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{{Adams
#REDIRECT [[IR 05000483/2012009]]
| number = ML12328A053
| issue date = 11/20/2012
| title = IR 05000483-12-009, on 09/10 - 11/7/2012, on Callaway Plant, Scoping of Nonsafety-Related Affecting Safety-Related Systems and Review of License Renewal Aging Management Programs
| author name = Miller G
| author affiliation = NRC/RGN-IV/DRS/EB-2
| addressee name = Heflin A
| addressee affiliation = Union Electric Co
| docket = 05000483
| license number = NPF-030
| contact person =
| document report number = IR-12-009
| document type = Inspection Report, Letter
| page count = 78
}}
See also: [[see also::IR 05000483/2012009]]
 
=Text=
{{#Wiki_filter:UNITED STATES
                                NU C LE AR RE G ULATO RY C O M M I S S I O N
                                                  R E GI ON I V
                                        612 EAST LAMAR BLVD , SU ITE 400
                                        AR LI NGTON, TEXAS 76011-4125
                                          November 20, 2012
Mr. Adam C. Heflin, Senior Vice
  President and Chief Nuclear Officer
Union Electric Company
P.O. Box 620
Fulton, MO 65251
SUBJECT:        CALLAWAY PLANT - NRC LICENSE RENEWAL INSPECTION REPORT
                05000483/2012009
Dear Mr. Heflin:
On September 28, 2012, a U.S. Nuclear Regulatory Commission (NRC) team completed the
onsite portion of an inspection of your application for license renewal of your Callaway Plant.
The team discussed the inspection results with Ms. S. Kovaleski, Supervising Engineer, and
other members of your staff during the exit meeting on November 7, 2012.
This inspection examined activities that supported the application for a renewed license for the
Callaway Plant. The inspection addressed your processes for scoping structures, systems, and
components to select equipment subject to an aging management review. Further, the
inspection addressed the development and implementation of aging management programs to
support continued plant operation into the period of extended operation. As part of the
inspection, the NRC examined procedures and representative records, interviewed personnel,
and visually examined accessible portions of various structures, systems, or components to
verify license renewal scoping and to observe any effects of equipment aging. These NRC
inspection activities constitute one of several inputs into the NRC review process for license
renewal applications.
The team concluded that your staff appropriately implemented the scoping of nonsafety-related
structures, systems, and components that could affect safety-related structures, systems and
components. The team concluded that your staff conducted an appropriate review of the
materials and environments and established appropriate aging management programs, as
described in the license renewal application and as supplemented through your responses to
requests for additional information from the NRC. The team concluded that your staff
maintained the documentation supporting the application in an auditable and retrievable form.
The team identified a number of issues that resulted in your staff revising your license renewal
application and revising aging management processes, which are described in the report.
Based on the samples reviewed by the team, the inspection results support a conclusion of
reasonable assurance that actions have been identified and have been or will be taken to
manage the effects of aging in the structures, systems, and components identified in your
application and that the intended functions of these structures, systems, and components will be
maintained in the period of extended operation.
 
A. Heflin                                    -2-
In accordance with 10 CFR 2.390 of the NRC's Rules of Practice, a copy of this letter, and its
enclosure, will be available electronically for public inspection in the NRC Public Document
Room or from the Publicly Available Records component of NRCs document 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/
                                                Geoffrey Miller, Chief
                                                Engineering Branch 2
                                                Division of Reactor Safety
Docket: 50-483
License: NPF-30
Enclosure: Inspection Report 05000483/2012009
  w/attachments
Electronic Distribution to Callaway
 
A. Heflin                                  -3-
Electronic distribution by RIV:
Regional Administrator (Elmo.Collins@nrc.gov)
Deputy Regional Administrator (Art.Howell@nrc.gov)
DRP Director (Kriss.Kennedy@nrc.gov)
Acting DRP Deputy Director (Barry.Westreich@nrc.gov)
Acting DRS Director (Tom.Blount@nrc.gov)
Acting DRS Deputy Director (Jeff.Clark@nrc.gov)
Senior Resident Inspector (Thomas.Hartman@nrc.gov)
Resident Inspector (Nestor.Makris@nrc.gov)
Resident Inspector (Zachary.Hollcraft@nrc.gov)
Branch Chief, DRP/B (Neil.OKeefe@nrc.gov)
Senior Project Engineer, DRP/B (Leonard.Willoughby@nrc.gov)
Project Engineer, DRP/B (David.You@nrc.gov)
CW Administrative Assistant (Dawn.Yancey@nrc.gov)
Public Affairs Officer (Victor.Dricks@nrc.gov)
Public Affairs Officer (Lara.Uselding@nrc.gov)
Project Manager (Fred.Lyon@nrc.gov)
Branch Chief, DRS/TSB (Ray.Kellar@nrc.gov)
RITS Coordinator (Marisa.Herrera@nrc.gov)
Regional Counsel (Karla.Fuller@nrc.gov)
Technical Support Assistant (Loretta.Williams@nrc.gov)
Congressional Affairs Officer (Jenny.Weil@nrc.gov)
OEMail Resource
ROPreports
RIV/ETA: OEDO (Cayetano.Santos@nrc.gov)
DRS/TSB STA (Dale.Powers@nrc.gov)
RidsNrrDlr Resource
RidsNrrDlrRpb1 Resource
RidsNrrDlrRpb2 Resource
RidsNrrDlrRerb Resource
RidsNrrDlrRpob Resource
File located: R:\_REACTORS\CWY\CWY LRI2012009 RP-gap.docx ML12328A053
SUNSI Rev Compl.  Yes  No            ADAMS        Yes  No    Reviewer Initials  GAP
Publicly Avail            Yes  No    Sensitive    Yes  No    Sens. Type Initials GAP
DRS/EB2                DRS/EB2          DRS/PSB2        RI:DRS/EB1      DRP/PBE
GPick                  NOkonkwo          SAlferink        GMeyer          JMelfi
/RA/                    /RA/              /RA/            /RA/            /RA/
11/7 /2012              11/15/2012        11/15/2012      11/5/2012        11/8/2012
C:DRS/EB2              C:DRP/PBB        C:DRS/EB2
GMiller                NO'Keefe          GMiller
/RA/                    /RA/              /RA/
11/14/2012              11/ 19/2012        11/20 /2012
OFFICIAL RECORD COPY T=Telephone                  E=E-mail    F=Fax
 
