ML11308A018
| ML11308A018 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 11/01/2011 |
| From: | James Shea Tennessee Valley Authority |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| TAC MC1704, TAC MC1705, TAC MC1706 0-TI-565, Rev. 0003 | |
| Download: ML11308A018 (40) | |
Text
Tennessee Valley Authority, 1101 Market Street, Chattanooga, Tennessee 37402-2801 November 1,2011 10 CFR 50.90 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, D.C. 20555-0001 Browns Ferry Nuclear (BFN) Plant, Units 1, 2, and 3 Facility Operation License Nos. DPR-33, DPR-52, and DPR-68 NRC Docket Nos. 50-259, 50-260, and 50-296
Subject:
One-Time Inspection Procedure for BFN Units 1, 2 and 3
References:
- 1. NRC Letter to TVA, "Issuance of Renewed Facility Operating License Nos. DPR-33, DPR-52, And DPR-68 for Browns Ferry Nuclear Plant, Units 1, 2, and 3 (TAC NOS. MC1704, MC1705, and MC1706)", dated May 4, 2006
- 2. Letter from TVA to NRC, "Browns Ferry Nuclear (BFN) Units 1, 2 and 3 License Renewal Application (LRA) - Revised Commitment List (TAC NOS. MC1704, MC1705, and MC1706)",
dated April 21, 2006
- 3. NUREG-1843, "Safety Evaluation Report Related to the License Renewal of the Browns Ferry Nuclear Plant, Units 1, 2, and 3" April 2006 On May 4, 2006, the NRC issued Renewed Operating Licenses to the Tennessee Valley Authority (TVA) for BFN Units 1, 2, and 3 (Reference 1). As discussed in Reference 2 and reflected in Reference 3, TVA committed to develop a One-Time Inspection Procedure and provide this procedure to the NRC two years prior to the expiration of the current operating license.
In accordance with NUREG-1843, Browns Ferry One-Time Inspection Procedure (0-TI-565, Revision 3) is provided in the enclosure.
Printed on recycled paper
U. S. Nuclear Regulatory Commission Page 2 November 1,2011 There are no regulatory commitments associated with this letter. Please address any questions regarding this matter to Tom Hess at 423-751-3487.
Respectfully, 7J.
. Shea
Enclosure:
Browns Ferry One-Time Inspection Procedure (0-TI-565, Revision 3) cc (Enclosure):
NRC Regional Administrator - Region II NRC Senior Resident Inspector - Browns Ferry Nuclear Plant Alabama State Department of Public Health
U. S. Nuclear Regulatory Commission Page 3 November 1, 2011 bcc (Enclosure):
NRC Project Manager - Browns Ferry Nuclear Plant NRC Branch Chief - Region II G. P. Arent S. M. Douglas J. E. Emens C. J. Gannon D.G. Green T. A. Hess D. E. Jernigan L. A. Jones K. J. Poison H. R. Rogers P. D. Swafford E. J. Vigluicci EDMS
ENCLOSURE 1 One-Time Inspection Procedure for BFN Units 1, 2, and 3 Browns Ferry One-Time Inspection Procedure (0-TI-565, Revision 3)
Browns Ferry Nuclear Plant Unit 0 Technical Instruction 0-TI-565 One-Time Inspection Procedure Revision 0003 Quality Related Level of Use: Reference Use Effective Date:
09-15-2011 Responsible Organization:
DEM, Design Eng Mech/Nuclear Prepared By:
Kathy L. Creamer, 256-614-6438 Approved By:
Kevin L. Groom
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 2 of 36 Current Revision Description Pages Affected:
Type of Change:
Documentation:
5,6,22 Revision Tracking Number:
004 PER 412108 Revised note to RWI of Appendix A for System 090 traps.
Added three definitions to 3.0.
Table of Contents 1.0 INTRO DUCTIO N......................................................................................................
4 1.1 Purpose........................................................................................................................
4 1.2 Scope............................................................................................................................
4
2.0 REFERENCES
4 3.0 DEFINITIO NS...............................................................................................................
5 4.0 G ENERA L PRECA UTIO NS......................................................................................
7 5.0 PREREQ UISITES..................................................................................................
8 6.0 EQ UIPM ENT................................................................................................................
8 7.0 PRO CEDURE...............................................................................................................
8 7.1 Responsibilities.............................................................................................................
8 7.2 Scope Determ ination..............................................................................................
10 7.3 Select Inspection Locations....................................................................................
10 7.4 Define the Inspection..............................................................................................
12 7.5 Conduct O ne-Tim e Inspections...............................................................................
12 7.6 Docum entation............................................................................................................
13 7.7 Evaluation...................................................................................................................
13 7.8 Corrective Actions.......................................................................................................
14 7.9 Report of the Inspection Results..............................................................................
14 8.0 ACCEPTANCE CRITERIA......................................................................................
14 Appendix A :
Inspection G roups................................................................................
16 A ppendix B:
Inspection M ethods..............................................................................
25 Appendix C:
Aging Effect Appearance and Characteristics...................................
31 Attachm ent 1: Inspection Data Sheet.........................................................................
34 : One-Time Inspection - Information/Results........................................
35 : Typical Tennessee Valley Authority Record of Visual Exam ination...........................................................................................
36
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 4 of 36
1.0 INTRODUCTION
1.1 Purpose A.
This procedure describes the One-Time Inspection (OTI) Program at Browns Ferry Nuclear Plant (BFN) to satisfy the requirements in Appendix 0, Section 1.26, of the FSAR.
B.
This procedure includes scoping, inspection point selection, inspection performance, documentation and evaluation of the inspection results and disposition of inspection anomalies.
1.2 Scope A.
The OTI Program applies to systems and components subject to aging management using the aging management programs for Water Chemistry, Fuel Oil Chemistry and Lubricating Oil Analysis and for which no aging effects have been observed or for which the aging effect is occurring very slowly and does not affect the component's or structure's intended function during the period of extended operation (PEO) based on prior operating experience data.
B.
The OTI Program may also include other components and materials where the environment in the period of extended operation is expected to be equivalent to that in the prior 40 years and for which no aging effects have been observed.
2.0 REFERENCES
A.
EPRI Report 1007933, "Aging Assessment Field Guide," December 2003 B.
