operated at approximately 100 percent power for the remainder of the reporting period. Unit 2 began the inspection period at approximately 100 percent power. On October 6, 2012, the operators shut down Unit 2 to begin a scheduled refueling outage. On November 2, 2012, the outage ended when the main generator output breakers were closed and Unit 2 was placed on the grid. On November 6, 2012, the unit returned to approximately 100 percent power and operated at that power level for approximately 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> before reducing power to 49 percent as a result of high sodium levels in the steam generators. On November 11, 2012, after steam generator sodium levels improved and repairs to the auxiliary condensers were completed, the unit returned to approximately 100 percent power. On November 17, 2012, the unit experienced an automatic reactor trip as a result of a low steam generator level. The low level was the result of a transient initiated by the heater drain system. The licensee repaired the heater drain system and commenced a reactor startup the same day. On November 18, operators closed the main generator output breakers and the unit returned to approximately 100 percent power the following day. On November 20, 2012, operators initiated a manual runback of the turbine to 900 megawatts, approximately 75 percent power, as a result of a transient of the heater drain system. The licensee returned the unit to approximately 100 percent power the same day and operated at approximately 100 percent power for the remainder of the reporting period.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity

1R01 Adverse Weather Protection

a. Inspection Scope

seasonal extreme low temperatures. The inspectors verified that weather-related equipment deficiencies identified during the previous years were corrected prior to the onset of low temperatures and evaluated the implementation of the adverse weather preparation procedures and compensatory measures. The inspectors focused on plant-specific used to mitigate or respond to adverse weather conditions. The inspectors placed additional emphasis on the diesel generators and the Unit 1 feedwater control system. The inspectors reviewed the Final Safety Analysis Report and performance requirements for systems selected for inspection, and verified that procedures were appropriate. Specific documents reviewed during this inspection are listed in the attachment. The inspectors also reviewed corrective action program items to verify that the licensee was identifying adverse weather issues at an appropriate threshold and entering them into the corrective action program.

These activities constitute completion of one readiness for seasonal adverse weather sample as defined in Inspection Procedure 71111.01-05.

b. Findings

No findings were identified.

1R04 Equipment Alignments

.1 Partial Equipment Walkdowns

a. Inspection Scope

The inspectors performed partial system walkdowns of the following risk-significant systems: October 24, 2012, Unit 2, reactor coolant pump backseat leakoff during refueling outage November 6, 2012, Unit 1, diesel generators during an orange ORAM (outage risk assessment and management) condition November 8, 2012, Unit 1, reactor coolant pump 4 oil collection system November 15, 2012, Unit 1, auxiliary feedwater pump 1-02 and the turbine driven auxiliary feedwater pump when auxiliary feedwater pump 1-01 was unavailable during maintenance The inspectors selected these systems based on their risk significance relative to the reactor safety cornerstones at the time they were inspected. The inspectors focused on discrepancies that could affect the function of the system and, therefore, potentially increase risk. The inspectors reviewed applicable operating procedures, system diagrams, Final Safety Analysis Report, technical specification requirements, outstanding work orders, condition reports, and the impact of ongoing work activities on redundant trains of equipment in order to identify conditions that could have rendered the systems incapable of performing their intended functions. The inspectors also walked down accessible portions of the systems to verify system components and support equipment were aligned correctly and operable. The inspectors examined the material condition of the components and observed operating parameters of equipment to verify that there were no obvious deficiencies. The inspectors also verified that the licensee had properly identified and resolved equipment alignment problems that could cause initiating events or impact the capability of mitigating systems or barriers and entered them into the corrective action program with the appropriate significance characterization. These activities constitute completion of four partial system walkdown samples as defined in Inspection Procedure 71111.04-05.

b. Findings

No findings were identified.

.2 Complete System Walkdown

a. Inspection Scope

The inspectors performed a complete system walkdown of the Unit 1 train B safety chill water system and the Unit 2 480 Volt bus 2EB3 to verify the functional capability of the system. The inspectors selected these systems because they were considered both safety-significant and risk-inspectors walked down the systems to review mechanical and electrical equipment line-ups, electrical power availability, system pressure and temperature indications, component labeling, component lubrication, component and equipment cooling, hangers and supports, operability of support systems, and to ensure that ancillary equipment or debris did not interfere with equipment operation. The inspectors reviewed a sample of past and outstanding work orders to determine whether any deficiencies significantly affected the system function. In addition, the inspectors reviewed the corrective action program database to ensure that system equipment-alignment problems were being identified and appropriately resolved. Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of two complete system walkdown samples as defined by Inspection Procedure 71111.04-05.

b. Findings

No findings were identified.

1R05 Fire Protection

.1 Quarterly Fire Inspection Tours

a. Inspection Scope

The inspectors conducted fire protection walkdowns in the following risk-significant plant areas: October 24, 2012, Unit 2, fire zone 2CA101, containment November 5, 2012, Unit 1, reactor coolant pump motor oil collection system November 15, 2012, Unit 1, fire zone AF33, train A component cooling water pump room November 15, 2012, Unit 2, fire zone AE32, train A component cooling water pump room November 20, 2012, transformer XST2A yard area The inspectors reviewed areas to assess if licensee personnel had implemented a fire protection program that adequately controlled combustibles and ignition sources within the plant; effectively maintained fire detection and suppression capability; maintained passive fire protection features in good material condition; and had implemented adequate compensatory measures for out of service, degraded or inoperable fire The inspectors selected fire areas based on their overall contribution to internal fire risk individual plant examination of external events or their potential to affect equipment that could initiate or mitigate a plant transient. The inspectors verified that fire hoses and extinguishers were in their designated locations and available for immediate use, that fire detectors and sprinklers were unobstructed, that transient material loading was within the analyzed limits, and fire doors, dampers, and penetration seals appeared to be in satisfactory condition.

These activities constitute completion of five quarterly fire protection inspection samples as defined in Inspection Procedure 71111.05-05.

b. Findings

No findings were identified.

1R06 Flood Protection Measures

a. Inspection Scope

The inspectors performed internal flood protection walkdowns of the following plant areas: Unit 1, train B emergency core cooling system pumps and corridor Uninterruptible power supply air conditioning units The inspectors verified the adequacy of flood control measures. The inspectors reviewed the Final Safety Analysis Report, the flooding analysis, and plant procedures to assess susceptibilities involving internal flooding. The inspectors reviewed the corrective action program to determine if licensee personnel identified and corrected flooding problems. Specific documents reviewed during this inspection are listed in the attachment.

These activities constitute completion of two internal flood protection measures inspection samples as defined in Inspection Procedure 71111.06-05.

b. Findings

No findings were identified.

1R08 Inservice Inspection Activities

Completion of Sections

.1 Inspection Activities Other Than Steam Generator Tube Inspection, Pressurized Water Reactor Vessel Upper Head Penetration Inspections, and Boric Acid Corrosion Control (71111.08-02.01)

a. Inspection Scope

The inspectors observed 36 nondestructive examination activities and reviewed one nondestructive examination package that included five types of examinations.

The inspectors directly observed the following nondestructive examinations: SYSTEM WELD IDENTIFICATION EXAMINATION TYPE Steam Generator Steam Generator 4, main steam nozzle to vessel weld. TCX-2-1100-4-11 Magnetic Particle Main Feedwater Main feedwater pipe support. TCX-2-2402-H3 Magnetic Particle Main Feedwater Main feedwater pipe support. TCX-2-2203-H1 Magnetic Particle Main Feedwater Main feedwater pipe support. TCX-2-2203-H2 Magnetic Particle Reactor Coolant Reactor coolant pump motor 2-03 flywheel. TCX-RCPCPX-03 Penetrant Safety Injection Support. TCX-2-2582-H3.

Description:

SI-2-031-430-S32A Penetrant Chemical Volume and Control MOV-2-8402A. Joints TUX 8-1, 9-1, and 10-1 Radiograph Chemical Volume and Control MOV-2-8402A. Joints TUX 7-1 and FW-11 Radiograph Steam Generator Steam Generator 4, auxiliary feedwater nozzle to vessel weld. TCX-2-1100-4-10 Examination angle-0° Ultrasonic Steam Generator Steam Generator 4, auxiliary feedwater nozzle to vessel weld. TCX-2-1100-4-10 Examination angle-45° Ultrasonic Steam Generator Steam Generator 4, auxiliary feedwater nozzle to vessel weld. TCX-2-1100-4-10 Examination angle-60° Ultrasonic Reactor Coolant Reactor upper head penetration examination. Penetrations 63 and 65 Ultrasonic Reactor Coolant

Description:

Pipe to pipe. ID #: TXC-1-4500-3 Ultrasonic SYSTEM WELD IDENTIFICATION EXAMINATION TYPE Reactor Coolant

Description:

Pipe to pipe. ID #:TXC-1-4500-2 Ultrasonic Steam Generator Steam Generator 4, lower head to tubesheet weld. TCX-1-3100-4-1 Examination angle-0° Ultrasonic Steam Generator Steam Generator 4, lower head to tubesheet weld. TCX-1-3100-4-1 Examination angle-45° Ultrasonic Steam Generator Steam Generator 4, lower head to tubesheet weld. TCX-1-3100-4-1 Examination angle-60° Ultrasonic Main Steam Branch connection to flange TXC-2-2200-37 Ultrasonic Main Steam Branch connection to flange TXC-2-2200-30 Ultrasonic Main Steam Branch connection to flange TXC-2-2200-39 Ultrasonic Main Steam Branch connection to flange TXC-2-2200-40 Ultrasonic Reactor Coolant Steam Generator 4 inlet nozzle (hot leg) inner radius. TCX-1-3100-4A Ultrasonic Reactor Coolant Steam Generator 4 outlet nozzle (cold leg) inner radius. TCX-1-3100-4B Ultrasonic Reactor Coolant Unit 2 Hot Leg, Loop 1 Azimuth 202°, nozzle to safe-end Visual Reactor Coolant Unit 2 Hot Leg, Loop 2 Azimuth 337°, nozzle to safe-end Visual Reactor Coolant Unit 2 Hot Leg, 3Loop 3 Azimuth 22°, nozzle to safe-end Visual Reactor Coolant Unit 2 Hot Leg, Loop 4 Azimuth 158°, nozzle to safe-end Visual Reactor Coolant Steam Generator 1 Channel Head Drain Visual Reactor Coolant Steam Generator 2 Channel Head Drain Visual Reactor Coolant Steam Generator 3 Channel Head Drain Visual Reactor Coolant Steam Generator 4 Channel Head Drain Visual SYSTEM WELD IDENTIFICATION EXAMINATION TYPE Safety Injection Support TCX-2-2582-H3

Description:

SI-3-031-430-S32A Visual Reactor Coolant Reactor upper head. Robotic visual examination. Visual Main Feedwater Main feedwater pipe support. TCX-2-2203-H1 Visual Main Feedwater Main feedwater pipe support. TCX-2-2203-H2 Visual Main Feedwater Main feedwater pipe support. TCX-2-2402-H3 Visual The inspectors reviewed records for the following nondestructive examinations: SYSTEM WELD IDENTIFICATION EXAMINATION TYPE Reactor Coolant System Reactor vessel lower head bottom mounted instrumentation penetrations. Visual During the review and observation of each examination, the inspectors verified that activities were performed in accordance with the ASME Code requirements and applicable procedures. The inspectors also verified that the qualifications of nondestructive examination technicians performing the inspections were current.

The inspectors observed the following welding activities: SYSTEM WELD IDENTIFICATION WELD TYPE Chemical Volume and Control 3 inch - pipe to pipe Weld FW TXU 7-1 Tungsten Inert Gas Welding (GTAW) Chemical Volume and Control 3 inch - elbow to pipe Weld FW-11 Tungsten Inert Gas Welding (GTAW) The inspectors reviewed records for the following welding activities: SYSTEM WELD IDENTIFICATION WELD TYPE Chemical Volume and Control 3 inch - pipe to valve Weld FW TUX 8-1 Tungsten Inert Gas Welding (GTAW) Chemical Volume and Control 3 inch - pipe to valve Weld TUX 9-1 Tungsten Inert Gas Welding (GTAW) Chemical Volume and Control 3 inch - pipe to elbow Weld TUX 10-1 Tungsten Inert Gas Welding (GTAW)

The inspectors verified, by review, that the welding procedure specifications and the welder had been properly qualified in accordance with ASME Code,Section IX, requirements. The inspectors also verified, through observation and record review, that essential variables for the welding process were identified, recorded in the procedure qualification record, and formed the bases for qualification of the welding procedure specifications. Specific documents reviewed during this inspection are listed in the attachment. These actions constitute completion of the requirements for Section 02.01.

b. Findings

No findings were identified.