                  U.S. NUCLEAR REGULATORY COMMISSION
                                    REGION IV
Dockets:    50-483
Licenses:    NPF-30
Report:      05000483/2012009
Applicant:  Union Electric Company
Facility:    Callaway Plant
Location:    Junction Hwy CC and Hwy O
            Fulton, MO
Dates:      September 10 through November 7, 2012
Inspectors:  G. Pick, Senior Reactor Inspector and Team Leader
            S. Alferink, Reactor Inspector
            J. Melfi, Reactor Engineer
            G. Meyer, Senior Reactor Inspector, Region I
            N. Okonkwo, Reactor Inspector
Accompanying W. Holston, Senior Mechanical Engineer, Division of License Renewal,
Personnel:  Office of Nuclear Reactor Regulation
Approved By: Geoffrey Miller, Chief
            Engineering Branch 2
            Division of Reactor Safety
                                    -1-                                    Enclosure
 
                                        TABLE OF CONTENTS
SUMMARY OF FINDINGS............................................................................................................ 4
REPORT DETAILS ....................................................................................................................... 5
OTHER ACTIVITIES
  4OA5  Other - License Renewal ......................................................................................... 5
        a.    Inspection Scope ............................................................................................. 5
        b.1  Evaluation of Scoping of Nonsafety-Related Structures, Systems, and
                        Components ........................................................................................ 5
        b.2  Evaluation of New Aging Management Programs ........................................... 6
              .1 B2.1.15 Aboveground Metallic Tanks (XI.M29) .......................................... 7
              .2 B2.1.18 One-Time Inspection (XI.M32) ..................................................... 8
              .3 B2.1.19 Selective Leaching (XI.M33) ........................................................ 9
              .4 B2.1.21 External Surfaces Monitoring of Mechanical
                        Components (XI.M36) ........................................................................ 10
              .5 B2.1.25 Buried and Underground Piping and Tanks (XI.M41) ................. 11
              .6 B2.1.37 Electrical Cable Connections Not Subject to 10 CFR 50.49
                        Environmental Qualification Requirements (XI.E6) ........................... 13
              .7 B2.1.39 Metal-Enclosed Bus (XI.E4) ....................................................... 14
        b.3  Evaluation of Existing Aging Management Programs .................................... 15
              .1 B2.1.2 Water Chemistry (XI.M2) .............................................................. 15
              .2 B2.1.3 Reactor Head Closure Stud Bolting (XI.M3)................................. 16
              .3 B2.1.7 Flow-Accelerated Corrosion (XI.M17) .......................................... 17
              .4 B2.1.10 Open-Cycle Cooling Water System (XI.M20) ............................. 18
              .5 B2.1.11 Closed Treated Water Systems (XI.M21A) ................................. 19
              .6 B2.1.13 Fire Protection (XI.M26) ............................................................. 20
              .7 B2.1.14 Fire Water System (XI.M27) ....................................................... 22
              .8 B2.1.16 Fuel Oil Chemistry (XI.M30) ....................................................... 23
              .9 B2.1.24 Lubricating Oil Analysis (XI.M39) ............................................... 25
              .10 B2.1.30 Masonry Walls (XI.S5)................................................................ 26
              .11 B2.1.31 Structures Monitoring (XI.S6) ..................................................... 26
              .12 B2.1.32 RG 1.127, Inspection of Water-Control Structures Associated
                        with Nuclear Power Plants (XI.S7) ..................................................... 28
              .13 B2.1.33 Protective Coating Monitoring and Maintenance
                        Program (XI.S8) ................................................................................. 28
              .14 B2.1.34 Insulation Material for Electrical Cables and Connections Not
                        Subject to 10 CFR 50.49 Environmental Qualification
                        Requirements (XI.E1) ........................................................................ 29
              .15 B2.1.35 Insulation Material for Electrical Cables and Connections Not
                        Subject to 10 CFR 50.49 Environmental Qualification Requirements
                        Used in Instrumentation Circuits (XI.E2) ............................................ 30
              .16 B2.1.36 Inaccessible Power Cables Not Subject to 10 CFR 50.49
                        Environmental Qualification Requirements (XI.E3) ........................... 31
                                                  -2-                                                                  Enclosure
 
      b.4  System Reviews ............................................................................................ 32
      c.  Overall Conclusion ........................................................................................ 34
4OA6  Meetings, Including Exit ......................................................................................... 34
ATTACHMENT: SUPPLEMENTAL INFORMATION ........................................................... A-1
                                      -3-                                                                  Enclosure
 
                                    SUMMARY OF FINDINGS
IR 05000483/2012009; 09/10 - 11/7/2012; Callaway Plant, Scoping of Nonsafety-Related
Affecting Safety-Related Systems and Review of License Renewal Aging Management
Programs
NRC inspectors from Region IV, Region I, and a reviewer from Headquarters performed onsite
inspections of the applicant's license renewal activities. The team performed the evaluations in
accordance with Manual Chapter 2516, Policy and Guidance for the License Renewal
Inspection Programs, and Inspection Procedure 71002, License Renewal Inspection. The
team did not identify any findings as defined in NRC Manual Chapter 0612.
The team concluded that the applicant adequately performed scoping of nonsafety-related
structures, systems, and components as required by 10 CFR 54.4(a)(2). The team concluded
that the applicant conducted an appropriate review of the materials and environments and
established appropriate aging management programs, as described in the license renewal
application and as supplemented through responses to requests for additional information from
the NRC. The team found that the applicant provided the documentation that supported the
application and inspection process in an auditable and retrievable form. The team identified a
number of issues that resulted in changes to the application, aging management programs, and
processes.
Based on the samples reviewed by the team, the inspection results supported a conclusion of
reasonable assurance that actions have been identified and have been taken or planned to
manage the effects of aging in the structures, systems, and components identified in the
application and that the intended functions of these structures, systems, and components would
be maintained in the period of extended operation.
A.      NRC-Identified and Self-Revealing Findings
        No findings of significance were identified
B.      Licensee-Identified Violations
        None.
                                            -4-                                        Enclosure
 