EPRI Report 1010639, "Non-Class I Mechanical Implementation Guideline and Mechanical Tools, Revision 4," January 2006 C. NUREG-1801, Vol. 1, Rev. 0, 'Generic Aging Lessons Learned (GALL)
Report - Summary," U.S. Nuclear Regulatory Commission, published April 2001 D.
NUREG-1 801, Vol. 2, Rev. 0, "Generic Aging Lessons Learned (GALL)
Report - Tabulation of Results," U.S. Nuclear Regulatory Commission, published April 2001 E.
EPRI Report 107514, "Age-Related Degradation Inspection (ARDI)"
F.
FSAR Appendix 0, Section 0.1.26, One-Time Inspection G.
10 CFR Part 54, Requirements for Renewal of Licenses for Nuclear Power Plants H. NPG-SPP-03.1, Corrective Action Program
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 5 of 36
2.0 REFERENCES
(continued)
I.
NPG-SPP-07.0, Work Management J.
NPG-SPP-02.3, Operating Experience Program K. TVA-NQA-PLN89-A, TVA Nuclear Quality Assurance Plan L.
N-VT-1, Visual Examination Procedure for ASME Section Xl Preservice and Inservice M. N-VT-14, Visual Examination to Detect Erosion/Corrosion Damage N.
IEP-200, "Qualification and Certification Requirements for TVA Nuclear Power Group (NPG) NDE Personnel"
- 0. MCI-0-000-PRPOO2, Surface Preparation for NDE (Nondestructive Examination)
P.
N-UT-26, Ultrasonic Examination for the Detection of ID Pitting, Erosion, and Corrosion Q.
PER 333334, License Renewal OE Regarding Remote Visual Examinations R.
PER 333336, License Renewal OE Regarding UT Measurements of the Drywell Liner 3.0 DEFINITIONS A.
Air/Gas - Air/Gas environments include: air environments containing significant moisture such that condensation or water pooling may occur, atmospheric air (when internal to components), Carbon Dioxide, compressed air, exhaust gas from diesel generators, Freon, and Nitrogen.
B.
Aging Effect - Aging effects are the results of various aging mechanisms which result in surface anomalies such as change in material properties/reduction in fracture toughness, cracking, elastomer degradation, fouling product buildup, and loss of material.
C.
Aging Mechanism - Aging mechanism is a specific process that changes the characteristic of a material/component, with time or use, causing an aging effect.
D.
AMP - Aging Management Program E.
CASS - Cast Austenitic Stainless Steel F.
FSAR - Final Safety Analysis Report
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 6 of 36 3.0 DEFINITIONS (continued)
G.
LR - License Renewal H.
LRA - License Renewal Application I.
MIC - Microbiologically Influenced Corrosion J.
MT - Magnetic Particle Testing K.
NDE - Non-Destructive Examination L.
PEO - Period of Extended Operation M. PER - Problem Evaluation Report N.
PT - Dye Penetrant Testing
- 0.
PV - Performance Verification P.
Raw or Potable Water - Raw water is not demineralized or chemically controlled to any significant extent. Raw water includes water that enters the plant from the Wheeler Reservoir (Tennessee River) in which the water is rough filtered to remove large particles and biocides may be added to prevent fouling, water that enters the plant from the potable water system in which biocides may be added to make the water suitable for human consumption, and water that may be contaminated by impurities such as condensation and water in drainage and waste collection systems. Water beyond the chemical control boundaries of treated water systems. Examples include water in piping between double isolation valves; beyond isolation valves, vent valves, or drain valves; and transferred to sampling systems.
Q.
RE - Responsible Engineer R.
RP - Radiation Protection S.
RT - Radiographic Testing T.
SCC - Stress Corrosion Cracking U.
SER - Safety Evaluation Report V.
Treated Water - Treated water is the base water for all clean systems. Treated water is demineralized water or chemically purified water. Treated water may have been injected with treatment chemicals in accordance with applicable chemistry control programs.
W.
UNID - Unique Identifier X.
UT - Ultrasonic Testing
3.0 DEFINITIONS (continued)
Y.
VT - Visual Inspection Testing Z.
WO - Work Order 4.0 GENERAL PRECAUTIONS A.
For OTI inspection point selection, review the available WO history or other plant records to provide reasonable assurance that components selected for inspection are representative of long-term exposure to the relevant conditions for aging. Components should not have been replaced within the 20 years prior to the PEO.
B.
Use caution when using draft License Renewal (LR) boundary drawings.
Selection of OTI points should be validated against the most current revision of the appropriate drawing(s).
C.
Electrical, instrument, and mechanical craft work required to support the inspection program shall be requested and scheduled utilizing the WO process.
D.
During inspections, should any personnel recognize a safety hazard, equipment malfunction, or other condition adverse to quality, they shall notify their supervisor/manager and document the condition in accordance with NPG-SPP-03.1, Corrective Action Program.
E.
Inspection personnel shall comply with all applicable plant procedures and requirements such as safety, radiological controls, hold order tags, caution signs, etc., that are posted on plant equipment.
F.
Inspection activities shall be coordinated using the Work Management Process in accordance with NPG-SPP-07.0, Work Management.
G.
Inspection activities should be coordinated through the Unit Work Control supervisor, e.g., processing hold orders and craft, Operations, or RP support required for inspection activities.
H.
Electrical, instrument, and mechanical craft activities shall be limited to work as identified in the approved work instruction. At no time will any work outside the scope of the authorized WO be permitted.
- 1.
Inspection personnel shall exercise extreme caution when working around rotating, moving, or energized equipment. If equipment is NOT operating, personnel should be aware of the possibility of equipment automatically starting.
J.
Inspection personnel should verify the material of the inspection location specified in the WO.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 8 of 36 5.0 PREREQUISITES A.
The qualifications of the inspectors and the types of inspections required shall be identified.
B.
Personnel involved with the field implementation of this procedure shall use NDE techniques and be qualified to perform VT inspections as specified in IEP-200, "Qualification and Certification Requirements for TVA Nuclear Power Group (NPG) NDE Personnel".
C.
Before the inspection, involved team members shall be given a pre-job briefing in accordance with Browns Ferry pre-job brief expectations and the supervisor responsible for the inspection activity will ensure inspection team members are qualified to perform the inspection task.