.2 Vessel Upper Head Penetration Inspection Activities (71111.08-02.02)

a. Inspection Scope

The inspereactor vessel upper head penetrations, and verified that there was no evidence of boric acid challenging the structural integrity of the reactor head components and attachments. The inspectors also verified that the required inspection coverage was achieved and limitations were properly recorded. The inspectors reviewed the results of inspection met Code Case N-729-1. The inspectors also verified that the required inspection coverage was achieved and limitations were properly recorded. The inspectors verified that the personnel performing the inspection were certified examiners to their respective nondestructive examination method. Specific documents reviewed during this inspection are listed in the attachment. These actions constitute completion of the requirements for Section 02.02.

b. Findings

No findings were identified.

.3 Boric Acid Corrosion Control Inspection Activities (71111.08-02.03)

a. Inspection Scope

control program for monitoring degradation of those systems that could be adversely affected by boric acid corrosion. The inspectors reviewed the documentation associated Procedure STA- The inspectors verified that the visual inspections emphasized locations where boric acid leaks could cause degradation of safety-significant components, and that engineering evaluation used corrosion rates applicable to the affected components and properly assessed the effects of corrosion induced wastage on structural or pressure boundary integrity. The inspectors confirmed that corrective actions taken were consistent with the ASME Code, and 10 CFR 50, Appendix B requirements. Specific documents reviewed during this inspection are listed in the attachment. These actions constitute completion of the requirements for Section 02.03.

b. Findings

No findings were identified.

.4 Steam Generator Tube Inspection Activities (71111.08-02.04)

a. Inspection Scope

The technical specifications require, in part, that for the Unit 2 model D5 steam generators (alloy 600 thermally treated) inspect 100 percent of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months.

At the last inspection, refueling outage 2RF12, which took place in the spring of 2011, the steam generators had completed 180 effective full power months from the first inservice inspection of the steam generators. The required 100 percent inspection scope was completed during that refueling outage. The current refueling outage, 2RF13, falls into the second sequential period; therefore, the steam generators were not required to be inspected. No primary side inspections were performed. Therefore, the inspectors determined this section of Inspection Procedure 71111.08 was not applicable. These actions constitute completion of the requirements for Section 02.04.

b. Findings

No findings were identified.

.5 Identification and Resolution of Problems (71111.08-02.05)

a. Inspection scope

The inspectors reviewed 37 condition reports which dealt with inservice inspection activities and found the corrective actions for inservice inspection issues were appropriate. From this review the inspectors concluded that the licensee has an appropriate threshold for entering inservice inspection issues into the corrective action program and has procedures that direct a root cause evaluation when necessary. The licensee also has an effective program for applying industry inservice inspection operating experience. Specific documents reviewed during this inspection are listed in the attachment.

b. Findings

No findings were identified.

R11 Licensed Operator Requalification Program and Licensed Operator Performance

.1 Quarterly Inspection of Licensed Operator Requalification Program

a. Inspection Scope

On November 26, 2012, the inspectors observed a crew of licensed operators in the during requalification training. The inspectors assessed the following areas: Licensed operator performance The ability of the licensee to administer the evaluations The modeling and performance of the control room simulator The quality of post-scenario critiques Follow-up actions taken by the licensee for identified discrepancies These activities constitute completion of one quarterly inspection of licensed operator requalification program sample as defined in Inspection Procedure 71111.11-05.

b. Findings

No findings were identified.

.2 Quarterly Observation of Licensed Operator Performance

a. Inspection Scope

The inspectors observed the performance of on-shifmain control room. At the time of the observations, the plant was in a period of heightened activity. Tprocedures and other operations department policies. The inspectors observed the October 15, 2012, Unit 2, control of core offload October 27, 2012, Unit 2, midloop activities November 1, 2012, Unit 2, reactor startup November 20, 2012, Unit 1, recovery from unit runback These activities constitute completion of one quarterly observation of licensed operator performance sample as defined in Inspection Procedure 71111.11-05.

b. Findings

No findings were identified.

1R12 Maintenance Effectiveness

a. Inspection Scope

The inspectors evaluated the following risk significant systems, components, and degraded performance issues:

Service water intake structure, structural monitoring Unit 1 train B safety chill water system The inspectors reviewed events where ineffective equipment maintenance had resulted in failures and independently verified the licensee's actions to address system performance or condition problems in terms of the following: Implementing appropriate work practices Identifying and addressing common cause failures Scoping of systems in accordance with 10 CFR 50.65(b) Characterizing system reliability issues for performance Charging unavailability for performance Trending key parameters for condition monitoring Ensuring proper classification in accordance with 10 CFR 50.65(a)(1) or (a)(2) The inspectors verified appropriate performance criteria for structures, systems, and components classified as having an adequate demonstration of performance through preventive maintenance, as described in 10 CFR 50.65(a)(2), or as requiring the establishment of appropriate and adequate goals and corrective actions for systems classified as not having adequate performance, as described in 10 CFR 50.65(a)(1). The inspectors assessed performance issues with respect to the reliability, availability, and condition monitoring of the system. In addition, the inspectors verified maintenance effectiveness issues were entered into the corrective action program with the appropriate significance characterization. Specific documents reviewed during this inspection are listed in the attachment. These activities constituted completion of two maintenance effectiveness samples as defined in Inspection Procedure 71111.12-05.

b. Findings

No findings were identified.

1R13 Maintenance Risk Assessments and Emergent Work Control

a. Inspection Scope

The inspectors reviewed the licensee evaluation and management of plant risk for the maintenance and emergent work activities affecting risk-significant and safety-related equipment listed below to verify that the appropriate risk assessments were performed prior to removing equipment for work: October 3, 2012, Unit 2, refueling outage October 9, 2012, Unit 2, containment integrated leakage rate test October 17, 2012, Unit 2, bus 2EA2 while protected with defense-in-depth postings November 6, 2012, Unit 1, forced outage The inspectors selected these activities based on potential risk significance relative to the reactor safety cornerstones. As applicable for each activity, the inspectors verified that licensee personnel performed risk assessments as required by 10 CFR 50.65(a)(4) and that the assessments were accurate and complete. When licensee personnel performed emergent work, the inspectors verified that the licensee personnel promptly assessed and managed plant risk. The inspectors reviewed the scope of maintenance work, discussed the results of the assessment with the licensee's probabilistic risk analyst or shift technical advisor, and verified plant conditions were consistent with the risk assessment. The inspectors also reviewed the technical specification requirements and inspected portions of redundant safety systems, when applicable, to verify risk analysis assumptions were valid and applicable requirements were met.

These activities constitute completion of four maintenance risk assessments and emergent work control inspection samples as defined in Inspection Procedure 71111.13-05.

b. Findings

No findings were identified.

1R15 Operability Evaluations

a. Inspection Scope

The inspectors reviewed the following issues: CR-2011-005478, Units 1 and 2, water in control room air conditioning unit X-04 due to clogged drain CR-2012-006280, Unit 2, foreign material in diesel generator governor CR-2012-011513, Unit 1, blackout sequencer 1-02 partial actuation CR-2012-012553, Unit 1, auxiliary feedwater pump 1-01 outboard pump bearing oil darker than normal The inspectors selected these operability issues based on the risk significance of the associated components and systems. The inspectors evaluated the technical adequacy of the evaluations to ensure that technical specification operability was properly justified and the subject component or system remained available such that no unrecognized increase in risk occurred. The inspectors compared the operability and design criteria in the appropriate sections of the technical specifications and Final Safety Analysis Report operable. Where compensatory measures were required to maintain operability, the inspectors determined whether the measures in place would function as intended and were properly controlled. The inspectors determined, where appropriate, compliance with bounding limitations associated with the evaluations. Additionally, the inspectors reviewed a sampling of corrective action documents to verify that the licensee was identifying and correcting any deficiencies associated with operability evaluations. Specific documents reviewed during this inspection are listed in the attachment.

These activities constitute completion of four operability evaluation inspection samples as defined in Inspection Procedure 71111.15-05.

b. Findings

Introduction.

The inspectors reviewed a Green self-revealing non-cited violation of Technical Specification 5.4.1.a for the failure of the licensee to follow procedure and properly replace diesel generator governor oil. As a result, foreign material was introduced into the governor and caused a diesel generator start failure. The licensee replaced the governor to correct the problem.

Description.

On June 20, 2012, the licensee initiated a surveillance test of diesel generator 2-01. During the test, the engine started to crank but the engine speed would not exceed 200 revolutions per minute and after approximately 100 seconds, operators shut down the diesel generator. Normal speed for the engine is 450 revolutions per minute. A few hours later and as part of troubleshooting, operators performed a normal slow start of the diesel engine. The governor output shaft did not move for the first 30 seconds and then moved. The engine reached rated speed at 55 seconds and appeared to be operating correctly. During a slow start, the diesel generator would reach rated speed in approximately 38 seconds. determined that the cause of the diesel generator failure to start was a failure of the mechanical governor to function on the demand start. The failure of the governor was the result of a soft particle stuck either in the governor pilot valve or an internal check valve. The inspectors reviewed the apparent cause evaluation and determined that maintenance personnel replaced the governor oil on April 11, 2011. Procedure MSM-C0-written instructions for performing maintenance of diesel generator governors. Step 5.1 and the caution prior to Step 8.4.6 required, in part, to exercise extreme care to prevent the entry of foreign material into clean systems and that the cleanliness of governor internals is of upmost importance to governor operation. Erratic governor behavior and failure has been caused by contamination of governor oil system. On April 11, 2011, the licensee failed to exercise extreme care to prevent the entry of foreign material into the governor. As a result, foreign material was introduced into the governor and that caused a diesel generator start failure. The licensee replaced the governor and returned the diesel generator to operation.

The inspectors performed a walkdown of the governor and determined that the confined area near the governor created a challenge to keep foreign material from entering the governor. The inspectors determined that the governor oil replacement was the likely cause of the introduction of foreign material into the governor.

Analysisgenerator governor oil was a performance deficiency which resulted in a diesel generator start failure. The finding was more than minor because it was associated with the human performance attribute of the Mitigating Systems Cornerstone and adversely affected the cornerstone objective to ensure the reliability of systems that respond to initiating events to prevent undesirable consequences. Using NRC Inspection Manual Chapter At-actual loss of function of a single train for greater than its technical specification allowed outage time.

A senior reactor analyst performed a detailed evaluation of the finding. Diesel generator 2-01 failed to start after a period of seven days from the previous successful start. The analyst assumed that once the diesel generator was up to rated speed and Therefore, the change in risk is restricted to the 7-day period and is further reduced to 3.5 days to reflect a T/2 assumption. The standardized plant analysis risk model, Revision 8.22, was run at a truncation of 1.0E-11, average test and maintenance, and diesel generator 2-01 fail-to-a common cause potential. The resulting delta-core damage frequency was 2.31E-4. For a 3.5 day exposure, the incremental conditional core damage probability was 2.2E-6. The analyst noted that two mitigating factors were not included in the standardized plant analysis risk model result. First, the alternate power generators are not modeled. These units have been evaluated in the past to result in a mitigation factor of greater than one order of magnitude for diesel generator failures. Second, the manner of the failure was such that the diesel generator started successfully without any corrective action other than a repeated attempt to start. Thus, the recovery factors in the standardized plant analysis risk model, which are based on average failure states, are overly-bounding for this case. The analyst qualitatively determined that the internal events incremental conditional core damage probability would be below 1.0E-7 when these factors are taken into consideration. There are no external events that would result in a significant increase in the significance. The senior reactor analyst concluded that the risk of the diesel failure was of very low safety significance.

The finding has a human performance cross-cutting aspect associated with work control, in that, the confined job site conditions impacted the human performance of the work activity H.3b].

Enforcement.

Technical Specification 5.4.1.a requires, in part, that written procedures shall be established, implemented, and maintained covering the applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A. Regulatory Guide 1.33, Revision 2, Appendix A, Item 9.a, requires, in part, that maintenance that can affect the performance of safety-related equipment should be performed in accordance with written procedures. Procedure MSM-C0-uctions for performing maintenance of diesel generator governors. Step 5.1 and the caution prior to Step 8.4.6 required, in part, to exercise extreme care to prevent the entry of foreign material into clean systems and that the cleanliness of governor internals is of upmost importance to governor operation. Erratic governor behavior and failure has been caused by contamination of governor oil system.

Contrary to the above, on April 11, 2011, the licensee failed to implement written procedures as required by Technical Specification 5.4.1.a. Specifically, the licensee failed to implement Procedure MSM-C0-3367 and exercise extreme care to prevent the entry of foreign material into the governor when replacing the governor oil. As a result, foreign material was introduced into the governor and caused a diesel generator start failure. The licensee replaced the governor and returned the diesel generator to operation. Because the violation was of very low safety significance and was documented in the licenseeCR-2012-006280, it is being treated as a non-cited violation, consistent with Section 2.3.2 of the Enforcement Policy: NCV 05000446/2012005-Foreign Material in Diesel Generator Governor Causes Start Fa

1R18 Plant Modifications

a. Inspection Scope

The inspectors reviewed the plant modification of the auxiliary feedwater pump constant level oilers and the associated level indicating gauges. The inspectors reviewed Final Design Authorization FDA-2012-000089-01-02, the Final Safety Analysis Report, and technical specifications to ensure the modification did not affect operability of the auxiliary feedwater pumps. The inspectors observed the installation of the modification and the subsequent post modification testing. These activities constitute completion of one plant modifications inspection sample as defined in Inspection Procedure 71111.18-05.

b. Findings

No findings were identified.