                                      REPORT DETAILS
4.    OTHER ACTIVITIES
4OA5 Other - License Renewal
  a.  Inspection Scope (IP 71002)
      NRC inspectors performed this inspection to evaluate the thoroughness and accuracy of
      the applicant's scoping of nonsafety-related structures, systems, and
      components (SSCs), as required by 10 CFR 54.4(a)(2). The team evaluated whether
      aging management programs would be capable of managing identified aging effects in
      an appropriate manner.
      In order to evaluate scoping activities, the team selected a number of SSCs for review to
      evaluate whether the methodology used by the applicant appropriately addressed the
      nonsafety-related systems with the potential to affect the safety functions of a structure,
      system, or component within the scope of license renewal. Scoping activities are those
      activities performed by the applicant to identify the population of SSCs that should be
      considered for aging management activities.
      The team selected a sample of 23 of the 39 aging management programs developed by
      the applicant to verify the adequacy of the applicants guidance, implementation
      activities, and documentation. The team evaluated the aging management programs to
      determine whether the applicant would appropriately manage the effects of aging and to
      verify that the applicant would maintain the component safety functions during the period
      of extended operation.
      The team reviewed supporting documentation and interviewed personnel to confirm the
      accuracy of the license renewal application conclusions. The team walked down
      accessible portions of the in-scope systems to observe aging effects and to review the
      material condition of the SSCs. In-scope refers to SSCs that the applicant concluded
      would require aging management because they were passive or long-lived.
  b.1 Evaluation of Scoping of Nonsafety-Related Structures, Systems, and Components
      The team assessed the thoroughness and accuracy of the methods used to identify the
      SSCs required to be within the scope of the license renewal application as required by
      10 CFR 54.4(a)(2). The team verified that the applicant had established procedures
      consistent with the NRC-endorsed guidance contained in Nuclear Energy Institute 95-10,
      Industry Guideline for Implementing the Requirements of 10 CFR Part 54 - The License
      Renewal Rule, Revision 6, Appendix F, Sections 3, 4, and 5. The team assessed
      whether the applicant evaluated: (1) nonsafety-related SSCs within the scope of the
      current licensing basis, (2) nonsafety-related SSCs directly connected to safety-related
      SSCs, and (3) nonsafety-related SSCs not directly connected but spatially near
      safety-related SSCs.
      The team reviewed the complete set of license renewal drawings. The applicant had
      color-coded the drawings to indicate in-scope systems and components required
                                            -5-                                          Enclosure
 
    by 10 CFR 54.4(a)(1), (a)(2), and (a)(3). The team interviewed personnel, reviewed
    program documents and independently walked down numerous plant areas. The team
    determined that the personnel involved in the process were knowledgeable and
    appropriately trained.
    For SSCs selected because of potential spatial interactions, where failure of
    nonsafety-related components could adversely affect adjacent safety-related
    components, the team determined that the applicant accurately categorized the plant
    configuration within the license renewal documents. The team reviewed plant conditions
    in the essential service water pump house and the emergency diesel generator building.
    The team walked down the areas to confirm that safety-related equipment did not have
    any unaccounted for nonsafety-related components. The team reviewed plant areas,
    designated as not containing safety-related equipment. The specific areas reviewed
    included the condensate storage tank, valve house and tunnel, and the communications
    corridor to confirm that areas had no such equipment. Also, the team selected specific
    components to confirm that the components had been scoped properly and included
    accurately in the drawings and database. The team determined that the applicant
    accurately categorized the plant configuration for potential spatial interactions within the
    license renewal documents.
    For SSCs selected because of potential structural interaction (seismic design of
    safety-related components potentially affected by nonsafety-related components), the
    team determined that the applicant accurately identified and categorized the structural
    boundaries within the program documents. The team walked down areas in the turbine
    and auxiliary buildings and independently sampled the seismic boundary determinations
    identified on the isometric drawings. The team determined that the applicant
    appropriately identified the seismic design boundaries and correctly included the
    applicable components within the license renewal scope. Further, the team confirmed
    the accuracy of statements in applicant responses to requests for additional information
    related to potential safety-related equipment in the turbine building. The team
    determined that the applicant accurately categorized the plant configuration for potential
    structural interactions within the license renewal documents.
    The team concluded that the applicant had implemented an acceptable method of
    scoping nonsafety-related SSCs and that this method resulted in appropriate scoping
    determinations for the samples reviewed.
b.2 Evaluation of New Aging Management Programs
    The team reviewed 7 of 9 new aging management programs to determine whether the
    applicant had established appropriate actions or had actions planned to manage the
    effects of aging. The team reviewed site-specific operating experience to determine
    whether there were any aging effects for the systems and components within the scope
    of these programs that had not been identified when considering applicable industry
    operating experience.
    Because the applicant had developed draft implementing procedures, the team
    assessed the effectiveness of the planned implementation of these programs. Some of
    the new programs were one-time inspection programs that will involve testing of
                                          -6-                                          Enclosure
 
  applicable components prior to the period of extended operation to confirm the absence
  of significant aging effects. If the results determine aging effects have occurred, the
  applicant will need to establish actions to manage the identified effects.
  The team selected in-scope SSCs to assess how the applicant maintained plant
  equipment, to visually observe examples of nonsafety-related equipment determined to
  be within the scope of license renewal because of the proximity to safety-related
  equipment, and to evaluate the potential for failure as a result of aging effects.
.1 B2.1.15 Aboveground Metallic Tanks (XI.M29)
  The applicant established this new aging management program, consistent with
  NUREG-1801, Generic Aging Lessons Learned (GALL) Report, Revision 2 (GALL
  Report), to manage loss of material for the external surfaces, including the bottom
  surfaces, of aboveground, outdoor metallic tanks. Additionally, this program was
  credited with managing cracking, blistering, and change in color of the acrylic/urethane
  insulation on the condensate storage tank. The four tanks within the scope of the
  program included the condensate storage, the refueling water storage, and the two fire
  water storage tanks. For the carbon steel fire water tanks, the program relied on the
  application of coatings and a tank bottom edge grout as corrosion preventive measures.
  The applicant had cathodically protected the fire water tanks to prevent corrosion on
  exposed bare metal surfaces of the tanks. For the stainless steel condensate storage
  and refueling water tanks, the applicant used jacketed insulation with overlapping seams
  that prevent moisture intrusion or spray-on polyurethane foam insulation that adheres to
  tank surfaces as a corrosion preventive measure.
  For the four tanks, the team reviewed license renewal documents, the aging
  management program evaluation report, corrective action documents, technical
  specifications and drawings, procedures, and current external inspection results. The
  team verified that the applicant planned to perform ultrasonic testing (volumetric) to
  determine thickness measurements of tank bottoms whenever the tanks are drained and
  at least once within five years of entering the period of extended operation for the
  condensate storage and refueling water storage tanks. The volumetric inspection should
  provide direct evidence of any loss of material that has occurred or that could result in a
  loss of function.
  The applicant took an exception to the requirement in the GALL Report to perform
  ultrasonic testing (volumetric) to determine thickness measurements of tank bottoms
  whenever the tanks are drained and at least once within five years of entering the period
  of extended operation. At the time of the inspection, the applicant performed visual
  inspections on an alternating refueling outage frequency for each fire water storage tank.
  The applicant planned to perform ultrasonic thickness measurements of the bottom of
  each fire water storage tank within five years of entering the period of extended
  operation and a 10-year frequency from the initial inspection. The team determined that
  performing ultrasonic thickness measurements every ten years supplemented by visual
  inspections would provide an effective means to manage loss of material on the fire
  water storage tank bottoms.
                                          -7-                                        Enclosure
 