D.
For inspections in radiologically controlled areas, an As-Low-As-Reasonably-Achievable (ALARA) pre-plan may be necessary. The planner or job supervisor shall provide RP with the necessary information (e.g., RWP man-hours, high radiation area man-hours, etc.) during job walk down and WO review to determine if an ALARA pre-plan is required.
E.
Coordination with scheduled maintenance and outage activities is highly recommended for ease of access to components located in plant areas NOT normally accessible during normal plant operation.
6.0 EQUIPMENT Tools required for the inspections will be specified by the details in the WO.
7.0 PROCEDURE 7.1 Responsibilities 7.1.1 Director of Engineering A.
Responsible for establishing expectations for the support of and implementation of the OTI Program.
B.
Ensures individuals are assigned to programs and tasks in support of the OTI Program.
C.
Ensures training is developed and executed in support of the OTI Program and monitors training performance.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 9 of 36 7.1.2 Mechanical Design Manager A.
Provides oversight of the OTI Program.
B.
Assigns individuals and ensures resources are sufficient to successfully implement the OTI Program.
C. Ensure personnel assigned tasks possess the required training and qualifications by validating required qualifications and training periodically in the qualification database before assigning tasks.
D.
Evaluate nuclear industry experience information in accordance with NPG-SPP-02.3, Operating Experience Program, and recommend changes in system design or operation, when appropriate.
7.1.3 OTI Program Owner A.
Maintain a copy of OTI Program Inspection records.
B.
Provide oversight and technical direction of inspection and sampling activities.
C.
Provide review and disposition of anomalies.
D.
Ensure timely reporting of adverse conditions in accordance with NPG-SPP-03.1, Corrective Action Program.
E.
Maintain records of all OTI inspections on the OTI Program Inspection plan, similar to Attachment 2.
7.1.4 Inspection Personnel A.
Perform and document inspection results using Attachment I or an approved equivalent.
B.
Confirm material for inspection location.
C. Document actual inspection location and component type including component ID if applicable.
D.
Provide the inspection data to the Program Owner.
E.
Identify the need for additional engineering review of field anomalies.
F.
Ensure timely reporting of adverse conditions in accordance with NPG-SPP-03.1, Corrective Action Program.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 10 of 36 7.2 Scope Determination A.
The Program Owner (or designee) shall establish the total population of components and the aging effects for which the OTI Program is being credited from the BFN License Renewal Application (LRA), NRC Requests for Additional Information (RAIs) and the final Safety Evaluation Report (SER).
B.
The Program Owner (or designee) shall organize all materials of construction and environments combinations into inspection groups such that those unique material and environmental combination groups become the total population size for that inspection group. Refer to Appendix A.
C.
The sample size for each inspection group is determined based on 20 percent of the total sample population, with a maximum of 25 inspection locations for a group. Refer to Appendix A.
7.3 Select Inspection Locations A.
Using Appendix A for each inspection group, the Program Owner (or designee) shall review the associated system LR boundary drawings and select potential inspection points using the criteria for aging effects susceptibility.
- 1.
Cracking (SCC and/or Cyclic Loading)
- 2.
Elastomer Degradation (Oxidation and/or Thermal Exposure)
- 3.
Fouling
- 4.
Loss of Material
- a.
Crevice Corrosion
- b.
Galvanic Corrosion
- c.
General Corrosion
- d.
- e.
Pitting Corrosion
- 5.
Reduction in Fracture Toughness (CASS)
B.
The Program Owner (or designee) shall build an Inspection Plan (similar to ) using the potential locations identified for each system and the required sample size from Appendix A.
C.
The Program Owner (or designee) shall select a representative sample of components from each inspection group identified in Appendix A and the following considerations:
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 11 of 36 7.3 Select Inspection Locations (continued)
- 1.
Review on-line maintenance activities
- 2.
Review work planned for refueling outages
- 3.
Select inspections if no other opportunities exist
- 4.
Spread the inspections between all three units with no less than 15 percent of the inspections on a single unit.
- 5.
Accessibility, radiological concerns, and other outage activities
- 6.
Propose maintenance and outage work orders so as to inspect components that are removed (as much as practical), in order to minimize the impact of the inspection on in-line components (and thereby, plant operations).
- 7.
Review the available WO history or other plant records to provide reasonable assurance that components selected for inspection are representative of long-term exposure to the relevant conditions for aging.
Components should not have been replaced within the 20 years prior to the PEO.
D.
The Program Owner (or designee) shall build the Inspection Plan over the period prior to PEO until all inspections are complete.
E.
The Program Owner (or designee) should choose inspection locations that are most susceptible to age-related degradation, based on review of plant procedures, drawings (e.g., flow diagrams) and plant/industry operating experience, for components in the sample population include:
- 1.
Stagnant or low-flow locations are the most susceptible to degradation, with respect to cracking and loss of material, and typically occur in components such as:
- a.
Portions of systems that are in layup/standby during normal plant operations.
- b.
Dead end piping/tubing runs (e.g., normally isolated drain or vent lines/valves).
- c.
Low points, such as drain lines/valves or drain traps.
- 2.
Only locations where there is contact between dissimilar metals (e.g.,
carbon/alloy steel and copper alloy or stainless steel) are susceptible to a loss of material due to galvanic corrosion.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 12 of 36 7.3 Select Inspection Locations (continued)
- 3.
Heat exchanger tubes, cooling coils, and fins are susceptible to fouling (reduction of heat transfer) due to buildup of scale or other deposits.
- 4.
Locations with elevated temperatures (typically above 140 0F), such as upstream of a heat sink (heat exchanger) or downstream of a heat source, are the most susceptible to cracking of stainless steel due to stress corrosion cracking (SCC).
7.4 Define the Inspection A.
The Program Owner (or designee) shall initiate a WO for the inspection point.
B.
The appropriate inspection method should be determined using Appendix B, including specific acceptance criteria (if any) for each location. Consider the following:
- 1.
Cost, availability of personnel, accessibility of the component, expected condition/aging mechanism, etc.
- 2.
Visual inspections (preferred) that identify degraded conditions may be supplemented by volumetric techniques, which can further quantify the extent of the aging effect.
C.