1R19 Post-Maintenance Testing

a. Inspection Scope

The inspectors reviewed the following post-maintenance activities to verify that procedures and test activities were adequate to ensure system operability and functional capability: October 23, 2012, Unit 2, service water pump 2-02 testing following pump replacement October 29, 2012, Unit 2, main steam isolation valve 2-02 testing following valve maintenance October 31, 2012, Unit 2, safety injection pump 2-01 testing following pump replacement October 31, 2012, Unit 1, blackout sequencer 1-02 testing following relay and power supply replacement November 29, 2012, Unit 1, motor driven auxiliary feedwater pump 1-01 testing following pump outer bearing oil replacement The inspectors selected these activities based upon the structure, system, or component's ability to affect risk. The inspectors evaluated the activities to ensure the testing was adequate for the maintenance performed, the acceptance criteria were clear, and the test ensured equipment operational readiness.

The inspectors evaluated the activities against technical specifications, the Final Safety Analysis Report, 10 CFR Part 50 requirements, licensee procedures, and various NRC generic communications to ensure that the test results adequately ensured that the equipment met the licensing basis and design requirements. In addition, the inspectors reviewed corrective action documents associated with post-maintenance tests to determine whether the licensee was identifying problems and entering them into the corrective action program and that the problems were being corrected commensurate with their importance to safety. Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of five post-maintenance testing inspection samples as defined in Inspection Procedure 71111.19-05.

b. Findings

No findings were identified.

1R20 Refueling and Other Outage Activities

The activities below constitute completion of two refueling and other outage activities samples as defined in Inspection Procedure 71111.20-05.

.1 Unit 2 Refueling Outage

a. Inspection Scope

The inspectors reviewed the outage safety plan and contingency plans for the Unit 2 refueling outage, conducted October 6, 2012, through November 2, 2012, to confirm that licensee personnel had appropriately considered risk, industry experience, and previous site-specific problems in developing and implementing a plan that assured maintenance of defense-in-depth. During the refueling outage, the inspectors observed portions of the shutdown and cooldown of the reactor and monitored licensee controls over the outage activities listed below: Configuration management, including maintenance of defense-in-depth, is commensurate with the outage safety plan for key safety functions and compliance with the applicable technical specifications when taking equipment out of service Clearance activities, including confirmation that tags were properly hung and equipment appropriately configured to safely support the work or testing Installation and configuration of reactor coolant pressure, level, and temperature instruments to provide accurate indication, accounting for instrument error Status and configuration of electrical systems to ensure that technical specifications and outage safety plan requirements were met, and controls over switchyard activities Monitoring of decay heat removal processes, systems, and components Verification that outage work was not impacting the ability of the operators to operate the spent fuel pool cooling system Reactor water inventory controls, including flow paths, configurations, and alternative means for inventory addition, and controls to prevent inventory loss Controls over activities that could affect reactivity Refueling activities including fuel handling Startup and ascension to full power operation, tracking of startup prerequisites, walkdown of the containment to verify that debris had not been left which could block emergency core cooling system suction strainers, and reactor physics testing Licensee identification and resolution of problems related to refueling outage activities Specific documents reviewed during this inspection are listed in the attachment.

b. Findings

No findings were identified.

.2 Unit 1 Reactor Coolant Pump Outage

a. Inspection Scope

The inspectors reviewed the outage safety plan and contingency plans for the Unit 1 reactor coolant pump outage, conducted November 2, 2012, through November 11, 2012, to confirm that licensee personnel had appropriately considered risk, industry experience, and previous site-specific problems in developing and implementing a plan that assured maintenance of defense-in-depth. During the outage, the inspectors observed portions of the shutdown and cooldown of the reactor and monitored licensee controls over the outage activities listed below: Configuration management, including maintenance of defense-in-depth, is commensurate with the outage safety plan for key safety functions and compliance with the applicable technical specifications when taking equipment out of service Clearance activities, including confirmation that tags were properly hung and equipment appropriately configured to safely support the work or testing Status and configuration of electrical systems to ensure that technical specifications and outage safety plan requirements were met, and controls over switchyard activities Monitoring of decay heat removal processes, systems, and components Verification that outage work was not impacting the ability of the operators to operate the spent fuel pool cooling system Reactor water inventory controls, including flow paths, configurations, and alternative means for inventory addition, and controls to prevent inventory loss Controls over activities that could affect reactivity Startup and ascension to full power operation, tracking of startup prerequisites, and walkdown of the containment to verify that debris had not been left which could block emergency core cooling system suction strainers Licensee identification and resolution of problems related to outage activities Specific documents reviewed during this inspection are listed in the attachment.

b. Findings

No findings were identified.

1R22 Surveillance Testing

a. Inspection Scope

The inspectors reviewed the Final Safety Analysis Report, procedure requirements, technical specifications, and corrective action documents to ensure that the surveillance activities listed below demonstrated that the systems, structures, and components tested were capable of performing their intended safety functions.

Containment Isolation Valve Test October 9, 2012, Unit 2, containment integrated leakage rate test in accordance with Procedure PPT-S2-Revision 1 Reactor Coolant System Leakage Detection Surveillance Testing December 6, 2012, Unit 2, water inventory balance in accordance with Procedure OPT- Routine Surveillance Testing October 4, 2012, Unit 1, auxiliary feedwater pump 1-01 inservice test in accordance with Procedure OPT- October 19, 2012, Unit 2, train B undervoltage relay calibration in accordance with Procedure MSE-S2-December 5, 2012, Unit 2, diesel generator 2-01 24-hour load run in accordance with Procedure OPT- The inspectors either witnessed or reviewed test data to verify that the significant surveillance test attributes were adequate to address the following: Preconditioning Evaluation of testing impact on the plant Acceptance criteria Test equipment Procedures Jumper and lifted lead controls Test data Testing frequency and method demonstrated technical specification operability Test equipment removal Restoration of plant systems Fulfillment of ASME code requirements Updating of performance indicator data Reference setting data Annunciators and alarms setpoints Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of five surveillance testing inspection samples (one containment isolation valve test sample, one reactor coolant system leakage detection surveillance test sample, and three routine surveillance testing samples) as defined in Inspection Procedure 71111.22-05.

b. Findings

No findings were identified. Cornerstone: Emergency Preparedness

1EP4 Emergency Action Level and Emergency Plan Changes

a. Inspection Scope

The inspectors performed an in-office review to verify that no changes to the site emergency plan or emergency plan implementing procedures were submitted to the NRC in calendar year 2012 that required a detailed review according to the requirements of Inspection Procedure 71114.04. These activities constitute completion of one emergency action level and emergency plan changes sample as defined in Inspection Procedure 71114.04-05.

b. Findings

No findings were identified.

RADIATION SAFETY

Cornerstones: Public Radiation Safety and Occupational Radiation Safety

2RS1 Radiological Hazard Assessment and Exposure Controls

a. Inspection Scope

the radiological hazards in the workplace associated with licensed activities and the implementation of appropriate radiation monitoring and exposure control measures for both individual and collective exposures, (2) verify the licensee is properly identifying and reporting occupational radiation safety cornerstone performance indicators, and (3) identify those performance deficiencies that were reportable as a performance indicator and which may have represented a substantial potential for overexposure of the worker. The inspectors used the requirements in 10 CFR Part 20, the technical specifications, and thdetermining compliance. The inspectors interviewed the radiation protection manager, radiation protection supervisors, and radiation workers. The inspectors performed walkdowns of various portions of the plant, performed independent radiation dose rate measurements, and reviewed the following items: Performance indicator events and associated documentation reported by the licensee in the occupational radiation safety cornerstone of changes in plant operations and radiological surveys to detect dose rates, airborne radioactivity, and surface contamination levels Instructions and notices to workers, including labeling or marking containers of radioactive material, radiation work permits, actions for electronic dosimeter alarms, and changes to radiological conditions Programs and processes for control of sealed sources and release of potentially contaminated material from the radiologically controlled area, including survey performance, instrument sensitivity, release criteria, procedural guidance, and sealed source accountability Radiological hazards control and work coverage, including the adequacy of surveys, radiation protection job coverage, and contamination controls; the use of electronic dosimeters in high noise areas; dosimetry placement; airborne radioactivity monitoring; controls for highly activated or contaminated materials (non-fuel) stored within spent fuel and other storage pools; and posting and physical controls for high radiation areas and very high radiation areas Radiation worker and radiation protection technician performance with respect to radiation protection work requirements Audits, self-assessments, and corrective action documents related to radiological hazard assessment and exposure controls since the last inspection Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of the one radiological hazard assessment and exposure controls sample as defined in Inspection Procedure 71124.01-05.

b. Findings

No findings were identified.

2RS2 Occupational ALARA Planning and Controls

a. Inspection Scope

This area was inspected to assess performance with respect to maintaining occupational individual and collective radiation exposures as low as is reasonably achievable (ALARA). The inspectors used the requirements in 10 CFR Part 20, the technical criteria for determining compliance. The inspectors interviewed licensee personnel and reviewed the following items: Site-specific ALARA procedures and collective exposure history, including the current 3-year rolling average, site-specific trends in collective exposures, and source-term measurements ALARA work activity evaluations/postjob reviews, exposure estimates, and exposure mitigation requirements The methodology for estimating work activity exposures, the intended dose outcome, the accuracy of dose rate and man-hour estimates, and intended versus actual work activity doses and the reasons for any inconsistencies Records detailing the historical trends and current status of tracked plant source terms and contingency plans for expected changes in the source term due to changes in plant fuel performance issues or changes in plant primary chemistry Radiation worker and radiation protection technician performance during work activities in radiation areas, airborne radioactivity areas, or high radiation areas Audits, self-assessments, and corrective action documents related to ALARA planning and controls since the last inspection Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of the one occupational ALARA planning and controls sample as defined in Inspection Procedure 71124.02-05.

b. Findings

No findings were identified.

RS5 Radiation Monitoring Instrumentation (71124.05)

a. Inspection Scope

This area was inspected to verify the licensee is assuring the accuracy and operability of radiation monitoring instruments that are used to: (1) monitor areas, materials, and workers to ensure a radiologically safe work environment; and (2) detect and quantify radioactive process streams and effluent releases. The inspectors used the requirementprocedures required by technical specifications as criteria for determining compliance. During the inspection, the inspectors interviewed licensee personnel, performed walkdowns of various portions of the plant, and reviewed the following items: Audits, self-assessments, and corrective action documents related to radiation monitoring instrumentation since the last inspection Selected plant configurations and alignments of process, postaccident, and effluent monitors with descriptions in the Final Safety Analysis Report and the offsite dose calculation manual Select instrumentation, including effluent monitoring instrument, portable survey instruments, area radiation monitors, continuous air monitors, personnel contamination monitors, portal monitors, and small article monitors to examine their configurations and source checks Calibration and testing of process and effluent monitors, laboratory instrumentation, whole body counters, postaccident monitoring instrumentation, portal monitors, personnel contamination monitors, small article monitors, portable survey instruments, area radiation monitors, electronic dosimetry, air samplers, continuous air monitors Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of the one radiation monitoring instrumentation sample as defined in Inspection Procedure 71124.05-05.

b. Findings

No findings were identified.

2RS6 Radioactive Gaseous and Liquid Effluent Treatment

a. Inspection Scope

This area was inspected to: (1) ensure the gaseous and liquid effluent processing systems are maintained so radiological discharges are properly mitigated, monitored, and evaluated with respect to public exposure; (2) ensure abnormal radioactive gaseous or liquid discharges and conditions, when effluent radiation monitors are out-of-service, are controlled in accordance with the applicable regulatory requirements and licensee procedures; (3) verify the licensees quality control program ensures the radioactive effluent sampling and analysis requirements are satisfied so discharges of radioactive materials are adequately quantified and evaluated; and (4) verify the adequacy of public dose projections resulting from radioactive effluent discharges. The inspectors used the requirements in 10 CFR Part 20; 10 CFR Part 50, Appendices A and I; 40 CFR Part 190; the offsite dose calculation manual, and licensee procedures required by the technical specifications as criteria for determining compliance. The inspectors interviewed licensee personnel and reviewed and/or observed the following items: Radiological effluent release reports since the previous inspection and reports related to the effluent program issued since the previous inspection Effluent program implementing procedures, including sampling, monitor setpoint determinations and dose calculations Equipment configuration and flow paths of selected gaseous and liquid discharge system components, filtered ventilation system material condition, and significant changes to their effluent release points, and associated 10 CFR 50.59 reviews Selected portions of the routine processing and discharge of radioactive gaseous and liquid effluents (including sample collection and analysis) Controls used to ensure representative sampling and appropriate compensatory sampling Results of the inter-laboratory comparison program Effluent stack flow rates Surveillance test results of technical specification-required ventilation effluent discharge systems since the previous inspection Significant changes in reported dose values A selection of radioactive liquid and gaseous waste discharge permits Part 61 analyses and methods used to determine which isotopes are included in the source term Offsite dose calculation manual changes Meteorological dispersion and deposition factors Latest land use census Records of abnormal gaseous or liquid tank discharges Groundwater monitoring results contaminated spills/leaks to groundwater Identified leakage or spill events and entries made into 10 CFR 50.75 (g) records, if any, and associated evaluations of the extent of the contamination and the radiological source term Offsite notifications and reports of events associated with spills, leaks, or groundwater monitoring results Audits, self-assessments, reports, and corrective action documents related to radioactive gaseous and liquid effluent treatment since the last inspection Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of the one radioactive gaseous and liquid effluent treatment sample, as defined in Inspection Procedure 71124.06-05.

b. Findings

No findings were identified.