  The applicant established procedures to visually inspect for aging of the tank external
  surface paint or damage of the insulation covering. The applicant identified
  requirements to remove a representative sample of the stainless steel tank insulation to
  inspect the metal surface. Whenever the applicant finds damaged insulation that could
  permit water ingress, the applicant established requirements to remove the damaged
  insulation and perform inspections. The applicant will inspect the surfaces of the carbon
  steel fire water tanks for signs of coating degradation, such as flaking, cracking, and
  peeling, to manage loss of material of the metallic surfaces.
  The team confirmed from review of the tank inspection results that the applicant had
  previously identified light corrosion and implemented corrective actions to clean and
  recoat the fire water storage tanks. The team concluded that the surface coating of
  corrosion had no impact on the structural integrity of the tank.
  The team walked down each of the tanks and discussed the condition of the tanks with
  program and system engineers. During the walk downs, the team identified that eight of
  the ten accessible condensate storage tank anchor bolts had insufficient thread
  engagement on their nuts. The applicant confirmed that the bolting manual specified
  that these nonsafety-related anchor bolts were to have the studs flush with their nuts.
  The applicant documented this performance deficiency in Callaway Action
  Request 2012-06831. The applicant performed a prompt operability assessment and
  determined that all 56 anchor bolts could have the minimal amount of thread
  engagement identified during the walk down and still remain functional.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in the affected systems. The team concluded that, if implemented as
  described with the exception, the applicant developed guidance to appropriately identify
  and address aging effects during the period of extended operation.
.2 B2.1.18 One-Time Inspection (XI.M32)
  This was a new aging management program, consistent with the GALL Report, to
  manage loss of material, cracking, and reduction of heat transfer internal to plant
  systems. The applicant planned to conduct these one-time inspections to identify and
  characterize the material conditions in representative low-flow and stagnant areas of
  plant piping and components. The systems and components reviewed were evaluated
  by the Water Chemistry, the Fuel Oil Monitoring, and the Oil Analysis programs. The
  planned visual and volumetric inspections should provide direct evidence of the
  presence and extent of loss of material resulting from all types of corrosion in treated
  liquid environments if it had occurred. The inspection should also provide direct
  evidence of any cracking as a result of stress corrosion cracking.
  The team reviewed the license renewal application, aging management program
  evaluation report, plant operating experience, and a draft program procedure. The team
  discussed the program evaluations and planned activities with the responsible license
  renewal and plant staff. The team reviewed a sampling plan based on the
  material/environment combinations at Callaway, which estimated that approximately 200
  inspections would be performed. The team confirmed that appropriately qualified
                                        -8-                                          Enclosure
 
  personnel would perform the nondestructive evaluations by using procedures and
  processes that met regulatory requirements.
  The elements of the program included: (1) determining the sample size based on
  20 percent of the components in each material-environment-aging effect group up to a
  maximum of 25 components, (2) identifying inspection locations in each material-
  environment group based on the potential for the aging effect to occur, (3) identifying the
  most effective examination technique, including acceptance criteria, to be used,
  and (4) evaluating the aging effects and the need for follow-up examinations using the
  corrective action program.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in the affected systems. The team concluded that, if implemented as
  described, the applicant provided guidance to appropriately identify and confirm whether
  aging effects had occurred prior to the period of extended operation.
.3 B2.1.19 Selective Leaching (XI.M33)
  This was a new aging management program, consistent with the GALL Report with
  exception, credited with managing loss of material resulting from selective leaching. The
  selective leaching could occur in components made from gray cast iron and copper alloy
  with greater than 15 percent zinc or greater than 8 percent aluminum exposed to treated
  water, raw water, waste water, or groundwater environments. There were no copper
  alloy components with greater than eight percent aluminum within the scope of license
  renewal. The program will include a one-time visual inspection supplemented by
  mechanical testing methods of susceptible components to determine whether loss of
  material resulted from selective leaching. Inspections will commence within the five-year
  period prior to entering the period of extended operation. The following systems
  contained components susceptible to selective leaching: fire protection; chemical and
  volume control; service water; compressed air; essential service water; plant heating;
  fuel building heating, ventilation and air conditioning; auxiliary building heating,
  ventilation and air conditioning; containment purge; and oily waste.
  The team reviewed the license renewal application, the draft NRC aging management
  program audit results, aging management program evaluation report, plant operating
  experience, and draft implementing procedures. The team discussed the program
  evaluations and planned activities with the responsible staff. If selective leaching is
  detected, deficiencies will be corrected in order to ensure that the systems will perform
  their intended function. Follow-up evaluations would include confirmation through
  metallurgical evaluation and expansion of the sample size.
  The team noted that the applicant identified an exception to allow opportunistic
  inspections of excavated buried gray cast iron fire protection valves and will send at
  least one for laboratory metallurgical examination from each batch with a minimum of
  two tests within the five years prior to entering the period of extended operation. The
  team determined that opportunistic inspections with a minimum of two valves being
  submitted for metallurgical examination would provide adequate insight into whether
  selective leaching was occurring in the soil environment. The metallurgical testing
                                        -9-                                            Enclosure
 
  provided more accurate indication whether selective leaching occurred than simply
  scraping and chipping the metal.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in components and systems that have metal alloys subject to this
  mechanism. The team concluded that, if implemented as described, the applicant
  provided guidance to appropriately identify and address aging effects during the period
  of extended operation.
.4 B2.1.21 External Surfaces Monitoring of Mechanical Components (XI.M36)
  This was a new aging management program, consistent with the GALL Report, credited
  with managing: (1) loss of material and cracking for metallic components; (2) cracking
  and changes in material properties for cement board (splash panel) components;
  and (3) loss of material, cracking, hardening and loss of strength for polymeric
  components. The applicant planned to conduct periodic engineering walk downs of
  external surfaces to: (1) identify loss of material and leakage; (2) include manual or
  physical manipulation of polymeric material to verify the absence of cracking, hardening,
  or loss of strength; and (3) inspect stainless steel components for cracking when
  exposed to an air environment containing halides.
  The team reviewed license renewal documents, the aging management program
  evaluation report, and implementing procedures. The team interviewed system
  engineers and license renewal personnel and performed system walk downs to evaluate
  the external condition of plant systems.
  The applicant planned to conduct visual inspection of metallic components for
  (1) corrosion, corrosion stains, material wastage, evidence of insulation damage or
  wetting; wear, flaking or oxide-coated surfaces; and leakage onto external surfaces
  and (2) coating degradation (e.g. cracking, flaking, and blistering) as an indicator of
  possible underlying degradation of the component. The applicant planned to inspect
  polymeric materials for dimensional change, exposure of internal reinforcement, and
  hardening/loss of strength as evidenced by loss of suppleness during manual or physical
  manipulation. The applicant planned to evaluate stainless steel components for cracking
  when exposed to an aggressive air environment containing halides. The applicant
  planned inspection of cement board components for loss of material or cracking that
  results in a loss of the components intended function.
  The applicant planned to determine the inspection intervals for inaccessible components
  through an evaluation of aging effects and their impact on intended functions observed
  during external surface inspections on accessible components with the same material
  and environment combination. The team verified that the applicant evaluated
  degradation in accordance with their corrective action program.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent plant operating history to determine the effects of aging in the
  affected systems. The team concluded that, if implemented as described, the applicant
                                        - 10 -                                      Enclosure
 