The Program Owner (or designee) shall document each identified inspection location in the inspection plan along with the component number, method of inspection, basis for selection, and any specific acceptance criteria. The plan shall be verified early enough in outage preparations that scope changes can be adequately planned. Refer to Attachment 2 for an example inspection plan.
The format may be adjusted at the discretion of the Program Owner.
- 1.
Inspections may occur over the course of several outages and/or with the plant in normal operation.
- 2.
The inspection plan should take advantage of opportunities for visual inspection (such as when opened for maintenance, repair or modification) as much as possible.
7.5 Conduct One-Time Inspections A.
The inspection WO will be scheduled through Outage Management or Daily Scheduling as appropriate.
B.
The one-time inspections shall be performed by qualified personnel (the inspector), following procedures that are consistent with Section XI of the ASME B&PV Code and with 10 CFR 50, Appendix B, and using a variety of the non-destructive examination (NDE) techniques as described in Appendix B.
7.5 Conduct One-Time Inspections (continued)
C.
The inspector shall perform and document the inspection in accordance with the WO.
D.
The inspector shall include the inspection results in the WO and submit a copy to the Program Owner.
E.
The Program Owner shall ensure that inspections not meeting the acceptance criteria are entered into the Corrective Action Program.
7.6 Documentation A.
Inspection findings will be documented on Attachment 1, Inspection Data Sheet(s), or an approved equivalent.
B.
All completed inspection records will be reviewed by the Program Owner and documented on the inspection plan.
C.
The Program Owner shall review and disposition each unacceptable finding submitted on the Inspection Data Sheet.
D.
Completed data packages will be sent to Records Management as part of the WO package.
7.7 Evaluation A.
The Program Owner (or designee) shall perform an initial review of one-time inspection data from inspected components, as it is received.
- 1.
Ensure that the data is for the correct component and that documentation is complete (e.g., contains adequate description of findings). Any inspection data that is incomplete or inaccurate shall be re verified by the inspector.
- 2.
Perform the initial review as soon as possible after receipt of the inspection results (prompt review may ensure that the component is still accessible for verification, if needed).
- 3.
All visual indications of surface anomalies shall be documented in a PER and are subject to evaluation by the Program Owner.
B.
The Program Owner (or designee) shall compile and review all inspection data for each material/environment combination to:
- 1.
Determine if any identified degradation is related to normal aging of the component or to other considerations.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 14 of 36 7.7 Evaluation (continued)
- 2.
If degradation is related to the normal aging of the component, then subsequent evaluation is appropriate to evaluate the rate of aging and if the aging rate requires either additional monitoring or other actions within the PEO.
- 3.
If degradation/condition is NOT related to normal aging (e.g., is due to a design issue, such as cavitation, or to a unique event), then evaluate the condition and determine the appropriate action to either monitor or correct the condition.
7.8 Corrective Actions A.
The engineering evaluation of inspection results, performed in accordance with NPG-SPP-03.1, Corrective Action Program, to ensure that the intended functions of the components within the scope of this procedure can be maintained consistent with the current licensing basis.
B.
If the engineering evaluation concludes that age-related degradation is occurring and could result in loss of component function during the period of extended operation, the unacceptable condition is documented in the corrective action program. "Aging management" should be included in the Service Request description to ensure proper trending of aging management issues.
Required corrective actions may include further analytical evaluation, repair, component replacement, or establishing a program to periodically monitor and trend the identified degradation.
C.
If no degradation is detected or engineering evaluation concludes that component intended function would NOT be lost during the period of extended operation, no further inspections or periodic activities are needed.
7.9 Report of the Inspection Results A.
The Program Owner (or designee) shall assemble all Data Sheets and Problem Evaluation Reports for each material/environment combination described in Appendix A for each operating unit.
B.
The Program Owner (or designee) shall prepare a One-Time Inspection report to document the related activities and conclusions.
C.
The Program Owner (or designee) shall submit the completed package to Records Management (RM).
8.0 ACCEPTANCE CRITERIA A.
Any indication of degradation.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 15 of 36 8.0 ACCEPTANCE CRITERIA (continued)
B.
Any evidence of localized corrosion such as crevice, pitting, or galvanic (at dissimilar metal interfaces) corrosion, or of cracking (due to SCC or cyclic loading).
C.
Any evidence of general (uniform) corrosion.
D.
Any evidence of the relevant conditions for MIC (e.g., presence of sulfate-reducing bacteria).
E.
Any evidence of a fouling layer on the tubes of heat exchangers/coolers, or loss/reduction of the heat transfer capability.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 16 of 36 Appendix A (Page 1 of 9)
Inspection Groups Date Number of Estimated Total Required Population Inspections Aging Effects Requiring Inspection Group Environment Material Affected Systems (3 Units)
(3 Units)
Management 012 031 AG1 Air/Gas Non-ferrous 053
>125 25 Cracking, Fouling, Loss of Material 064 067 001 033 071 002 037 073 003 040 074 010 043 075 012 053 076 023 063 077 AG2 Air/Gas Steel 024 064 078
>125 25 Cracking, Loss of Material 025 065 082 026 066 084 027 067 085 029 068 086 030 069 090 031 070 RV
Appendix A (Page 2 of 9)
Number of Estimated Total Required Population Inspections Aging Effects Requiring Inspection Group Environment Material Affected Systems (3 Units)
(3 Units)
Management AG3 Air/Gas Elastomer 082 88 18 Degradation due to 086 Thermal Exposure 003 012 Cracking (003 only),
Fouling (031 and 084 AG4 Air/Gas Stainless Steel 031
>125 25 only), Loss of Material, Reduction in Fracture 072 Toughness (003 only) 084 FO1 Fuel Oil Non-ferrous 018
>125 25 Loss of Material (MIC only)
F02 Fuel Oil Steel 018
>125 25 Loss of Material F03 Fuel Oil Elastomer 018 16 4
Degradation due to Oxidation F04 Fuel Oil Stainless Steel 018 16 Loss of Material (MIC only) 077 LO1 Lubricating Oil Steel 41 9
Loss of Material 082 077 L02 Lubricating Oil Copper Alloy 082 33 7
Loss of Material
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 18 of 36 Appendix A (Page 3 of 9)
Number of Estimated Total Required Population Inspections Aging Effects Requiring Inspection Group Environment Material Affected Systems (3 Units)
(3 Units)
Management 029 Cracking (090 only),
RW1 Raw Water Non-ferrous 031
>125 25 Fouling (031 only), Loss of Material 090 027 029 RW2 Raw Water Steel 031
>125 25 Loss of Material 050 077 029 031 RW3 Raw Water Stainless Steel 050
>125 25 Fouling (031 only), Loss of Material 068 077 002 044 074 012 063 075 023 068 077 Cracking, Fouling (071 TW1 Treated Water Non-ferrous
>125 25 and 073 only), Loss of 026 069 078 Material 037 071 085 043 073
Appendix A (Page 4 of 9)
Number of Estimated Total Required Population Inspections Aging Effects Requiring Inspection Group Environment Material Affected Systems (3 Units)
(3 Units)
Management 001 069 002 037 071 003 043 073 006 044 074 TW2 Treated Water Steel
>125 25 Cracking, Loss of Material 008 063 075 010 064 077 012 066 078 023 068 085 001 064 074 002 068 075 003 069 077 TW3 Treated Water Stainless Steel 010 071 078
>125 25 Cracking, Fouling (074 only), Loss of Material 023 072 085 043 073 092 063 See note below for See note below for Submerged Treated Water Steel, Stainless Steel N/A Submerged.