2RS7 Radiological Environmental Monitoring Program

a. Inspection Scope

This area was inspected to: (1) ensure that the radiological environmental monitoring program verifies the impact of radioactive effluent releases to the environment and sufficiently validates the integrity of the radioactive gaseous and liquid effluent release program; (2) verify that the radiological environmental monitoring program is offsite dose calculation manual, and to validate that the radioactive effluent release program meets the design objective contained in Appendix I to 10 CFR Part 50; and (3) ensure that the radiological environmental monitoring program monitors non-effluent exposure pathways, is based on sound principles and assumptions, and validates that doses to members of the public are within the dose limits of 10 CFR Part 20 and 40 CFR Part 190, as applicable. The inspectors reviewed and/or observed the following items: Annual environmental monitoring reports and offsite dose calculation manual Selected air sampling and thermoluminescence dosimeter monitoring stations Collection and preparation of environmental samples Operability, calibration, and maintenance of meteorological instruments Selected events documented in the annual environmental monitoring report which involved a missed sample, inoperable sampler, lost thermoluminescence dosimeter, or anomalous measurement Selected structures, systems, or components that may contain licensed material and has a credible mechanism for licensed material to reach ground water Records required by 10 CFR 50.75(g) Significant changes made by the licensee to the offsite dose calculation manual as the result of changes to the land census or sampler station modifications since the last inspection Calibration and maintenance records for selected air samplers, composite water samplers, and environmental sample radiation measurement instrumentation Interlaboratory comparison program results Audits, self-assessments, reports, and corrective action documents related to the radiological environmental monitoring program since the last inspection Specific documents reviewed during this inspection are listed in the attachment. These activities constitute completion of the one radiological environmental monitoring program sample as defined in Inspection Procedure 71124.07-05.

b. Findings

No findings were identified.

2RS8 Radioactive Solid Waste Processing, and Radioactive Material Handling, Storage, and Transportation

a. Inspection Scope

This area was inspected to verify the effectiveness of the licensees programs for processing, handling, storage, and transportation of radioactive material. The inspectors used the requirements of 10 CFR Parts 20, 61, and 71 and Department of Transportation regulations contained in 49 CFR Parts 171-180 for determining compliance. The inspectors interviewed licensee personnel and reviewed the following items: The solid radioactive waste system description, process control program, and the scope of the licensees audit program Control of radioactive waste storage areas including container labeling/marking and monitoring containers for deformation or signs of waste decomposition Changes to the liquid and solid waste processing system configuration including a review of waste processing equipment that is not operational or abandoned in place Radio-chemical sample analysis results for radioactive waste streams and use of scaling factors and calculations to account for difficult-to-measure radionuclides Processes for waste classification including use of scaling factors and 10 CFR Part 61 analysis Shipment packaging, surveying, labeling, marking, placarding, vehicle checking, driver instructing, and preparation of the disposal manifest Audits, self-assessments, reports, and corrective action reports radioactive solid waste processing, and radioactive material handling, storage, and transportation performed since the last inspection Specific documents reviewed during this inspection are listed in the attachment.

These activities constitute completion of the one radioactive solid waste processing, and radioactive material handling, storage, and transportation sample as defined in Inspection Procedure 71124.08-05.

b. Findings

No findings were identified.

OTHER ACTIVITIES

Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity, Emergency Preparedness, Public Radiation Safety, and Occupational Radiation Safety

4OA1 Performance Indicator Verification

.1 Data Submission Issue

a. Inspection Scope

The inspectors performed a review of the data submitted by the licensee for the third quarter 2012 performance indicators for any obvious inconsistencies prior to its public release in accordance with NRC Inspection Manual Chapter as such, did not constitute a separate inspection sample.

b. Findings

No findings were identified.

.2 Mitigating Systems Performance Index - Emergency ac Power System (MS06)

a. Inspection Scope

The inspectors sampled licensee submittals for the mitigating systems performance index emergency ac power system performance indicator for Units 1 and 2 for the period from the third quarter 2011 through the second quarter 2012. To determine the accuracy of the performance indicator data reported during those periods, the inspectors used definitions and guidance contained in Nuclear Energy Institute Document 99-02, derivation reports, condition reports, and NRC integrated inspection reports to validate the accuracy of the submittals. The inspectors reviewed the mitigating systems performance index component risk coefficient to determine if it had changed by more than 25 percent in value since the previous inspection, and if so, that the change was in accordance with applicable Nuclear Energy Institute guidance. The inspectors also identified with the performance indicator data collected or transmitted for this indicator and none were identified. These activities constitute completion of two mitigating systems performance index emergency ac power system samples as defined in Inspection Procedure 71151-05.

b. Findings

No findings were identified.

.3 Mitigating Systems Performance Index - High Pressure Injection Systems (MS07)

a. Inspection Scope

The inspectors sampled licensee submittals for the mitigating systems performance index high pressure injection systems performance indicator for Units 1 and 2 for the period from the third quarter 2011 through the second quarter 2012. To determine the accuracy of the performance indicator data reported during those periods, the inspectors used definitions and guidance contained in Nuclear Energy Institute Document 99-02, performance index derivation reports, and NRC integrated inspection reports to validate the accuracy of the submittals. The inspectors reviewed the mitigating systems performance index component risk coefficient to determine if it had changed by more than 25 percent in value since the previous inspection, and if so, that the change was in accordance with applicable Nuclear Energy Institute guidance. The inspectors also identified with the performance indicator data collected or transmitted for this indicator and none were identified.

These activities constitute completion of two mitigating systems performance index high pressure injection system samples as defined in Inspection Procedure 71151-05.

b. Findings

No findings were identified.

.4 Mitigating Systems Performance Index - Heat Removal System (MS08)

a. Inspection Scope

The inspectors sampled licensee submittals for the mitigating systems performance index heat removal system performance indicator for Units 1 and 2 for the period from the third quarter 2011 through the second quarter 2012. To determine the accuracy of the performance indicator data reported during those periods, the inspectors used definitions and guidance contained in Nuclear Energy Institute Document 99-02, sion 6. The inspectors performance index derivation reports, and NRC integrated inspection reports to validate the accuracy of the submittals. The inspectors reviewed the mitigating systems performance index component risk coefficient to determine if it had changed by more than 25 percent in value since the previous inspection, and if so, that the change was in accordance with applicable Nuclear Energy Institute guidance. The inspectors also identified with the performance indicator data collected or transmitted for this indicator and none were identified.

These activities constitute completion of two mitigating systems performance index heat removal system samples as defined in Inspection Procedure 71151-05.

b. Findings

No findings were identified.

.5 Mitigating Systems Performance Index

Residual Heat Removal System (MS09)

a. Inspection Scope

The inspectors sampled licensee submittals for the mitigating systems performance index residual heat removal system performance indicator for Units 1 and 2 for the period from the fourth quarter 2011 through the third quarter 2012. To determine the accuracy of the performance indicator data reported during those periods, performance indicator definitions and guidance contained in Nuclear Energy Institute Document 99-02, Regulatory Assessment Performance Indicator Guideline, 6, and NUREG-1022, CFR 50.72 and 50.73 definitions logs, operability assessments, maintenance rule records, maintenance work orders, condition reports, and NRC Integrated Inspection reports to validate the accuracy of the condition report database to determine if any problems had been identified with the performance indicator data collected or transmitted for this indicator and none were identified. Specific documents reviewed are described in the attachment to this report. These activities constitute completion of two mitigating systems performance index residual heat removal system samples as defined in Inspection Procedure 71151-05.

b. Findings

No findings were identified.

.6 Mitigating Systems Performance Index

Cooling Water Systems (MS10)

a. Inspection Scope

The inspectors sampled licensee submittals for the mitigating systems performance index cooling water systems performance indicator for Units 1 and 2 for the period from the fourth quarter 2011 through the third quarter 2012. To determine the accuracy of the performance indicator data reported during those periods, the inspectors used definitions and guidance contained in Nuclear Energy Institute Document 99-on 6. The inspectors reviewed the reports, condition reports, and NRC integrated inspection reports to validate the accuracy of the submittals. The inspectors reviewed the mitigating systems performance index component risk coefficient to determine if it had changed by more than 25 percent in value since the previous inspection, and if so, that the change was in accordance with applicable Nuclear Energy Institute guidance. The inspectors also identified with the performance indicator data collected or transmitted for this indicator and none were identified. Specific documents reviewed are described in the attachment to this report. These activities constitute completion of two mitigating systems performance index cooling water systems samples as defined in Inspection Procedure 71151-05.

b. Findings

No findings were identified.

.7 Occupational Exposure Control Effectiveness (OR01)

a. Inspection Scope

The inspectors reviewed performance indicator data for the third quarter of 2011 through the third quarter of 2012. The objective of the inspection was to determine the accuracy and completeness of the performance indicator data reported during these periods. The inspectors used the definitions and clarifying notes contained in Nuclear Energy Institute Document 99-as criteria for determining whether the licensee was in compliance.

The inspectors reviewed corrective action program records associated with high radiation areas (greater than 1 rem/hr) and very high radiation area non-conformances. The inspectors reviewed radiological, controlled area exit transactions greater than 100 mrem. The inspectors also conducted walkdowns of high radiation areas (greater than 1 rem/hr) and very high radiation area entrances to determine the adequacy of the controls of these areas. These activities constitute completion of one occupational exposure control effectiveness sample as defined in Inspection Procedure 71151-05.

b. Findings

No findings were identified.

.8 Radiological Effluent Technical Specifications/Offsite Dose Calculation Manual Radiological Effluent Occurrences (PR01)

a. Inspection Scope

The inspectors reviewed performance indicator data for the third quarter of 2011 through the third quarter of 2012. The objective of the inspection was to determine the accuracy and completeness of the performance indicator data reported during these periods. The inspectors used the definitions and clarifying notes contained in Nuclear Energy Institute Document 99-as criteria for determining whether the licensee was in compliance.

The inspectors individual annual or special reports to identify potential occurrences such as unmonitored, uncontrolled, or improperly calculated effluent releases that may have impacted offsite dose.

These activities constitute completion of one radiological effluent technical specifications/offsite dose calculation manual radiological effluent occurrences sample as defined in Inspection Procedure 71151-05.

b. Findings

No findings were identified.

4OA2 Identification and Resolution of Problems

.1 Routine Review of Identification and Resolution of Problems

a. Inspection Scope

As part of the various baseline inspection procedures discussed in previous sections of this report, the inspectors routinely reviewed issues during baseline inspection activities and plancorrective action program at an appropriate threshold, that adequate attention was being given to timely corrective actions, and that adverse trends were identified and addressed. The inspectors reviewed attributes that included: the complete and accurate identification of the problem; the timely correction, commensurate with the safety significance; the evaluation and disposition of performance issues, generic implications, common causes, contributing factors, root causes, extent of condition reviews, and previous occurrences reviews; and the classification, prioritization, focus, action proof documents reviewed. These routine reviews for the identification and resolution of problems did not constitute any additional inspection samples. Instead, by procedure, they were considered an integral part of the inspections performed during the quarter and documented in Section 1 of this report.

b. Findings

No findings were identified.

.2 Daily Corrective Action Program Reviews

a. Inspection Scope

In order to assist with the identification of repetitive equipment failures and specific human performance issues for follow-up, the inspectors performed a daily screening of accomplished this through re The inspectors performed these daily reviews as part of their daily plant status monitoring activities, so these reviews did not constitute any separate inspection samples.

b. Findings

No findings were identified.

.3 Semi-Annual Trend Review

a. Inspection Scope

The inspectors reviewed documents to identify trends that could indicate the existence of a more significant safety issue. The inspectors focused on plant transients. The inspectors reviewed documents and interviewed personnel to determine if the licensee completely and accurately identified problems in a timely manner commensurate with its significance, evaluated and dispositioned operability issues, considered the extent of condition, prioritized the problem commensurate with its safety significance, identified appropriate corrective actions, and completed corrective actions in a timely manner commensurate with the safety significance of the issue. These activities constitute completion of one semi-annual trend review inspection sample as defined in Inspection Procedure 71152-05.

b. Findings and Observations

No findings were identified.