  provided guidance to appropriately identify and address aging effects during the period
  of extended operation.
.5 B2.1.25 Buried and Underground Piping and Tanks (XI.M41)
  This was a new aging management program, consistent with the GALL Report, credited
  with managing the aging of buried and underground steel, stainless steel, and high
  density polyethylene components for loss of material, cracking, and blistering. The
  program includes prevention, mitigation, and inspection activities, including coatings,
  quality of backfill, cathodic protection, periodic inspections, and monitoring of the fire
  protection jockey pump activity. This program included the high pressure coolant
  injection, fire protection, emergency diesel fuel oil storage and transfer, essential service
  water, service water, and auxiliary feedwater systems.
  The team reviewed the aging management program evaluation report, implementing
  procedures and procedure markups, and corrective action documents. The team also
  reviewed plant specific operating experience, cathodic protection system evaluation
  reports, and excavation results. The team interviewed engineers responsible for the
  buried pipe and coatings programs and the cathodic protection system.
  The team determined that the three exceptions identified by the applicant agreed with
  changes identified in LR-ISG-2011-03, Changes to the Generic Aging Lessons Learned
  (GALL) Report Revision 2 Aging Management Program (AMP) XI.M41, Buried and
  Underground Piping and Tanks. These exceptions addressed that there were no
  coatings on the high density polyethylene piping, external volumetric examinations would
  not be utilized to detect internal corrosion of underground piping because other aging
  management programs evaluate aging effects for each of the in-scope systems, and
  evaluations would be used to expand inspections once a deficient condition was
  identified rather than a pure doubling of the sample size.
  The team reviewed the buried pipe program against the recommendations in
  LR-ISG-2011-03 and determined that the proposed program was consistent except for a
  deficiency related to cathodic protection. The team determined that the existing cathodic
  protection system did not provide sufficient protection of all buried in-scope piping. The
  applicant stated that they would either upgrade the cathodic protection system to meet
  the recommended availability and effectiveness requirements or perform the increased
  inspections required for a plant with an ineffective cathodic protection system. The team
  reviewed the applicants response to Request for Additional Information Item B2.1.25-6a
  in Letter ULNRC-05923, Responses to Request for Additional Information Set #13 &
  #14 and Amendment 14 to the Callaway License Renewal Application, dated
  October 31, 2012. The team found this response satisfactory since the applicant
  committed to meet the conditions in LR-ISG-2011-03 by establishing a cathodic
  protection system that met the availability and effectiveness criteria or by completing the
  specified number of inspections in each ten-year interval.
  The team noted that the Close-Interval Survey and Direct Current Voltage Gradient
  Survey Buried Fire Water Protection Piping report, dated May 7, 2008, recommended
  that for locations not meeting -850 mV criterion, the station should determine whether
  the alternative 100 mV potential shift criterion would demonstrate acceptable cathodic
                                        - 11 -                                        Enclosure
 
protection. The team also noted that LR-ISG-2011-03, Table 6a, Cathodic Protection
Acceptance Criteria, footnote 2, states, [w]hen the 100 mV criterion is utilized in lieu of
the -850 mV CSE criterion for steel piping, or where copper or aluminum components
are protected, applicants must explain in the application why the effects of mixed
potentials are minimal and why the most anodic metal in the system is adequately
protected. During discussions, the applicant stated that they would only use the 100mV
criterion for cast iron fire protection components because in the galvanic series, cast iron
has sufficient margin in its native value (i.e., -500 mV) to allow utilization of an increase
of -100 mV. The team reviewed the applicants response to a request for additional I
information for Item B2.1.25-5a. From review of the response, the team determined that
the applicant concluded that they had no electrically isolated piping sections and no data
to quantify that the effects of mixed potentials would be minimal. The team concluded
that the applicant would only use the -850 mV criteria and found the applicants
response satisfactory.
From review of several opportunistic buried piping inspection results, the team
determined that the applicant had appropriately evaluated and documented inspection
findings with one exception. The team determined that the buried pipe engineer and
coatings engineer were appropriately involved in each inspection. The applicant
documented the results, including location, length of piping inspected, excavation site
details, photographs, description of nonconforming conditions, ultrasonic inspections
results, and coating repair dispositions. In one instance, the applicant had not
documented a condition adverse to quality (i.e., pieces of wood found in the backfill
adjacent to stainless steel piping). When questioned, the applicant agreed that the wood
was, in fact, foreign material in the backfill. The applicant documented this
nonconforming condition in Callaway Action Request 2012-06525.
In addition, for a buried pipe evaluation of piping considered not in-scope, the team
reviewed photographs that appeared to indicate pipe wrapping that was not completely
adhered. During discussions, the applicant stated that had the buried piping been
safety-related or in-scope, it is likely that they would have replaced the wrapping. The
applicant added a corrective action to Callaway Action Request 2012-06868 that
specified the coatings engineer will perform the coatings evaluation when required.
The team reviewed several soil sample results. With the exception of one instance, the
correct parameters were analyzed. During the excavation of stainless steel piping the
buried piping engineer failed to preserve the samples in a manner appropriate to allow
testing for bacteria content. When questioned by the team in relation to how the
knowledge should be captured, the applicant initiated actions and revised Form CA2904,
As Found Buried Piping Inspection Form, to describe packing samples in ice to keep
them cool during shipping.
The team reviewed Procedure MTT-ZZ-01003, Coatings and Wrapping of Piping,
Revision 6, for new and repaired coating locations. The team noted that Sections 4.10
and 4.12 stated that Holiday testing (continuity testing) may be conducted. The team
informed the applicant that performing Holiday testing at lower voltages would confirm
the correct application of coatings without damaging the coating. The applicant
documented this procedure gap in Callaway Action Request 2012-06616 (i.e., enhance
the procedure to conduct Holiday testing on new shop and field applied thin coatings
                                      - 12 -                                        Enclosure
 