Submerged.
Loss of Material
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 20 of 36 Appendix A (Page 5 of 9)
Note 1: Number of inspections required is 20% of the total population but not greater than 25.
AG1 - Within scope there are 15 coolers in System 064, 52 in System 031, and 3 in System 067. Non-ferrous alloys include aluminum and copper alloys. Each of the coolers has copper alloy cooling coils and aluminum alloy fins that are exposed to the air/gas environment. There are also 2 copper alloy traps in System 053 and 1 copper alloy valve in System 012.
Therefore, the total population for AG1 is greater than 125.
Crack initiation/growth due to stress corrosion cracking (SCC) was identified as an aging effect requiring management in the air/gas environment only in System 031, and only for the aluminum alloy fins.
Loss of material includes the following mechanisms: crevice, pitting, and galvanic corrosion. Galvanic corrosion was identified as an aging effect requiring management in the air/gas environment only in System 012, and only for the joints between a bronze isolation valve for flow element FE-1 2-77 and the stainless steel instrumentation piping.
AG2 - Within scope, steel (carbon and low-alloy steel, cast iron and cast iron alloys) exposed to the air/gas environment is a common material/environment combination in 39 systems, including the Reactor Vessel. Therefore, a total population of greater than 125 is a reasonable estimate for AG2.
Loss of material includes the following mechanisms: crevice, galvanic (dissimilar metal contact), general, and pitting corrosion.
AG3 - The only elastomers within scope that are exposed to the air/gas environment are flexible connectors/hoses in the diesel systems, System 082 and System 086. A review of System Reports and boundary drawings reveals that there are 6 for each of 4 diesels on Unit 0 System 082, and 12 for each of 4 diesels on Unit 3 System 082. There are 2 for each of 4 diesels on Unit 0 System 086, and 2 for each of 4 diesels on Unit 3 System 086. Therefore, the total population for AG3 is 88.
Appendix A (Page 6 of 9)
AG4 - Within scope, stainless steel exposed to the air/gas environment is a common material/environment combination in 5 systems. Stainless steel includes nickel alloys. Therefore, a total population of greater than 125 is a reasonable estimate for AG4.
Crack initiation/growth due to cyclic loading and SCC were identified as aging effects requiring management for stainless steel in the air/gas environment of only one system, System 003 (cyclic loading is only for components that are within the reactor coolant pressure boundary (RCPB).
Fouling product buildup due to particulate was identified as an aging effect requiring management only for stainless steel heat exchanger tubes in the air/gas environment of 2 systems, System 031 and System 084. A review of the System Reports and boundary drawings reveals that there are 6 such heat exchangers per Unit in System 031, and a total of 2 for System 084.
Loss of material includes the following mechanisms: crevice and pitting corrosion.
FO1 and F02 - There is only one system within the scope of the One-Time Inspection Program with a fuel oil environment, i.e., System 018. Common component types such as fittings, piping, tubing, and valves, have been identified as non-ferrous metal alloys (aluminum alloys and copper alloys), and steel (carbon steel and cast iron). With hundreds of such components within the scope of the One-Time Inspection Program, a total population of greater than 125 is a reasonable estimate for each of these inspection groups.
Loss of material includes the following mechanism for all components: microbiologically influenced corrosion (MIC). For tanks, loss of material also includes crevice, general and pitting corrosion.
F03 - There is only one system within scope with a fuel oil environment, i.e., System 018, and the only elastomer components are flexible hoses. A review of the System Report and boundary drawings reveals that there are 2 for each of 4 diesels on Unit 0 System 018, and 2 for each of 4 diesels on Unit 3 System 018. Therefore, the total population for F03 is 16.
Appendix A (Page 7 of 9)
F04 - There is only one system within scope with a fuel oil environment, i.e., System 018, and the only stainless steel components are associated with 4 pressure indicators, one each on the suction and discharge sides of the two fuel oil transfer pumps. Components include piping, tubing and valves. Therefore, the total population for F04 is estimated at 20.
Loss of material includes the following mechanisms: MIC.
LOI - There are only two systems within scope with a lubricating oil environment, i.e., System 077 and System 082. For System 077, a review of the System Report and boundary drawings reveals that only 3 piping segments, 2 valves, and associated fittings (estimated as 4 times the number of piping segments and valves, for a total of 20 fittings) are identified. For System 082, only strainers (2 for each of 8 diesels, for a total of 16) are identified. Therefore, the total population for L02 is 41.
Loss of material includes the following mechanisms: crevice and pitting corrosion.
L02 - There are only two systems within scope with a lubricating oil environment, i.e., System 077 and System 082. For System 077, a review of the System Report and the boundary drawings reveals that only one component is identified, i.e.,
valve 0-77-1352. For System 082, only tubing and valves (2 of each for each of 8 diesels, for a total of 32) are identified.
Therefore, the total population for L02 is 33.
Loss of material includes the following mechanisms: crevice, galvanic (dissimilar metal contact), general, and pitting corrosion.