The inspectors observed that the units have experienced several plant transients in the recent months. On November 2, 2012, Unit 1 operators initiated a manual reactor trip as a result of a reactor coolant pump 4 lower motor bearing high temperature. On November 6, 2012, Unit 2 operators reduced power to 49 percent as a result of high sodium levels in the steam generators. On November 17, 2012, Unit 2 operators experienced an automatic reactor trip as a result of a low steam generator level. The low level was the result of a transient initiated by the heater drain system. On November 20, 2012, Unit 2 operators initiated a manual runback of the turbine to 900 megawatts, approximately 75 percent power, as a result of a transient of heater drain system. The licensee initiated condition reports for the above transients.

===.4 Operator Workarounds

a. Inspection Scope

The inspectors reviewed the Unit 2 cumulative effects of the operator workarounds and burdens to determine the reliability, availability, and potential for incorrect operation of systems or components. The inspectors verified the ability of operators to respond in a correct and timely manner to plant transients and accidents, and if the licensee has identified and implemented appropriate corrective actions associated with operator workarounds. These activities constitute completion of one operator workarounds sample as defined in Inspection Procedure 71152-05.

b. Findings

No findings were identified.

=

The activities documented below constitute completion of two event followup samples as defined in Inspection Procedure 71153.

.1 Unit 1 Manual Reactor Trip

a. Inspection Scope

On November 2, 2012, operators manually tripped the reactor as a result of a high motor bearing temperature on reactor coolant pump 4. The inspectors responded to the inspectors performed a walkdown of the control boards to verify appropriate equipment response following the trip. The inspectors discussed the trip with operations management and the control room staff.

b. Findings

No findings were identified.

.2 Unit 2 Automatic Reactor Trip

a. Inspection Scope

On November 17, 2012, the unit experienced an automatic reactor trip as a result of a low steam generator level. The low level was the result of a transient initiated by the heater drain system. The inspectors responded to the control room to access the The inspectors performed a walkdown of the control boards to verify appropriate equipment response following the trip. The inspectors discussed the trip with operations management and the control room staff.

b. Findings

No findings were identified.

OA5 Other

.1 (Closed) NRC Temporary Instruction Emergency Core Cooling, Decay Heat Removal and Containment Spray Systems (NRC Generic Letter 2008- As documented in NRC Inspection Reports 05000445/2010003; 2011003; 2011004 and 05000446/2010003; 2011003; 2011004, the inspectors completed activities associated with Temporary Instruction 2515/177. .2 (Closed) NRC Temporary Instruction 2515/187Inspection of Near-Term Task Force Recommendatio

a. Inspection Scope

The inspectors verified that the for the safe shutdown impoundment riprap, service water intake structure north wall, and the service water pipe tunnel contained the elements as specified in Nuclear Energy Institute 12-07 Walkdown Guidance. The inspectors accompanied the licensee on their walkdowns of the safe shutdown impoundment riprap, service water intake structure north wall, and the diesel generator fuel oil storage tank covers. In addition, the inspectors independently performed a walkdown of the service water pipe tunnel. For each of the walkdowns, the inspectors confirmed that the licensee verified the following flood protection features, as applicable: External visual inspection for indications of degradation that would prevent its credited function from being performed Reasonable simulation Critical structure system and component dimensions were measured Available physical margin was determined Flood protection feature functionality was determined using either visual observation or by review of other documents The inspectors verified that noncompliances with current licensing requirements, and issues identified in accordance with the 10 CFR 50.54(f) letter, Item 2.g of Enclosure 4, were entered into the licensee's corrective action program. In addition, issues identified ability to mitigate the consequences will be subject to additional NRC evaluation.

b. Findings

No findings were identified.

OA6 Meetings

Exit Meeting Summary

On October 18, 2012, the inspectors presented the results of the first radiation safety inspection to Mr. K. Peters, Site Vice President, and other members of the licensee staff. The licensee acknowledged the issues presented. The inspectors asked the licensee whether any materials examined during the inspection should be considered proprietary. No proprietary information was identified. On October 19, 2012, the inspectors presented the inspection results of the review of inservice inspection activities to Mr. K. Nickerson, Director, Site Engineering, and other members of the licensee staff. The licensee acknowledged the issues presented. The inspectors asked the licensee whether any materials examined during the inspection should be considered proprietary. No proprietary information was identified. On December 7, 2012, the inspectors presented the results of the second radiation safety inspection to Mr. K. Peters, Site Vice President, and other members of the licensee staff. The licensee acknowledged the issues presented. The inspectors asked the licensee whether any materials examined during the inspection should be considered proprietary. No proprietary information was identified. On January 15, 2013, the inspectors presented the resident inspection results to Mr. K. Peters, Site Vice President, and other members of the licensee staff. The licensee acknowledged the issues presented. The inspectors acknowledged review of proprietary material during the inspection. No proprietary information has been included in the report.

SUPPLEMENTAL INFORMATION

KEY POINTS OF CONTACT

Licensee Personnel

R. Flores, Senior Vice President and Chief Nuclear Officer

T. Gilder, Director, Performance Improvement

D. Goodwin, Director, Engineering Support

T. Hope, Manager, Nuclear Licensing

B. Kidwell, Manager, Emergency Preparedness

F. Madden, Director, Oversight and Regulatory Affairs

B. Mays, Vice President, Engineering and Support

K. Nickerson, Director, Site Engineering

B. Patrick, Director, Maintenance

K. Peters, Site Vice President

S. Sewell, Director, Organizational Effectiveness

M. Smith, Director, Operations

S. Smith, Plant Manager

K. Tate, Manager, Security

D. Wilder, Director, Plant Support

LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED

Opened and Closed

05000446/2012005-01 NCV Foreign Material in Diesel Generator Governor Causes Start Failure (Section 1R15) Closed 2515/177 TI Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems (NRC Generic Letter 2008-01) (Section 4OA5.1) 2515/187 TI Inspection of Near-Term Task Force Recommendation 2.3 Flooding Walkdowns (Section 4OA5.2)

Attachment 1

Section 1R01: Adverse Weather Protection

PROCEDURES NUMBER TITLE REVISION

OWI-912 Cold Weather 3

STA-634 Extreme Temperature Equipment Protection Program 4

ABN-912 Extreme Cold Weather/Heat Tracing and Freeze Protection System Malfunction 8

CONDITION REPORTS 2012-012000

Section 1RO4: Equipment Alignments

CONDITION REPORTS 2012-011186

Section 1RO5: Fire Protection

CONDITION REPORTS 2012-011627 2012-012332

MISCELLANEOUS DOCUMENTS NUMBER TITLE REVISION M1-1928 Fire Hazard Analysis Auxiliary and Electrical Control Bldg EL -- CP-3

Section 1RO6: Flood Protection Measures

DRAWINGS NUMBER TITLE REVISION M1-0313 Flow Diagram

Ventilation Control Building UPS Area A/C Systems

CP-21 M1-0236 Sh. 01 Flow Diagram Vents and Drains System Auxiliary Building

CP-17 M1-0236 Sh. B Flow Diagram Vents and Drains System Safeguards and Auxiliary Building

CP-3

CONDITION REPORTS 2012-006995

Attachment 1

WORK ORDERS

4160670 3657316

Section 1R08: Inservice Inspection Activities

CONDITION REPORTS 2011-001730 2011-005859 2011-011428 2012-001789 2012-005329 2011-002860 2011-006088 2011-011726 2012-001922 2012-005394 2011-003711 2011-006096 2011-012490 2012-001935 2012-005646 2011-003722 2011-006132 2011-012678 2012-001991 2012-005681 2011-003808 2011-006186 2011-012901 2012-002002 2012-005767 2011-003836 2011-006276 2011-013075 2012-002110 2012-005873 2011-003893 2011-006370 2011-013204 2012-002289 2012-005922 2011-003963 2011-006409 2011-013235 2012-002627 2012-005956 2011-004012 2011-006583 2011-013416 2012-002684 2012-006200 2011-004034 2011-006796 2011-013552 2012-002726 2012-006459 2011-004198 2011-006802 2011-013634 2012-002761 2012-006587 2011-004296 2011-006814 2011-013714 2012-002766 2012-007048 2011-004452 2011-007035 2011-013774 2012-002998 2012-007186 2011-004521 2011-007420 2011-013797 2012-003178 2012-007267 2011-004543 2011-007595 2011-013799 2012-003331 2012-007290 2011-004565 2011-007822 2011-013908 2012-003394 2012-007717 2011-004607 2011-008225 2011-013948 2012-003413 2012-007763 2011-004639 2011-008258 2011-013956 2012-003423 2012-007772 2011-004690 2011-008371 2012-000077 2012-003448 2012-007838 2011-004727 2011-008727 2012-000145 2012-003529 2012-007955 2011-004810 2011-008930 2012-000175 2012-003549 2012-007958 2011-004987 2011-008948 2012-000263 2012-003610 2012-008137 2011-004992 2011-009263 2012-000777 2012-003618 2012-008144 2011-005117 2011-009899 2012-000848 2012-003735 2012-008451 2011-005146 2011-009975 2012-001258 2012-004126 2012-009103 2011-005426 2011-010045 2012-001292 2012-004142 2012-009150 2011-005470 2011-010087 2012-001380 2012-004337 2012-009472 2011-005523 2011-010090 2012-001473 2012-004623 2012-010309 2011-005701 2011-010196 2012-001684 2012-004678

2011-005805 2011-010662 2012-001689 2012-005174

Attachment 1

DRAWINGS NUMBER TITLE REVISION

SK-0001-10-000172-21-01 Chemical and Volume Control 1

BRP-CS-2-AB-069 Sheets 1 and 2 Chemical and Volume Control

CP-6

NONDESTRUCTIVE EXAMINATION REPORTS

MT-2012-002

MT-2012-005

MT-2012-009

MT-2012-016

PT-2012-015

PT-2012-016

RT-FW-11

RT-TUX-7-1

RT-TUX-8-1

RT-TUX-9-1

RT-TUX-10-1

UT-2012-028

UT-2012-029

UT-2012-031

UT-2012-039

UT-2012-044

UT-2012-046

UT-2012-050

UT-2012-051

UT-2012-055

UT-2012-056

VT-2012-070

VT-2012-071

VT-2012-094

VT-2012-118

WDI-PJR-1308102-FSR-001

PROCEDURES NUMBER TITLE REVISION

RCS Pressure Boundary Dissimilar Metal Weld Visual Examination Plan 3

RCS Pressure Boundary Dissimilar Metal Weld Visual Examination Plan 4

STA-737 Boric Acid Corrosion Detection And Evaluation 6

TX-ISI-11 Liquid Penetrant Examination for Comanche Peak Steam Electric Station 11

TX-ISI-210- Ultrasonic Examination Procedure for Welds in Ferritic Steel Vessels 7

TX-ISI-8

VT-1 and

VT-3 Examination Procedure for CPSES 6

WLD-106 CPSES Welding Program Manual 2

WORK ORDERS

3810474

3811873

3814062

4126033

4158042

4158087

4162345

4325372

4325385

4325413

4333871

4358851

4368387

4408186

4409608

4409637

4427800

4488074

4489415

4491886

4495800

4495925

4496017

4496875

4498261

Attachment 1

MISCELLANEOUS DOCUMENTS NUMBER TITLE REVISION / DATE

On-going Self-Assessment or NOD Surveillance - QA Surveillance July 14, 2011

Comanche Peak Steam Electric Station, Units 1 and 2 -Request for Relief to Extend the Inservice Inspection Interval for the Reactor Vessel Weld Examination (Tac Nos. ME0777 And ME0778) December 22, 2009 Assessment No.

CR-2011-006510 Comanche Peak Nuclear Power Plant Welding Program Self Assessment August 30, 2011 Condition Report

CR-2012-002117 CPNPP Self-Assessment Report:

Reactor Coolant System Materials Management Program April 26, 2012 Condition Report

CR-2012-002117 CPNPP Self-Assessment Worksheet:

Boric Acid Corrosion Control (BACC) and Leak Management Program April 12, 2012 Condition Report

CR-2012-002117 CPNPP Self-Assessment Worksheet:

Boric Acid Corrosion Control (BACC) and Leak Management Program April 12, 2012

CP-201200879

TXX-12116 Comanche Peak Nuclear Power Plant, Docket Nos. 50-445 and 50-446, Relief Request No. V-1 for Unit 1 and Unit 2 Inservice Testing Plan for Pumps and Valves (ASME OM Code 2004 Edition, thorough 2006 Addenda: Third Interval Start Date: August 3, 2013) September 6, 2012

CP-201200978

TXX-12129 Comanche Peak Nuclear Power Plant, Docket 50-445, Relief Request No. C-2 for the Unit 1 Reactor Pressure Vessel Leak-Off Flange (Third ISI Interval Start Date: August 13, 2010 August 23, 2012

EV-CR-2011-002860-1 Evaluation of increased leakage from borated systems in U2 containment prior to 2RF12 March 14, 2011

EV-CR-2012-001473-1 Evaluation to identify acceptable stainless steel replacement for bolts, nuts, and washers for

TBX-RHA February 9, 2012

EV-CR-2012-001473-3 Evaluations for boric acid accumulations on RHR pumps February 9, 2012

EV-CR-2012-003331-1 Evaluations for boric acid accumulations identified during the U2 containment boric acid inspection for the U2 Trip April 2, 2012

EV-CR-2012-010309-1 Evaluations for boric acid accumulations identified during the 2RF13 mode 3 boric acid inspection October 6, 2012

FDA 10-000172-21 Replace Remote Operated Manual Gate Valve

2-8402A with a Motor Operated Gate Valve.