  where Holiday testing is accessible). The team determined that Section 4.7 lists a 10°F
  lower limit for use of the procedure, which agreed with the information provided by the
  vendor. The team identified a potential conflict between Section 6.5.3 that directs the
  craft to apply one coat of primer and Section 5.6, which states that primer is used, if
  required. The team determined that the vendor recommended that a primer be used
  anytime the temperature is below 32°F. Because of the potential for error, the applicant
  added the need to correct this apparent conflict in application of primer to piping in
  Callaway Action Request 2012-06616.
  The team concluded that the applicant had performed appropriate evaluations of the
  piping conditions and considered pertinent industry experience and plant operating
  history to determine the effects of aging on buried piping and tanks. The team
  concluded that, if implemented as described including the exceptions and changes
  described in the above paragraphs, the applicant developed guidance to appropriately
  identify and address aging effects during the period of extended operation.
.6 B2.1.37 Electrical Cable Connections Not Subject to 10 CFR 50.49 Environmental
  Qualification Requirements (XI.E6)
  This was a new aging management program, consistent with the GALL Report, credited
  with managing the increased resistance of connections to ensure that either aging of
  metallic cable connections was not occurring and/or that the existing preventive
  maintenance program was effective. This one-time test would confirm the absence of
  age-related degradation of cable connections resulting from thermal cycling, ohmic
  heating, electrical transients, vibration, chemical contamination, corrosion, or oxidation of
  non-environmentally qualified electrical cable connections. The applicant planned to
  evaluate a representative sample of electrical connections for in-scope components
  based upon the service application, circuit loading, and environment.
  The representative sample will consist of 20 percent of the population of each type of
  connection, with a maximum of 25 connections, which will be tested at least once prior to
  the period of extended operation. The applicant planned to select the samples based
  upon voltage level (medium and low voltage), circuit loading (high loading), connection
  type, and location (high temperature, high humidity, vibration, etc.). The technical basis
  for the sample selection will be documented. The applicant planned to establish
  acceptance criteria that will be based on the temperature rise above the ambient
  temperatures or the baseline temperature data from the same type of connections being
  tested.
  The team reviewed license renewal documents, the aging management program
  evaluation report, corrective action documents, industry and plant specific operating
  experience, and thermography results. The team walked down selected equipment
  while the applicant took thermography readings. The team determined that the applicant
  routinely performed infrared thermography as part of the preventive maintenance
  program for non-environmentally qualified electrical connections. In reviewing the
  operating experience, the team confirmed that the preventive maintenance program
  identified cable connections with thermal anomalies. These anomalies were evaluated
  and successfully repaired using the corrective action program and work process,
  respectively.
                                        - 13 -                                      Enclosure
 
  The team concluded that the applicant performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging. The team concluded that, if implemented as described, including
  establishing an appropriate sample plan, the applicant provided guidance to
  appropriately identify and address aging effects during the period of extended operation.
.7 B2.1.39 Metal-Enclosed Bus (XI.E4)
  This was a new aging management program, consistent with the GALL Report, credited
  with managing the aging affects associated with degradation of non-segregated metal-
  enclosed bus ducts, including bolted bus bar connections, insulators, supports, and
  elastomers. The program included 4.16 kV non-segregated buses that provided power
  to the circulating and service water pumps. The visual inspections will be performed at
  least once every five years, with the first inspections to be completed prior to the period
  of extended operation.
  The team reviewed license renewal documents, the aging management program
  evaluation report, implementing procedures, preventive maintenance tasks, and industry
  operating experience. The team walked down the in-scope non-segregated bus ducts
  and interviewed the license renewal project personnel and the responsible engineers.
  The applicant planned to inspect: (1) internal surfaces of bus enclosure assemblies for
  cracks, corrosion, foreign debris, excessive dust buildup, and evidence of moisture
  intrusion; (2) bus insulation for signs of reduced resistance resulting from thermal
  degradation, radiation induced oxidation, moisture/debris intrusion, or ohmic heating, as
  indicated by embrittlement, cracking, chipping, melting, discoloration, or swelling;
  (3) internal bus insulating supports for structural integrity and signs of cracks;
  (4) external portions of the bus duct, including gaskets and sealants, for surface
  cracking, crazing, scuffing, dimensional change (e.g., "ballooning" and "necking"),
  shrinkage, discoloration, hardening and loss of strength caused by elastomer
  degradation; and (5) external surfaces for loss of material resulting from general
  corrosion, pitting, and crevice corrosion.
  The applicant planned to inspect visually a sample (20 percent of the population with a
  maximum of 25) of the accessible bolted connections. During the walk down and
  review, the team identified that the planned preventive maintenance activity and the
  plant drawings for the non-segregated bus duct did not identify the presence of a gasket
  between each bus duct joint. Further, the applicant did not discuss evaluating the
  gasket material in the aging management program evaluation report. From review of the
  vendor manual for the non-segregated bus duct, the team determined that the bus duct
  joints required installation of a gasket. The applicant initiated Callaway Action
  Request 201206807 to resolve the discrepancy between the vendor and licensee
  documents. The applicant planned to inspect the non-segregated bus duct in
  December 2012 to establish the presence of the gaskets. If the applicant identifies no
  gaskets are present, the applicant will install the gaskets.
  The team determined that the aging management program evaluation report did not list
  nor discuss managing aging effects of flexible links from the bus duct to the transformers
                                        - 14 -                                        Enclosure
 
    and to the switchgear. During walk downs and review of design information, the
    applicant confirmed the presence of flexible links and identified the need to monitor
    these connections for aging effects. The applicant initiated Procedure Change Tracking
    Form CW192 to include the flexible links in the bus duct preventive maintenance
    program and revise the aging management program evaluation report to include the
    inspection of flexible links for the bus duct connections.
    The team determined that the applicant cleaned and visually inspected the metal-
    enclosed bus ducts during outages in accordance with existing preventive maintenance
    tasks. The applicant found no evidence of aging effects during past inspections of the
    metal-enclosed bus ducts and has initiated a preventive maintenance procedure to
    monitor and correct any aging effects in the future.
    The team concluded that the applicant had performed appropriate evaluations and
    considered pertinent plant and industry experience to determine the effects of aging on
    the metal enclosed non-segregated bus ducts. The team concluded that, if implemented
    as described, the applicant provided guidance to appropriately identify and address
    aging effects during the period of extended operation.
b.3 Evaluation of Existing Aging Management Programs
    The team sampled 16 of the 30 existing aging management programs to determine
    whether the applicant had taken or planned to take appropriate actions to manage the
    effects of aging, as specified in the GALL Report.
    The team reviewed site-specific operating experience to determine whether there were
    any aging effects for the systems and components within the scope of these programs
    that had not been identified from the applicants review of industry operating experience.
    The team evaluated whether the applicant implemented or planned to implement
    appropriate actions to manage the effects of aging. These programs have established
    procedures, records of past corrective actions, and previous operating experience
    related to applicable components. Further, some programs required the applicant to
    implement enhancements (i.e., new program aspects that will be implemented prior to
    the period of extended operation) to ensure consistency with the GALL Report.
    The team walked down selected in-scope SSCs to assess how the applicant maintained
    plant equipment under the current operating license, to visually observe examples of
    nonsafety-related equipment determined to be in-scope because of the proximity to
    safety-related equipment, and to assess the potential for failure as a result of aging
    effects.
.1  B2.1.2 Water Chemistry (XI.M2)
    This was an existing program, consistent with the GALL Report, credited with managing
    loss of material, cracking, reduction of heat transfer, and wall thinning in components
    exposed to a treated water environment. This mitigation program relied on monitoring
    and control of primary and secondary water chemistry to keep peak levels of various
                                          - 15 -                                      Enclosure
 