RWl - The System 031 copper alloy cooling coils that are identified in group AG1 have raw water as the internal environment of the tubes. In addition, there are copper alloy tubing, valves, and associated fittings in the raw water supply and return lines for these cooling coils; and numerous copper alloy valves and fittings in System 029, which supplies cooling water to some of these cooling coils. There are also aluminum traps in System 090 exposed to raw water. Therefore, a total population of greater than 125 is a reasonable estimate for RWl.
Crack initiation/growth due to SCC was identified as an aging effect requiring management in the raw water environment only for the aluminum traps in System 090.
Appendix A (Page 8 of 9)
Fouling product buildup due to particulate was identified as an aging effect requiring management only for copper alloy heat exchanger tubes (cooling coils) in the raw water environment of System 031. As described in AG1 above, there are 52 such cooling coils.
Loss of material includes the following mechanisms: crevice, galvanic, and pitting corrosion.
RW2 - Within scope, steel exposed to the raw water environment is a common material/environment combination in 4 systems.
Therefore, a total population of greater than 125 is a reasonable estimate for RW2.
Loss of material includes the following mechanisms for all components: crevice, galvanic, general, and pitting corrosion. For System 050 and System 077, loss of material also includes biofouling and MIC.
RW3 - Within scope, stainless steel exposed to the raw water environment is a common material/environment combination in 4 systems. Therefore, a total population of greater than 125 is a reasonable estimate for RW3.
Fouling product buildup due to particulate was identified as an aging effect requiring management only for stainless steel heat exchanger tubes in the raw water environment of System 031. A review of the System Report and boundary drawings reveals that there are 6 such heat exchangers per Unit in System 031.
Loss of material includes the following mechanisms for all components: crevice and pitting corrosion. For System 050 and System 077, loss of material also includes biofouling and MIC.
TWl - Within scope, non-ferrous metal alloys exposed to the treated water environment is a common material/environment combination in 17 systems. Therefore, a total population of greater than 125 is a reasonable estimate for TWI.
Fouling product buildup due to particulate was identified as an aging effect requiring management only for copper alloy heat exchanger tubes in the treated water environment of 2 systems. A review of the System Reports and boundary drawings reveals that there is one such heat exchanger per system per unit. Therefore, the total population for TWI b is 6.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 24 of 36 Appendix A (Page 9 of 9)
Loss of material includes the following mechanisms: crevice, galvanic, and pitting corrosion.
TW2 - Within scope, steel exposed to the treated water environment is a common material/environment combination in 23 systems. Therefore, a total population of greater than 125 is a reasonable estimate for TW2.
Loss of material includes the following mechanisms: crevice, galvanic, general, and pitting corrosion.
TW3 - Within scope, stainless steel exposed to the treated water environment is a common material/environment combination in 19 systems. Therefore, a total population of greater than 125 is a reasonable estimate for TW3.
Fouling was identified as an aging effect requiring management for stainless steel components exposed to treated water in only one system, System 074. A review of the System Report and boundary drawings reveals that, for each Unit, there are 4 RHR heat exchangers and 4 RHR pump seal water heat exchangers with stainless steel tubes in System 074.
Loss of material includes the following mechanisms: crevice and pitting corrosion.
Submerged - This inspection group consists of the ASME equivalent Class MC supports submerged in the torus (pressure suppression chamber), which are evaluated as exposed to a treated water environment. The population is the accessible portions of 16 ring girder supports and 48 down comer tie bar supports. The number of required inspections is 25% of the population, or 4 ring girders and 12 down comer tie bar supports on Unit 2 and 4 ring girders and 12 down comer tie bar supports on Unit 3.
Loss of material includes the following mechanisms: crevice, general, and pitting corrosion.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 25 of 36 Appendix B (Page 1 of 6)
Inspection Methods Examples of Parameters Monitored or Inspected And Aging Effect for Specific Structure or Component1 Aging Aging Parameter Inspection Effect Mechanism Monitored Method 2 Loss of Crevice Corrosion Wall Thickness Visual (VT-1 or equivalent) and/or Material Volumetric (RT or UT)
Loss of Galvanic Corrosion Wall Thickness Visual (VT-3 or equivalent) and/or Material Volumetric (RT or UT)
Loss of General Corrosion Wall Thickness Visual (VT-3 or equivalent) and/or Material Volumetric (RT or UT)
Loss of MIC Wall Thickness Visual (VT-3 or equivalent) and/or Material Volumetric (RT or UT)
Loss of Pitting Corrosion Wall Thickness Visual (VT-1 or equivalent) and/or Material Volumetric (RT or UT)
Loss of Heat Fouling Buildup /
Tube/Fin Fouling Visual (VT-3 or equivalent) or Transfer Particulate Enhanced VT-1 for CASS Cracking SCC or Cyclic Cracks Enhanced Visual (VT-1 or equivalent) and/or Loading Volumetric (RT or UT)
NUREG-1 801 XI.M32 One-Time Inspection 2
Visual inspection may be used only when the inspection methodology examines the surface potentially experiencing the aging effect.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 26 of 36 Appendix B (Page 2 of 6) 1.0 VISUAL INSPECTION (VT)
A.
Most one-time inspections will be conducted using visual examination techniques. This section provides specific information for visual examinations and incorporates the applicable sections of TVA procedure N-VT-1 to provide guidance for the inspectors.
B.
Personnel performing visual examinations shall be certified in accordance with IEP-200 [Reference N], or a written practice approved by TVA. Level-I personnel may perform examinations only under the guidance of a Level-II or Level-Ill individual.
C.
General Requirements:
- 1.
Illumination and resolution requirements shall be considered adequate based on the following table for procedure qualification and demonstration:
Table CA1 Visual Minimum Maximum Direct Maximum Resolvable Lower Examination Illumination Exam Distance, Feet Case Character Height VT-1 50 fc 2
0.044-inches VT-3 50 fc N/A 0.105-inches VTE 1 Note 2
1 mil. Wire Enhanced
- a.
For the procedure demonstration (VT-1 / VT-3), a near distance vision test chart containing text with lower case characters, without an ascender or descender, containing the correct heights shall be resolved at the distances and illumination levels specified in Table C.1. The lighting source for the above demonstration shall be verified.