Work Order #

4333871 September 19, 2012 Self-Assessment

SA-2009-025 CPSES Self-Assessment Report Title: Inservice Inspection Processes and Program September 17, 2009 Self-Assessment

SA-2010-004 CPSES Self-Assessment Report:

Steam Generator June 16, 2010 Weld Doc: Comanche Peak Nuclear Power Plant Weld Record(s).

April 18, 2012

Attachment 1

MISCELLANEOUS DOCUMENTS NUMBER TITLE REVISION / DATE

120209 Work Order

4333871 Weld Doc:

1202139 Comanche Peak Nuclear Power Plant Weld Record(s).

Work Order

4333871 May 17, 2012 WPS:

CP-301 Comanche Peak Steam Electric Station Welding Procedure Specification 11

Section 1R11: Licensed Operator Requalification Program

PROCEDURES NUMBER TITLE REVISION

IPO-010B Reactor Coolant Systems Reduced Inventory Operations 13

Section 1R12: Maintenance Effectiveness

CONDITION REPORTS 2012-010932

Section 1R13: Maintenance Risk Assessments and Emergent Work Control

CONDITION REPORTS 2012-010737

Section 1R15: Operability Evaluations

MISCELLANEOUS DOCUMENTS

TITLE DATE

SI and Blackout Sequencers Study Guide June 10, 2011

WORK ORDERS

4154915

CONDITION REPORTS 2012-004598 2012-004336 2012-011513 2005-003468

Section 1R19: Post-Maintenance Testing

Attachment 1

CONDITION REPORTS 2012-011360 2008-002053

MISCELLANEOUS DOCUMENTS NUMBER TITLE REVISION

OPT-509B MSIV Testing 6

ETP-215B Service Water Pump Test 5

Section 1R20: Refueling and Other Outage Activities

PROCEDURES NUMBER TITLE REVISION

IPO-010B Reactor Coolant Systems Reduced Inventory Operations 13

OPT-305 Containment Close Out Inspection 12

Section 1R22: Surveillance Testing

WORK ORDERS

4180576

4135154

2RS01 Radiological Hazard Assessment and Exposure Controls

PROCEDURES NUMBER TITLE REVISION

RPI-110 Radiation Protection Shift Activities 19

RPI-212 Radioactive Source Control 12

RPI-602 Radiological Surveillance and Posting 51

RPI-606 Radiation Work and General Access Permits 22

RPI-623 Radiological Briefings

5

RPI-700 Sealed Source Leak Testing 11

STA-652 Radioactive Material Control 17

STA-656 Radiation Work Control 18

STA-660

Control of High Radiation Areas 15

CONDITION REPORTS 2011-007690 2011-011743 2011-013888 2011-013951 2011-014104 2012-010171 2012-010669 2012-010850

Attachment 1

RADIOLOGICAL SURVEYS NUMBER TITLE DATE 12-08-0603 -213 September 1, 2012 12-09-0043 Warehouse C September 17, 2012 12-09-0237 -213 September 15, 2012 12-09-0535 -213 September 28, 2012 12-10-0603 -213 October 4, 2012 12-10-0938 Warehouse C October 16, 2012

RADIATION WORK PACKAGES NUMBER TITLE

20111215 1RF15 Scaffold Activities

20110600 1RF15 Refuel

20122103 2RF13 Chemistry Sampling Crud Burst and Cleanup

20122219 Rework

2-8956B Check Valve

20122402 Gas Void UTs Elevated Dose Rates and Posted HRAs

20122404 2RF13 ISI, VT2, and FAC Activities

20122600 2RF13 Refuel Activities

20122603 2RF13 Alloy 600 Inspections

MISCELLANEOUS DOCUMENTS TITLE DATE LHRA and VHRA Key Inventory

October 2012 Sealed Sources Inventory October 2012 Leak Test Records October 2012

2RS02 Occupational ALARA Planning and Controls

PROCEDURES NUMBER TITLE REVISION

RPI-601 Radiation Protection Outage Preparations 22

RPI-606 Radiation Work and General Access Permits 22

RPI-607 Radiation Work

Permit In-Process Review/Revision 2

RPI-608 Control of Shielding

11

RPI-628 Stop Work Criteria 0

STA-651 ALARA Program 10

Attachment 1

PROCEDURES NUMBER TITLE REVISION

STA-657 ALARA Job Planning/Debriefing 11

CONDITION REPORTS 2011-000954 2011-009376 2011-010859 2011-011158 2011-012155 2011-011569

RADIATION WORK PACKAGES NUMBER TITLE

20110403 Snubber Work

20110404 ISI Inspection

20111100 Radiation Protection/Decon in Containment

20111101 Operators in RCAs

20111102 Radiation Protection/Decon in

BOP 20111600 1RF15 Refuel

20111603 1RF15 Alloy 600 Inspections

20112215 Scaffolding

20120202 Maintenance in Reactor Building

20120601 In-Core Instruments

MISCELLANEOUS DOCUMENTS TITLE DATE 1RF15 Radiation Protection Outage ALARA Report

January 30, 2012 1RF15 Radiation Work Permit 1600 Critique January 30, 2012 CPNPP Five Year Dose Reduction Plan 2010-2015 January 19, 2012

CPNPP-EPRI pH Evaluation December 2007 Unit-1 RWST Activity Graph October 2012

Section 2RS05:

Radiation Monitoring Instrumentation

PROCEDURES NUMBER TITLE REVISION

INC-7081X DCOT & CCAL

Liquid Waste Eff Process Radiation Monitor CH X-RE-5253 6

INC-7084 DCOT & CCAL

Turbine Building Floor Drains LPRM

CH 1-RE-5100/2-RE-5100 8

Attachment 1

PROCEDURES NUMBER TITLE REVISION

INC-7090X X-RE-5570B 6

RPI-862 Calibration Of The Argos/Sirius Personnel Contamination Monitor 9

RPI-881 Calibration of Portable Dose Rate Instruments 18

RPI-886 Calibration Of The Eberline Pm-7 Personnel Monitor 5

RPI-889 Calibration Of The Eberline Ams-4 3

RPI-895 Calibration Of The NE Technology SAM (Small Articles Monitor) 5

CONDITION REPORTS 2011-000498 2011-006833 2012-007687 2012-008063 2012-008251 2012-010167 2012-011264 2012-012478

CALIBRATION OF INSTALLED MONITORS NUMBER TITLE DATE

3719821 Turbine Building Sump Liquid Effluent 2-RE-5100 January 14, 2011

4084148 Turbine Building Sump Liquid Effluent 2-RE-5100 July 11, 2012

3578968 Liquid Waste Processing Discharge X-RE-5253 March 24, 2010

3912453 Liquid Waste Processing Discharge X-RE-5253 November 7, 2011

3539008 North Vent Stack Wide Range Gas X-RE-5570B March 25, 2010

3914751 North Vent Stack Wide Range Gas X-RE-5570B December 16, 2011

3610666 Unit 1 Containment High Range 1-RE-6290A April 20, 2010

3937711 Unit 1 Containment High Range 1-RE-6290A October 14, 2011

3817738 Unit 2 Containment High Range 2-RE-6290B April 16, 2011

4141666 Unit 2 Containment High Range 2-RE-6290B October 24, 2012 3-04-308372-01 Unit 1 Containment Incore High Range 1-RE-6256 July 19, 2005

3561314 Unit 1 Containment Incore High Range 1-RE-6256 November 11, 2009

3907837 Flow channel 5288 August 4, 2011

CALIBRATION OF RADIATION PROTECTION INSTRUMENTS NUMBER TITLE DATE 0058 ARGOS/Sirius Personnel Contamination Monitor June 19, 2012 0026 Eberline Model

PM-7 Personnel Contamination Monitor November 27, 2012 1907 MGP Telepole May 30, 2012

Attachment 1

CALIBRATION OF RADIATION PROTECTION INSTRUMENTS NUMBER TITLE DATE 3122 Radeye G July 11, 2012 30282 Electrometer/Ion Chamber March 07, 2012

MISCELLANEOUS DOCUMENTS TITLE DATE Chemistry Quality Assurance Report (Ge Detectors 1-6) December 3, 2012 Chemistry Quality Assurance Report (Ge Detectors 1-6) December 4, 2012

Section 2RS06:

Radioactive Gaseous and Liquid Effluent Treatment

PROCEDURES NUMBER TITLE REVISION

CHM-104 Quality Assurance and Quality Control 21

CHM-170 Liquid and Gaseous Effluent Program 3

CLI-741 Setpoint Modification and DRMS Pre-Release Surveillance 7

CLI-745 Radioactive Effluent Post-Release Permit Processing and Surveillance Tracking 2

CLI-768 Calculation of Dose Equivalent I-131 5

COP-816 Plant Ventilation 6

PPT-SX-7503A Control Room Ventilation Filtration Carbon Analysis

Train A 0

PPT-SX-7504B Control Room Ventilation Filtration Carbon Analysis

Train B 0

PPT-SX-7511A Primary Plant ESF Filter Carbon Analysis

Train A 1

PPT-SX-7512B Primary Plant ESF Filter Carbon Analysis

Train B 1

PPT-SX-7520A Control Room Ventilation Filter Test

CPX-VAFUPK-21 1

STA-654 Groundwater Protection Program 8

AUDITS,

SELF-ASSESSMENTS, AND SURVEILLANCES NUMBER TITLE DATE

EVAL-2011-001 Radiation Protection June 23, 2011

EVAL-2011-006 Radioactive Waste, Effluent, Environmental, and Chemistry August 25, 2011

Attachment 1

CONDITION REPORTS 2010-006694 2011-001885 2011-002479 2011-003303 2011-003459 2011-009252 2011-009403 2011-009686 2011-010612 2012-010418 2012-010712 2012-011703

RELEASE PERMITS G2011-173 G2012-214 G2012-215 G2012-216 G2012-220 G2012-221 L2011-046 L2012-065

SAMPLING AND ANALYSIS RESULTS NUMBER TITLE DATE

177142 Effluent Support System - SPVS Gas December 4, 2012

177143 Effluent Support System - Iodine WRGM December 4, 2012

177144 Effluent Support System - SPVS Particulate December 4, 2012

177145 Effluent Support System - NPVS Gas December 4, 2012

177146 Effluent Support System - NPVS Iodine December 4, 2012

177147 Effluent Support System - NPVS Particulate December 4, 2012

IN-PLACE FILTER TESTING RECORDS SYSTEM TEST DATE Primary Plant Ventilation Exhaust Filter Unit X-16 Charcoal Sample October 15, 2011 Primary Plant Ventilation Exhaust Filter Unit X-02 Charcoal Sample November 21, 2011 Control Room Emergency Pressurization Unit X-21 Filter Sample February 21, 2012 Control Room Emergency Pressurization Unit X-22 Filter Sample March 21, 2012 Primary Plant Ventilation Exhaust Filter Unit X-15 Charcoal Sample March 26, 2012 Control Room Emergency Filtration Unit X-23 Charcoal Sample April 19, 2012 Primary Plant Ventilation Exhaust Filter Unit X-01 Charcoal Sample April 23, 2012 Control Room Emergency Filtration Unit X-24 Charcoal Sample June 12, 2012

Attachment 1

MISCELLANEOUS DOCUMENTS TITLE REVISION / DATE CPSES Offsite Dose Calculation Manual

Unit 1 and Unit 2 32 Final Safety Analysis Report

Ch. 11: Radioactive Waste Management 104 Results of Radiochemistry Cross Check Program

4th Quartile 2011 January 12, 2012 2010 Radioactive Effluent Release Report March 28, 2011 Annual Radiological Environmental Operating Report for 2010 March 29, 2011 2011 Radioactive Effluent Release Report April 4, 2012 Annual Radiological Environmental Operating Report for 2011 April 25, 2012 Radiation Monitoring System health Report

1st Quarter FY12

Radiation Monitoring System health Report

3rd Quarter FY12

CONDITION REPORTS 2010-2024 2010-7432 2010-8111 2010-9198 2011-3303

Section 2RS07:

Radiological Environmental Monitoring Program

PROCEDURES NUMBER TITLE REVISION

STA-654 Groundwater Protection Program 8

RPI-521 General Area Monitoring Program 12

RPI-710 Radiological Environmental Monitoring, Sampling, and Analysis Program 18

RPI-713 Collection, Preparation, and Shipment of Radiological Environmental Samples 12