  contaminants below system-specific limits based on Electric Power Research Institute
  primary and secondary water chemistry guidelines.
  The applicant established their primary water chemistry program consistent with Electric
  Power Research Institute 1014986, PWR Primary Water Chemistry Guidelines,
  Revision 6, Volumes 1 and 2. The applicant established their secondary water
  chemistry program consistent with Electric Power Research Institute 1016555, PWR
  Secondary Water Chemistry Guidelines, Revision 7. The applicant planned to
  supplement this program with the One-Time Inspection Program, which will utilize
  inspections or nondestructive evaluations of representative samples to verify the
  effectiveness of the Water Chemistry program in stagnant or low-flow areas.
  The team reviewed license renewal documents, the aging management program
  evaluation report, implementing procedures, audits and self-assessments, program
  health reports, corrective action documents, the site strategic chemistry plan, and
  primary water chemistry trend data for the last five years. The team interviewed the
  program owners and license renewal project personnel. The team verified that the
  applicant maintained the primary and secondary water chemistry programs within the
  guidelines of Electric Power Research Institute 1014986 and Electric Power Research
  Institute 1016555, respectively.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in the affected systems. The team concluded that the applicant provided
  guidance to appropriately identify and address aging effects during the period of
  extended operation if the program is implemented as described.
.2 B2.1.3 Reactor Head Closure Stud Bolting (XI.M3)
  This was an existing program, consistent with the GALL Report, credited with managing
  cracking and loss of material of the reactor head closure studs. The program included
  periodic visual and volumetric examinations of reactor vessel flange stud hole threads,
  reactor head closure studs, nuts, and washers and performed visual inspection of the
  reactor vessel flange during primary system leakage tests. The program conducted
  inspections in accordance with American Society of Mechanical Engineer Section XI,
  Subsection IWB, Table IWB 2500-1, Examination Categories, Examination Category B-
  G-1, Pressure Retaining Bolting Greater Than 2 in. (50 mm) in Diameter. The program
  included preventive measures as recommended in Regulatory Guide 1.65, Materials
  and Inspections for Reactor Vessel Closure Studs, to use stable lubricants and to use
  bolting material for closure studs that had an actual yield strength less than 150 kilo-
  pounds per square inch.
  The team reviewed the aging management program evaluation report, implementing
  procedures, corrective action documents, and operating experience. The team reviewed
  certified material test reports, engineering evaluations related to a stud protection
  sleeve, stress calculations, and nondestructive evaluations of the reactor vessel studs.
  The team verified that the applicant did not use lubricants containing molybdates and
  verified that the material had yield strength less than 150 kilo-pounds per square inch.
                                        - 16 -                                        Enclosure
 
  From review of operating experience and discussions with NRC headquarters personnel,
  the team determined that the applicant had several reactor vessel stud holes that had
  damaged threads removed. The team determined that Stud Holes 7, 4, 5, 53, 2, and 9
  had 4, 6, 7.9, 9, 13.1 and 15.1 threads removed, respectively. Four other stud holes had
  one or fewer threads removed. The applicant attributed the damage to foreign material
  that had dropped into the stud holes because of poor foreign material exclusion controls
  during the several outages beginning with the first refueling outage. Also, Stud 18
  became stuck in the vessel flange 2.625 inches from being fully inserted during
  Refueling Outage 8. The team reviewed the calculations that demonstrated that
  sufficient threads were engaged to allow the reactor vessel to be tensioned without
  overstressing the threads on the stud or in the stud holes. The team concluded that the
  threads were not overstressed provided that the threads that were engaged did not have
  any damage. During discussions, the applicant described that they had no evidence to
  indicate the presence of additional thread damage.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging for the reactor head closure studs and other components. The team
  concluded that, if implemented as described, the applicant provided guidance to
  appropriately identify and confirm whether aging effects had occurred prior to and during
  the period of extended operation.
.3 B2.1.7 Flow-Accelerated Corrosion (XI.M17)
  This was an existing program, consistent with the GALL Report, credited with managing
  aging effects of wall thinning on the internal surfaces of carbon or low alloy steel piping,
  elbows, reducers, expanders, and valve bodies that contain high energy fluids (both
  single phase and two phases). This program managed aging effects by performing
  analyses to determine critical locations, conducting baseline and follow-up inspections at
  these critical locations, and taking corrective actions as necessary. The applicant used
  ultrasonic, visual, or other approved testing techniques capable of detecting wall
  thinning. The program implemented the guidelines in Electric Power Research
  Institute NSAC-202L, Recommendations for an Effective Flow-Accelerated Corrosion
  Program, Revision 3. Where applicable, the analyses to determine critical locations
  were performed using CHECWORKS', an industry standard predictive code that used
  the implementation guidance of NSAC-202L.
  The team reviewed license renewal documents, the aging management program
  evaluation report, implementing procedures, calculations, system susceptibility
  evaluation drawings, outage reports, program health reports, and corrective action
  documents. The team interviewed the program owner and license renewal project
  personnel. The team reviewed the flow-accelerated corrosion database for a selected
  sample of monitoring points.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in the affected systems. The team concluded that, if implemented as
  described, the applicant provided guidance to appropriately identify and confirm whether
  aging effects had occurred prior to and during the period of extended operation.
                                        - 17 -                                      Enclosure
 