- b.
The illumination levels shall be checked before and after each field examination or series of examinations, not to exceed 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> when battery powered portable lighting is used by resolving the applicable characters on the Visual Illumination Card (VIC) the maximum examination distance applied, not to exceed the distance specified in Table C.1. As an alternative to the VIC, minimum illumination levels specified in Table C.1 may be verified with a light meter. Illumination verification checks shall be noted on the report.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 27 of 36 Appendix B (Page 3 of 6) 1.0 VISUAL INSPECTION (VT) (continued)
- c.
The illumination levels shall be verified before each field examination when ambient (not battery powered) lighting is used by resolving the applicable characters on the VIC at the maximum examination distance applied, not to exceed the distance specified in Table C.1. As an alternative to the VIC, minimum illumination levels specified in Table C.1 may be verified with a light meter.
Illumination verification checks shall be noted on the report.
- d.
Remote visual examinations may use visual aids such as mirrors, telescopes, boroscopes, fiber optics, video scopes, cameras, or other suitable instruments. Such systems shall have a resolution capability and color discrimination ability at least equivalent to that obtainable by direct visual observation. The parameters established for the remote visual device demonstration (i.e. actual viewing distance, resolution, monitors, etc.) shall be the parameters used for the remote examination.
- e.
If a boroscope is used, Character Card calibrations in the same plane as the boroscope shall be used (i.e., parallel or perpendicular to the boroscope). Ensure that examination record sheets contain proper reference to the Character Card and inspection angle. [PER 333334]
NOTE: The Enhanced Visual examination is applicable to specific applications (i.e., VT of inner radius areas in lieu of UT). The illumination levels shall be verified before and after each field examination or series of examinations by resolving the 1 mil wire at or near the area of examination at the maximum distance applied not to exceed the distance specified in Table C.1 and using the applicable light source necessary to obtain the required resolution (i.e., flashlight, ambient, etc.).
- 2.
The license renewal visual examinations are typically performed when the piping system is open (such as during maintenance, repair or modification) and components are accessible for visual examination of the internal surfaces.
- 3.
Examinations shall be documented on an appropriate form meeting the required attributes. Generic forms are shown in Attachments 1 and 3.
Other forms that list the required attributes may be used.
- 4.
Examinations that reveal adverse conditions not meeting the acceptance criteria shall be reported to the Program Owner.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 28 of 36 Appendix B (Page 4 of 6) 1.0 VISUAL INSPECTION (VT) (continued)
- 5.
Conditions that cannot be easily recorded on the appropriate data form shall be sketched or photographed in order to record the conditions accurately.
- 6.
Examinations that identify degraded conditions outside the recording requirements (e.g., flaws located outside the required examination area) of this procedure shall be reported to the Program Owner.
D.
VT-1 Examination Method:
- 1.
The VT-1 visual examination shall be conducted to determine the condition of the part, component, or surface examined by detecting degradation from such conditions as cracks, wear, corrosion, erosion or physical damage on the examination surface.
- 2.
The VT-1 visual examination may be performed by the direct or remote visual examination methods or a combination thereof.
- 3.
Examinations that detect crack-like indications may be supplemented by either surface or volumetric examinations to determine the size, shape, and orientation of the suspected flaw.
- 4.
Direct VT-1 visual examinations may be performed when access is sufficient to place the eye within 2-feet of the surface to be examined and at an angle not less than 30 degrees to the surface to be examined.
Mirrors may be used to improve the angle of vision, and aids such as a magnifying lens may be used to assist examinations.
- 5.
Remote examinations may be substituted for direct examination provided the system has resolution capabilities equivalent to that attainable by the direct visual of Table C.1. Optical aids, such as those described in paragraph C.I.d above may be used for the examination. When using Remote Visual Examination techniques, the following shall be documented:
The type of remote equipment used for the exam (See paragraph C. 1.d above for demonstration requirements).
The maximum demonstration distance utilized in paragraph C.1.
Pre and post examination resolution verification times.
- 6.
Lighting, natural or artificial, shall be as required in paragraph C.1.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 29 of 36 Appendix B (Page 5 of 6) 1.0 VISUAL INSPECTION (VT) (continued)
E.
VT-3 Examination Method:
- 1.
The VT-3 visual examination shall be conducted to determine the general condition of the part, component, or surface examined by detecting degradation from such conditions as corrosion, wear, erosion, Microbiological Induced Corrosion (MIC), fouling buildup or physical damage on the examination surface.
- 2.
Examinations that detect crack-like indications shall be supplemented by either surface or volumetric examinations to determine the size, shape, and orientation of the suspected flaw.
- 3.
Direct VT-3 Visual Examination may be performed when access is sufficient to meet the illumination and resolution requirements of Table C.1. Mirrors may be used to aide in the examination.
- 4.
Remote examinations may be substituted for direct examination provided the system has resolution capabilities equivalent to that attainable by the direct visual of Table C.1. Optical aids, such as those described in paragraph 0.1.d above may be used for the examination. When using Remote Visual Examination techniques, the following shall be documented:
The type of remote equipment used for the exam (See paragraph C.1.d above for demonstration requirements).
The maximum demonstration distance utilized in paragraph C.1.
Pre and post examination resolution verification times.
- 5.
Lighting, natural or artificial, shall be as required in paragraph C.1.
F.
Personnel conducting VT's shall transmit all visual inspection results, including any sketches or photographs, as follows:
- 1.
To the Program Owner (or designee), for initial evaluation.
- 2.
To the WO for permanent retention.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 30 of 36 Appendix B (Page 6 of 6) 2.0 OTHER METHODS A.
Other acceptable and accurate inspection methods, which are current at the time of inspection, may be used at the discretion of the Program Owner, for example:
- 1.
Ultrasonic (UT) or radiographic (RT) testing. Note that RT is usually used only on small-bore and socket-welded piping and poses a radiological safety hazard which must be considered.
- 2.
Performance testing, heat transfer testing, or other accepted tests for heat exchangers/coolers may be required to determine the extent of fouling and its impact on heat transfer during the period of extended operation.
- 3.
Magnetic particle (MT) or dye penetrant (PT) testing may be used to detect cracking.
- 4.
Collection and laboratory testing of bacteria (e.g., sulfate-reducing) may be needed to determine the extent of MIC.