RPI-714 Land Use Census 5

AUDITS,

SELF-ASSESSMENTS, AND SURVEILLANCES NUMBER TITLE DATE

EPRI Groundwater Protection Initiative Self Assessment July 26, 2012 22873 NUPIC Audit for GEL Laboratories LLC (Supplier No. 5644)

December 10, 2011

EVAL-2011-006 Radioactive Waste, Effluent, Environmental, and Chemistry (QA) August 2, 2011

CONDITION REPORTS 2010-005641 2010-007417 2010-009485 2010-011063 2011-005937

Attachment 1

CONDITION REPORTS 2011-010659 2011-010945 2012-001947 2012-003122 2012-004808 2012-007450 2012-007451 2012-007544 2012-007854

CALIBRATION AND MAINTENANCE RECORDS NUMBER TITLE DATE 2181B Low Volume Air Sampler Calibration Data Sheet April 19, 2012 2181B Low Volume Air Sampler Calibration Data Sheet November 27, 2012 2184B Low Volume Air Sampler Calibration Data Sheet March 22, 2012 2184B Low Volume Air Sampler Calibration Data Sheet June 13, 2012 2188B Low Volume Air Sampler Calibration Data Sheet February15, 2011 2188B Low Volume Air Sampler Calibration Data Sheet July 3, 2012 2194B Low Volume Air Sampler Calibration Data Sheet March 2, 2012 2194B Low Volume Air Sampler Calibration Data Sheet June 13, 2012 2196B Low Volume Air Sampler Calibration Data Sheet February 14, 2011 2196B Low Volume Air Sampler Calibration Data Sheet November 27, 2012

MISCELLANEOUS DOCUMENTS NUMBER TITLE REVISION / DATE

Offsite Dose Calculation Manual - Units 1 & 2 32

Percentage of Good Control Room Meteorological Data from Jan. 1, 2012 to Dec. 3, 2012 December 4, 2012 2011 Radiological Environmental Operating Report May 1, 2012 2010 Land Use Census August 4, 2010 2011 Land Use Census December 13, 2011

Section 2RS08:

Radioactive Solid Waste Processing and Radioactive Material handling, Storage, and Transportation

PROCEDURES NUMBER TITLE REVISION

RPI-215 Waste Stream Sampling 6

RPI-232 Characterizing Radioactive Material for Shipment 5

RPI-242 Radioactive Waste Characterization and Classification 7

STA-709 Radioactive Waste Management Program 9

STA-713 Process Control Program 2

CONDITION REPORTS 2010-011055 2011-005649 2012-005042 2011-008222 2010-011041

Attachment 1

CONDITION REPORTS 2011-001130 2011-006170 2011-007503 2011-007690 2011-010278 2011-009448 2011-010177 2011-010865 2011-011621 2011-011631 2011-013432 2011-013567 2011-013781 2012-012700 2012-012778

RADIOACTIVE MATERIAL SHIPMENTS NUMBER TITLE DATE 2010-055 RHR Pump Impeller-Diffuser December 15, 2010 2011-024 Dry Active Waste April 27, 2011 2011-054 Dry Active Waste, Contaminated Metal September 21, 2011 2012-009 Anion Resins April 4, 2012

RADIOACTIVE MATERIAL SHIPMENT SURVEYS NUMBER TITLE DATE 11-03-00388 5 Gallon Container Survey March 21, 2011 11-10-0164 Shipment Drum Container Survey October 3, 2011 12-02-0369 5 Gallon Container Survey February 21, 2012 12-04-0274 Classification Drum Container Survey April 11, 2012

RADIOACTIVE MATERIAL STORAGE SURVEYS NUMBER TITLE DATE 12-09-0043

September 4, 2012 12-11-0586

November 26, 2012 12-11-0587

November 26, 2012 12-11-0592 Interim Low Level Rad Waste Storage Area November 26, 2012

MISCELLANEOUS DOCUMENTS NUMBER TITLE REVISION / DATE

2010 Radioactive Effluent Release Report March 28, 2011

2011 Radioactive Effluent Release Report April 4, 2012

CPNPP Core Status and Fuel Performance Update Report November 30, 2012

CPNPP Self-Assessment Report Condition Report:

CR-2010-001175 January 24, 2011

Customer Monthly Report: Burial and Return Summary December 2010 - October 2012

Attachment 1

MISCELLANEOUS DOCUMENTS NUMBER TITLE REVISION / DATE

Radioactive Material/Waste Shipping Log December 8, 2010 - November 7, 2012

Radioactive Waste Storage Vault Inventory

Training Records for Shipping Personnel

Waste Stream Report November 6, 2012

EVAL-2011-006 CPNPP Quality Assurance Evaluation Planning and Performance Evaluation: Radioactive Waste, Effluent, Environment, and Chemistry January 19, 2011

RPI-202-1 2011 Radioactive Material Receipt Log 5

RPI-202-1 2012 Radioactive Material Receipt Log 6

Section 4OA1: Performance Indicator Verification

MISCELLANEOUS DOCUMENTS NUMBER TITLE DATE N/A Radiation Safety NRC Performance Indicators

October 2012

Section 4OA2: Identification and Resolution of Problems

CONDITION REPORTS 2012-011607 2012-011805 2012-01229

Section 4OA5: Other

CONDITION REPORTS 2012-008970

2012-008977

MISCELLANEOUS DOCUMENTS NUMBER TITLE

PEUS-WR-12-3-PART-1 CPNPP Post Fukishima Flooding Walkdown Report Attachment 2

REQUEST FOR INFORMATION

OCCUPATIONAL RADIATION SAFETY INSPECTION The following items are requested to support the occupational radiation safety inspection conducted during the week of October 15, 2012.

The areas of inspection are radiological hazard assessment and exposure controls (71124.01), occupational ALARA planning and controls (71124.02), and performance indicator verification (71151) for the occupational and public radiation safety cornerstones. Please provide the requested information on or before October 9, 2012.

Please submit this information using the same lettering system as below.

For example, all contacts and phone numbers for Inspection Procedure 71124.01 should be in - -

If information is placed in ims.certrec.com, please ensure the inspection exit date entered is at least 30 days later than the onsite inspection dates so the inspectors will have access to the information while writing the report. In addition to the corrective action document lists provided for each inspection procedure listed below, provide updated lists of corrective action documents at the entrance meeting.

The dates for these lists should range from the end dates of the original lists to the day of the entrance meeting. Since more than one inspection procedure is being conducted and if the information requests appear to be redundant, there is no need to provide duplicate copies.

Enter a note explaining in which file the information can be found. If you have any questions or comments, contact Louis C. Carson II at 817-200-1221 or Louis.Carson@nrc.gov.

Paul Elkmann will also be assisting on this inspection.

1. Radiological Hazard Assessment and Exposure Controls (71124.01) a. List of contacts and telephone numbers for the radiation protection organization staff and technicians b. Applicable organization charts c. Audits, self assessments, and license event reports written since October 2011, related to this inspection area d. Procedure indexes for the radiation protection procedures e. Specific procedures related to the following areas noted below.

Additional procedures may be requested by number after the inspectors review the procedure indexes.

Radiation protection program description

Radiation protection conduct of operations

Personnel dosimetry program

Posting of radiological areas

High radiation area controls

Radiological controlled area access controls and radworker Instructions

Conduct of radiological surveys

Radioactive source inventory and control

Declared pregnant worker program Attachment 2 f. List of corrective action documents (including corporate and subtiered systems) since October 2011.

Initiated by the radiation protection organization

Assigned to the radiation protection organization

NOTE:

The lists should indicate the significance level of each issue and the search criteria used.

Please provide s can perform word searches. If not covered above, a summary of corrective action documents since October 2011, involving unmonitored releases, unplanned releases, or releases in which any dose limit or administrative dose limit was exceeded for public radiation safety performance indicator verification in accordance with Inspection Procedure 71151. g. List of radiologically significant work activities scheduled to be conducted during the inspection period.

Since the inspection is scheduled during an outage, also include a list of work activities greater than 1 rem with the dose estimate for the work activity. h. List of active radiation work permits i. Radioactive source inventory list 2.

Occupational ALARA Planning and Controls (71124.02) a. List of contacts and telephone numbers for ALARA program personnel b. Applicable organization charts c. Copies of audits, self-assessments, and licensee event reports, written since October 2011, focusing on ALARA d. Procedure index for ALARA program e. Specific procedures related to the following areas noted below.

Additional procedures may be requested by number after the inspectors review the procedure indexes.

ALARA program

ALARA committee

Radiation work permit preparation f. A summary list of corrective action documents including corporate and subtiered systems written since October 2011, related to the ALARA program.

In addition to ALARA, the summary should also address radiation work permit violations, electronic dosimeter alarms, and radiation work permit dose estimates. NOTE:

The lists should indicate the significance level of each issue and the search g.

List of work activities greater than 1 rem, since October 2011.

Include original dose estimate and actual dose.

Attachment 2 h. Site dose totals and 3-year rolling averages for the past 3 years, based on dose of record i. Outline of source term reduction strategy j. The annual ALARA report for 2011 and the last post refueling outage report Attachment 3

REQUEST FOR INFORMATION

INSERVICE INSPECTION

The following items are requested to support the inservice inspection conducted October 8 through October 19, 2012.

The inspection procedure being used will be Inspection Procedure

In an effort to keep the requested information organized, please submit the information using the same request designation.

For example, the names and phone numbers for the program leads should be in a file/folder titled A.5.b. If you have any questions or comments, please contact the lead inspector Ronald Kopriva at (817) 200-1104 (Ron.Kopriva@nrc.gov ) or Christie Hale at (469)-831-0830 (Christie.Hale@nrc.gov).

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 Ronald Kopriva, by October 1, 2012, to facilitate the selection of specific items that will be reviewed during the onsite inspection week.

The inspectors 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 attachment).

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. .1 ISI/Welding Programs and Schedule Information a. A detailed schedule (including preliminary dates) of:

Nondestructive examinations planned for Class 1 & 2 systems and containment, performed as part of your ASME Section XI, risk informed (if applicable), and augmented inservice inspection programs during the upcoming outage.

Provide a status summary of the nondestructive examination inspection activities vs. the required inspection period percentages for this interval by category per ASME Section XI,

IWX-2400.

Do not provide separately if other documentation requested contains this information.

Reactor pressure vessel head examinations planned for the upcoming outage.

Examinations planned for Alloy 82/182/600 components that are not included in the Section XI scope (If applicable).

Examinations planned as part of your boric acid corrosion control program (Mode 3 walkdowns, bolted connection walkdowns, etc.).

Welding activities that are scheduled to be completed during the upcoming outage (ASME Class 1, 2, or 3 structures, systems, or components). b. A copy of ASME Section XI Code Relief Requests and associated NRC safety evaluations applicable to the examinations identified above.

Attachment 3 c. A list of nondestructive examination reports (ultrasonic, radiography, magnetic particle, dye penetrant, Visual

VT-1,

VT-2, and

VT-3), which have identified relevant conditions on Code Class 1 and 2 systems 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.

Also, include in the list the nondestructive examination reports with relevant conditions in the reactor pressure vessel head penetration nozzles that have been accepted for continued service.

The list of nondestructive examination reports should include a brief description of the structures, systems, or components where the relevant condition was identified. d. A list with a brief description (e.g., system, material, pipe size, weld number, and nondestructive examinations performed) of the welds in Code Class 1 and 2 systems which have been fabricated due to component repair/replacement activities since the beginning of the last refueling outage, or are planned to be fabricated this refueling outage. e. 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. f. Copy of any 10 CFR Part 21 reports applicable to your 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. g. A list of any temporary noncode repairs in service (e.g., pinhole leaks). h. Please provide copies of the most recent self-assessments for the inservice inspection, welding, and Alloy 600 programs. .2 Reactor Pressure Vessel Head (RPVH) a.

Provide the detailed scope of the planned nondestructive examinations of the reactor vessel head which identifies the types of nondestructive examination methods to be used on each specific part of the vessel head to fulfill commitments made in response to NRC Bulletin 2002-02 and NRC Order

EA-03-009.

Also, include examination scope expansion criteria and planned expansion sample sizes if relevant conditions are identified. (If applicable) b.

A list of the standards and/or requirements that will be used to evaluate indications identified during nondestructive examination of the reactor vessel head (e.g., the specific industry or procedural standards which will be used to evaluate potential leakage and/or flaw indications). .3 Boric Acid Corrosion Control Program a.

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. b. 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 Attachment 3 containment walkdown inspections performed as part of the boric acid corrosion control program. c. Please provide a copy of the most recent self-assessment performed for the boric acid corrosion control program. .4 Steam Generator Tube Inspections a. 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). b. Please provide a copy of your steam generator inservice inspection program and plan.

Please include a copy of the operational assessment from last outage and a copy of the following documents as they become available:

Degradation assessment

Condition monitoring assessment c. If you are planning on modifying your technical specifications such that they are consistent with Technical Specification Task Force Traveler

TSTF-Generator Tube Inregarding deviations from the standard technical specifications. d. Copy of steam generator history documentation given to vendors performing eddy current testing of the steam generators during the upcoming outage. e. Copy of steam generator eddy current data analyst guidelines and site validated eddy current technique specification sheets.

Additionally, please provide a copy of EPRI f. Identify and quantify any steam generator tube leakage experienced during the previous operating cycle.

Also provide documentation identifying which steam generator was leaking and corrective actions completed or planned for this condition (If applicable). g.

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.). h. Provide copies of your most recent self-assessments of the steam generator monitoring, loose parts monitoring, and secondary side water chemistry control programs. i. Indicate where the primary, secondary, and resolution analyses are scheduled to take place. j. Provide a summary of the scope of the steam generator tube examinations, including examination methods such as Bobbin, Rotating Pancake, or Plus Point, and the percentage of tubes to be examined.

Do not provide these documents separately if already included in other information requested.

Attachment 3 .5 Additional Information Related to all Inservice Inspection Activities a.

A list with a brief description of inservice inspection, boric acid corrosion control program, and steam generator tube inspection related issues (e.g., condition reports) entered into your corrective action program since the beginning of the last refueling outage (for Unit 2).

For example, a list based upon data base searches using key words related to piping or steam generator tube degradation, such as inservice inspection, ASME Code,Section XI, NDE, cracks, wear, thinning, leakage, rust, corrosion, boric acid, or errors in piping/steam generator tube examinations. b.

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 Provided Onsite to the Inspectors at the Entrance Meeting (October 8, 2012): .1 Inservice Inspection / Welding Programs and Schedule Information a. Updated schedules for inservice inspection/nondestructive examination activities, including steam generator tube inspections, planned welding activities, and schedule showing contingency repair plans, if available. b. For ASME Code Class 1 and 2 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 weld procedures used to fabricate the welds and copies of procedure qualification records supporting the weld procedures

Copies of mechanical test reports identified in the procedure qualification records above

Copies of the nonconformance reports for the selected welds (If applicable)

Attachment 3

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

Copies of welder performance qualifications records applicable to the selected welds, including documentation that welder maintained proficiency in the applicable welding processes specified in the weld procedures (at least 6 months prior to the date of subject work)

Copies of nondestructive examination personnel qualifications (Visual inspection, penetrant testing, ultrasonic testing, radiographic testing), as applicable c. For the inservice inspection related corrective action issues selected by the inspectors from section A of this enclosure, provide a copy of the corrective actions and supporting documentation. d. For the nondestructive examination reports with relevant conditions on Code Class 1 and 2 systems selected by the inspectors from Section A above, provide a copy of the examination records, examiner qualification records, and associated corrective action documents. e. A copy of (or ready access to) most current revision of the inservice inspection program manual and plan for the current Interval. f. For the nondestructive examinations selected by the inspectors 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 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. .2 Reactor Pressure Vessel Head a. Provide the nondestructive personnel qualification records for the examiners who will perform examinations of the reactor pressure vessel head. b. Provide drawings showing the following (if a visual examination is planned for the upcoming refueling outage).

The drawings listed above should include fabrication drawings for the nozzle attachment welds as applicable.

Reactor pressure vessel head and control rod drive mechanism nozzle configurations

Reactor pressure vessel head insulation configuration c. Copy of nondestructive examination reports from the last reactor pressure vessel head examination.

Attachment 3 d. Copy of evaluation or calculation demonstrating that the scope of the visual examination of the upper head will meet the 95 percent minimum coverage required by NRC Order

EA-03-009 (If a visual examination is planned for the upcoming refueling outage). e. Provide a copy of the procedures that will be used to identify the source of any boric acid deposits identified on the reactor pressure vessel head.

If no explicit procedures exist which govern this activity, provide a description of the process to be followed including personnel responsibilities and expectations. f.

Provide a copy of the updated calculation of effective degradation years for the reactor pressure vessel head susceptibility ranking. g.

Provide copy of the vendor qualification report(s) that demonstrates the detection capability of the nondestructive examination equipment used for the reactor pressure vessel head examinations.

Also, identify any changes in equipment configurations used for the reactor pressure vessel head examinations which differ from that used in the vendor qualification report(s). .3 Boric Acid Corrosion Control Program a. Please provide boric acid walkdown 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. b. 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. .4 Steam Generator Tube Inspections a. Copies of the examination technique specification sheets and associated justification for any revisions. b. Copy of the guidance to be followed if a loose part or foreign material is identified in the steam generators. c. 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.).

Also include documentation for the specific equipment to be used. d. Please provide copies of your responses to NRC and industry operating experience communications such as Generic Letters, Information Notices, etc. (as applicable to steam generator tube inspections).

Do not provide these documents separately if already included in other information requested such as the degradation assessment. e. List of corrective action documents generated by the vendor and/or site with respect to steam generator inspection activities.

Attachment 3 .5 Codes and Standards a. 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):

Applicable Editions of the ASME Code (Sections V, IX, and XI) for the inservice inspection program and the repair/replacement program

EPRI and industry standards referenced in the procedures used to perform the steam generator tube eddy current examination Attachment 4

REQUEST FOR INFORMATION

OCCUPATIONAL RADIATION SAFETY INSPECTION The following items are requested for the Occupational/Public Radiation Safety Inspection conducted the week of December 3, 2012.

Please provide the requested information on or before November 13, 2012.

Please submit this information using the same lettering system as below.

For example, all contacts and phone numbers for - -

If information is placed on ims.certrec.com, please ensure the inspection exit date entered is at least 30 days later than the onsite inspection dates, so the inspectors will have access to the information while writing the report.

In addition to the corrective action document lists provided for each inspection procedure listed below, please provide updated lists of corrective action documents at the entrance meeting.

The dates for these lists should range from the end dates of the original lists to the day of the entrance meeting.

If more than one inspection procedure is to be conducted and the information requests appear to be redundant, there is no need to provide duplicate copies.

Enter a note explaining in which file the information can be found.

If you have any questions or comments, please contact Larry Ricketson at (817) 200-1165 or Larry.Ricketson@nrc.gov.

1.

Radiation Monitoring Instrumentation (71124.05) a. List of contacts and telephone numbers for the following areas:

Effluent monitor calibration

Radiation protection instrument calibration

Installed instrument calibrations

Count room and Laboratory instrument calibrations b. Applicable organization charts c. Copies of audits, self-assessments, vendor or NUPIC audits for contractor support and licensee event reports, written since date of last inspection, related to:

Count room and Laboratory instrument calibrations

Area radiation monitors, continuous air monitors, criticality monitors, portable survey instruments, electronic dosimeters, teledosimetry, personnel contamination monitors, or whole body counters

Installed radiation monitors Attachment 4 d. Procedure index for:

Calibration, use and operation of continuous air monitors, criticality monitors, portable survey instruments, temporary area radiation monitors, electronic dosimeters, teledosimetry, personnel contamination monitors, and whole body counters.

Calibration of installed radiation monitors e. Please provide specific procedures related to the following areas noted below.

Additional Specific Procedures will be requested by number after the inspector reviews the procedure indexes.

Calibration of portable radiation detection instruments (for portable ion chambers)

Whole body counter calibration

Laboratory instrumentation quality control f. A summary list of corrective action documents (including corporate and subtiered systems) written since date of last inspection, related to the following programs:

Area radiation monitors, continuous air monitors, criticality monitors, portable survey instruments, electronic dosimeters, teledosimetry, personnel contamination monitors, whole body counters

Installed radiation monitors

Effluent radiation monitors

Count room radiation instruments

NOTE:

The lists should indicate the significance level of each issue and the search criteria used. g. Offsite dose calculation manual, technical requirements manual, or licensee controlled specifications which lists the effluent monitors and calibration requirements. h. i. Primary to secondary source calibration correlation for effluent monitors. j.

A list of the point of discharge effluent monitors with the two most recent calibration dates and the work order numbers associated with the calibrations.

2. Radioactive Gaseous and Liquid Effluent Treatment (71124.06) a. List of contacts and telephone numbers for the following areas:

Radiological effluent control

Engineered safety feature air cleaning systems Attachment 4 b. Applicable organization charts c. Audits, self assessments, vendor or NUPIC audits of contractor support, and licensee event reports written since date of last inspection, related to:

Radioactive effluents

Engineered Safety Feature Air cleaning systems d. Procedure indexes for the following areas:

Radioactive effluents

Engineered Safety Feature Air cleaning systems e. Please provide specific procedures related to the following areas noted below.

Additional Specific Procedures will be requested by number after the inspector reviews the procedure indexes.

Sampling of radioactive effluents

Sample analysis

Generating radioactive effluent release permits

Laboratory instrumentation quality control

In-place testing of HEPA filters and charcoal absorbers

New or applicable procedures for effluent programs (e.g., including ground water monitoring programs) f. List of corrective action documents (including corporate and subtiered systems) written since date of last inspection, associated with:

Radioactive effluents

Effluent radiation monitors

Engineered Safety Feature Air cleaning systems

NOTE: The lists should indicate the significance level of each issue and the search criteria used. g. 2010 and 2011 Annual Radioactive Effluent Release Report h. Current Copy of the Offsite Dose Calculation Manual i. Copy of the 2010 and 2011 interlaboratory comparison results for laboratory quality control performance of effluent sample analysis j. Effluent sampling schedule for the week of the inspection k. New entries into 10

CFR 50.75(g) files since date of last inspection Attachment 4 l. Operations department (or other responsible department) log records for effluent monitors removed from service or out of service m. Listing or log of liquid and gaseous release permits since date of last inspection n.

For technical specification-required air cleaning systems, the most recent surveillance test results of in-place filter testing (of HEPA filters and charcoal adsorbers) and l aboratory testing (of charcoal efficiency)

3. Radiological Environmental Monitoring Program (71124.07) a. List of contacts and telephone numbers for the following areas:

Radiological environmental monitoring

Meteorological monitoring b. Applicable organization charts c. Audits, self assessments, vendor or NUPIC audits of contractor support, and licensee event reports written since date of last inspection, related to:

Radiological environmental monitoring program (including contractor environmental laboratory audits, if used to perform environmental program functions)

Environmental TLD processing facility

Meteorological monitoring program d. Procedure index for the following areas:

Radiological environmental monitoring program

Meteorological monitoring program e. Please provide specific procedures related to the following areas noted below.

Additional Specific Procedures will be requested by number after the inspector reviews the procedure indexes.

Environmental Program Description

Sampling, collection and preparation of environmental samples

Sample analysis (if applicable)

Laboratory instrumentation quality control

Procedures

associated with the Offsite Dose Calculation Manual Attachment 4

Appropriate QA Audit and program QA manual (which pertain to the REMP) f. A summary list of corrective action documents (including corporate and subtiered systems) written since date of last inspection, related to the following programs:

Radiological environmental monitoring

Meteorological monitoring

NOTE:

The lists should indicate the significance level of each issue and the search criteria used. g. Wind Rose data and evaluations used for establishing environmental sampling locations h. Copies of the 2 most recent calibration packages for the meteorological tower instruments i. Copy of the 2010 and 2011 Annual Radiological Environmental Operating Report and

Land Use Census, and current revision of the Offsite Dose Calculation Manual j. Copy of the environmental laboratorys interlaboratory comparison program results for

2010 and 2011, if not included in the annual radiological environmental operating report k. Data from the environmental laboratory documenting the analytical detection sensitivities for the various environmental sample media (i.e., air, water, soil, vegetation, and milk) l. Quality Assurance audits (e.g., NUPIC) for contracted services m. Current NEI Groundwater Initiative Plan and status

4. Radioactive Solid Waste Processing, and Radioactive Material Handling, Storage, and Transportation (71124.08) a. List of contacts and telephone numbers for the following areas:

Solid Radioactive waste processing

Transportation of radioactive material/waste b. Applicable organization charts (and list of personnel involved in solid radwaste processing, transferring, and transportation of radioactive waste/materials) c. Copies of audits, department self-assessments, and licensee event reports written since date of last inspection related to:

Solid radioactive waste management

Radioactive material/waste transportation program d. Procedure index for the following areas:

Solid radioactive waste management Attachment 4

Radioactive material/waste transportation e. Please provide specific procedures related to the following areas noted below.

Additional specific procedures will be requested by number after the inspector reviews the procedure indexes.

Process control program

Solid and liquid radioactive waste processing

Radioactive material/waste shipping

Methodology used for waste concentration averaging, if applicable

Waste stream sampling and analysis f. A summary list of corrective action documents (including corporate and subtiered systems) written since date of last inspection related to:

Solid radioactive waste

Transportation of radioactive material/waste

NOTE: The lists should indicate the significance level of each issue and the search criteria used. g. Copies of training lesson plans for 49CFR172 subpart H, for radwaste processing, packaging, and shipping. h. A summary of radioactive material and radioactive waste shipments made from date of last inspection to present i. Waste stream sample analyses results and resulting scaling factors for 2010 and 2011 j. Waste classification reports if performed by vendors (such as for irradiated hardware) k. Although it is not necessary to compile the following information, the inspector will also review training, and qualifications records of personnel responsible for the conduct of radioactive waste processing, package preparation, and shipping