B.
Other inspection methods shall be performed by qualified personnel and shall be documented on the applicable NDE data sheet, or an approved equivalent.
C.
If UT is used to detect wall-thinning, cracking, or pitting corrosion, the WO shall require a sign-off that surface preparation is satisfactory (SAT), or prepared in accordance with MCI-0-000-PRPOO2. [PER 333336]
D.
Personnel conducting other inspection methods shall transmit all inspection results, including any sketches or photographs, as follows:
- 1.
To the Program Owner (or designee), for initial evaluation.
- 2.
To the WO for permanent retention.
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 31 of 36 Appendix C (Page 1 of 3)
Aging Effect Appearance and Characteristics Aging Effect and Mechanism Appearance and Characteristics Change in Material Properties/Reduction in Fracture Increased yield and tensile strength Toughness due to Thermal Aging Decreased ductility Degradation of toughness properties Cracking due to Cyclic Loading Brittle-appearing fracture of a normally ductile alloy in the presence of an environment that causes minimal uniform corrosion Cracking due to Stress Corrosion Cracking Highly localized form of corrosion Brittle-appearing fracture of a normally ductile alloy in the presence of an environment that causes minimal uniform corrosion Transgranular Often initiated at pits or other discontinuities Crack growth progresses across the metal grain without regard to grain boundary Intergranular Initiated at areas of intergranular corrosion attack, pitting, or other discontinuities Crack growth progresses along the grain boundaries Elastomer Degradation due to Oxidation Embrittlement, reduced tensile strength, reduced elongation limit, increased stiffness, increased hardness
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 32 of 36 Appendix C (Page 2 of 3)
Aging Effect Appearance and Characteristics Aging Effect and Mechanism Appearance and Characteristics Elastomer Degradation due to Thermal Exposure Oxidation of polymer - Embrittlement, discoloration, crazing, reduced elongation limit Migration of additives and processing aids -
Embrittlement, discoloration, surface film, reduced elongation limit, increased hardness Water solubility increase - Volume loss, wrinkling Conductivity increase - Signal degradation, increased dielectric losses, decreased capacitance Molecular weight decrease - Reduced tensile strength, reduced elongation limit, reduced hardness, decreased creep resistance Softening (sulfur-cured polymers) - Reduced tensile strength, decreased hardness, reduced creep strength Creep damage - Localized or overall distortion Fouling Product Buildup due to Particulate Buildup of deposits on heat exchanger components Loss of Material due to Biofouling Corrosion caused by the attaching of animal and plant life to solid surfaces Loss of Material due to Crevice Corrosion Similar to pitting, but occurs in crevices created by equipment geometry Rate partially depends on crevice geometry and dimensions Autocatalytic in nature once initiated Failure occurs eventually by pitting propagation or stress corrosion cracking Loss of Material due to Galvanic Corrosion Corrosion of one metal joined to another that remains undamaged Loss of Material due to General Corrosion Uniform, regular removal of metal over entire surface of structure Uniform thinning of metal
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 33 of 36 Appendix C (Page 3 of 3)
Aging Effect Appearance and Characteristics Aging Effect and Mechanism Appearance and Characteristics Loss of Material due to Microbiologically Induced Presence of bacteria known to induce corrosion (Note:
Corrosion Presence of microbes is not an exclusive indicator of MIC.)
Heavy surface deposits or tubercles Severe corrosion of materials in solutions to which they are normally resistant Moderate to severe occlusion of pipe, heavy surface deposits on tank walls Undulating, non-uniform surface Foul odor often present Slimy feel Loss of Material due to Pitting Corrosion Localized corrosion attack of otherwise unaffected base metal Results from the failure of a passive film or localized impurities Small relative to total exposed area Self-propagating in nature once initiated Difficult to detect or to predict, but very destructive
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 34 of 36 Attachment I (Page 1 of 1)
Inspection Data Sheet Component Data Component Unit System Component ID (if applicable)
Component Type Component/Location Description Corresponding Flow Diagram/Coordinates Material/Environment (e.g. Carbon Steel/Treated Water)
Inspection Grouping/Chemistry Regime Inspection Data Inspection Method (VT, UT, RT, other)
Degradation Detected (Yes or No)
Description of Degradation (if any)
Change in Material Properties/Reduction in Fracture Toughness YESD NOD Cracking YESD NOD Elastomer Degradation YESD NOD Fouling Product Buildup YES-NOD Crevice Corrosion YESD NOD Galvanic Corrosion YESD NOD General Corrosion YESn NOD Microbiologically Influenced Corrosion YESO NOD Pitting Corrosion YESn NOD Comments (e.g., description of surface condition, reference for any photographs taken)
Examiner:
Date Program Owner Review:
Date (Page 1 of 1)
One-Time Inspection - Information/Results Unit Page Inspection Location Relevant Conditions Job Description Results Inspection Basis for Inspection Inspector Acceptance AC Resulting (No.)
Flow L
nI Material Environment Group Selection Methd Qualifications Criteria (YN PER Method (Y/N)
BFN One-Time Inspection Procedure 0-TI-565 Unit 0 Rev. 0003 Page 36 of 36 (Page 1 of 1)
Typical Tennessee Valley Authority Record of Visual Examination RECORD OF VISUAL EXAMINATION EXAM DATE:
PROCEDURE: 0-TI-565, REV:
REPORT NUMBER:
PLANT:
UNIT:
CYCLE:
COMPONENT ID:
SYSTEM:
DRAWING NO:
VISUAL AI D(S):
COMPONENTTYPE:
PUMP 01 VALVE 0 PIPING [I TANK 01 DUCTWORK 01 TUBING 0 TYPE OF VISUAL EXAM:
EVT-i 0 VT-i 0 VT-3 [0 DIRECT 0 REMOTE [0 LICENSE RENEWAL [0 ILLUMINATION CHECK ADEQUATE: 0 VISUAL CARD S/N:I REMARKS:
Examination Resolution VerificatIon Times:
(Initial)
(Final)
Maximum Demonstration Distance:
WORK ORDER NUMBER:
EXAMINER:
LEVEL:
DATE:
EXAMINER:
LEVEL:
DATE:
REVIEWER:
LEVEL:_
DATE:
Page