.4 B2.1.10 Open-Cycle Cooling Water System (XI.M20)
  This was an existing program, consistent with the GALL Report after enhancement,
  credited with managing the aging effects related to loss of material, reduction of heat
  transfer, cracking, blistering, change in color, and hardening and loss of strength for
  components exposed to raw water. The applicant managed the aging effects through
  periodic inspection and surveillance tests combined with chemistry controls and cleaning
  to minimize fouling, loss of material, and corrosion. The program specified performance
  testing of the component cooling water heat exchangers, visual inspections of the other
  safety-related heat exchangers, and periodic inspections to monitor aging effects on
  other structures, systems and components. The existing program implemented the
  recommendations of Generic Letter 89-13, Service Water System Problems Affecting
  Safety-Related Equipment, dated July 18, 1989.
  This program monitored aging effects in components serviced by the essential service
  water system and heat exchangers and other components in other systems serviced by
  the essential service water system. The safety-related heat exchangers cooled by
  essential service water included the: component cooling water heat exchangers,
  containment coolers, diesel generator heat exchangers, safety injection pump room
  coolers, spent fuel pool pump room coolers, residual heat removal pump room coolers,
  containment spray pump room coolers, centrifugal charging pump room coolers,
  component cooling water pump room coolers, auxiliary feedwater pump room coolers,
  control room air conditioning condensers, Class 1E switchgear air-conditioning
  condensers, and electrical penetration room coolers.
  The team reviewed the aging management program evaluation report, implementing
  procedures, and relevant corrective action documents. The team reviewed service
  water and ultimate heat sink chemistry data, component cooling water heat exchanger
  test results, essential service water flow balance test results, nondestructive testing
  results, room cooler and air conditioning condenser heat exchanger inspection results,
  tube plugging limits and tube plug maps, and corrosion coupon trend data. In addition,
  the team interviewed the program manager and walked down accessible portions of the
  essential service water system, the ultimate heat sink spray ponds, and the essential
  service water pump and mechanical cooling tower structures. The team determined
  from the data and trend graphs that the applicant monitored and maintained proper
  controls to minimize fouling. The team determined that the applicant maintained
  effective controls of the design and heat transfer capability in the heat exchangers.
  In response to site-specific operating experience, the applicant had implemented
  corrective actions, which resulted in improving the material condition of the essential
  service water system. Specifically, the applicant had:
      *  Replaced the containment coolers that had been blocked by debris with a
          different design that allowed for tube cleaning,
      *  Replaced all 4-inch diameter and smaller carbon steel piping and components
          with stainless steel to correct low flow and leakage issues,
                                        - 18 -                                      Enclosure
 
      *  Replaced the admiralty brass emergency diesel generator jacket water, lube oil
          cooler, and intercoolers with stainless steel to correct for loss of material in the
          tubes,
      *  Replaced 5 of 16 safety-related admiralty brass room coolers with stainless steel
          room coolers because aging issues caused poor performance. The applicant
          has a long term plan to replace the remaining 11 room coolers during upcoming
          outages with the final two room coolers replaced by 2022, and
      *  Replaced the buried essential service water piping with high-density polyethylene
          (HDPE) piping, as a result of significant leakage resulting from microbiological
          induced corrosion.
  The team reviewed additional site specific operating experience that identified erosion
  from cavitation had occurred at the raised face flanges going into the safety-related room
  coolers. Because this was an identified aging effect caused by erosion, the team
  evaluated the controls that existed to evaluate additional erosion of the carbon steel
  flanges. The team determined that the coolers were scheduled to be replaced over the
  next ten years. Further, the team determined that the heat exchanger inspection form
  required taking measurements of the flange face. The team concluded that the applicant
  had implemented sufficient controls that will continue to detect erosion prior to leakage
  through the flange.
  The applicant specified that procedures will be enhanced to include polymeric material
  inspection requirements, parameters monitored, and acceptance criteria. The applicant
  specified this examination would be consistent with the examinations performed when
  inspecting polymeric materials in the Internal Surfaces in Miscellaneous Piping and
  Ducting Components program. The team verified that the proposed changes to
  Procedure EDP-ZZ-01121, Raw Water Systems Predictive Performance Program,
  Revision 14, provided appropriate guidance to evaluate polymeric material.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in components cooled by open-cycle cooling water. The team
  concluded that, if implemented as described with the enhancement, the applicant
  provided guidance to appropriately identify and address aging effects during the period
  of extended operation.
.5 B2.1.11 Closed Treated Water Systems (XI.M21A)
  This was an existing program, consistent with the GALL Report after enhancement,
  credited with managing loss of material, cracking, and reduction of heat transfer for
  components in the closed-cycle cooling water systems. The program included
  monitoring and control of corrosion inhibitor and chemistry parameters consistent with
  the guidance of Electric Power Research Institute TR-107396, Closed Cooling Water
  Chemistry Guideline, Revision 1. Also, the applicant planned to conduct periodic
  inspections to determine the presence or extent of corrosion, fouling, and/or cracking.
  The program uses four chemistry control programs: molybdate with tolyltriazole
  (component cooling and chilled water systems), ethylene glycol (plant heating steam),
                                      - 19 -                                          Enclosure
 
  nitrite control with tolyltriazole (diesel generator jacket water), or diesel coolant additive
  and ethylene glycol (fire protection diesel jacket water). The systems included in this
  program were diesel generator jacket water, component cooling water, chilled water, and
  plant heating.
  The team reviewed implementing procedures, corrosion rate data, and chemistry data
  for the monitored systems. The team walked down the piping and components in the
  closed treated water systems and interviewed the system engineer. The team
  determined from the data and trend graphs reviewed that the applicant appropriately
  monitored for heat transfer and loss of material in the in-scope systems. The team
  verified that the heat exchangers had very few plugged tubes and determined that the
  applicant had replaced the admiralty brass heat exchangers for the safety-related diesel
  generator with stainless steel heat exchangers.
  The applicant planned to enhance this program to include visual inspections of
  component surfaces. The visual inspections will: (1) include representative samples of
  each combination of material and water treatment program at least every 10 years or
  opportunistically when consistent with sample requirements; (2) be conducted and
  evaluated consistent with American Society of Mechanical Engineers Code inspections,
  industry standards, or a plant-specific inspection procedure by personnel qualified to
  detect aging; (3) include additional examinations if adverse conditions were found;
  and (4) determine the extent of cracking, loss of material and fouling, which would serve
  as a leading indicator of the condition of the interior of piping components otherwise
  inaccessible for visual inspection.
  The team compared the draft inspection procedure to the aging management program
  evaluation report that specified visual inspection requirements. The team identified
  several statements between the documents that did not agree. Following discussions
  with the applicant regarding these discrepancies, the applicant reviewed the comments
  and made changes to both the draft inspection procedure and the aging management
  program evaluation report. The team verified that the changes made in each document
  corrected the identified discrepancies. Further, the applicant tracked these changes
  under Action Item RI202. The applicant documented the changes in Enclosure 3,
  Regional Inspection Item Updates, in Letter ULNRC-05923.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in the affected systems. The team concluded that, if implemented as
  described with the enhancement, the applicant provided guidance to appropriately
  identify and address whether aging effects had occurred during the period of extended
  operation.
.6 B2.1.13 Fire Protection (XI.M26)
  This was an existing program, consistent with the GALL Report after enhancement,
  credited with managing loss of material of fire rated doors, fire dampers, and the halon
  system; concrete cracking, spalling, and loss of material of fire barrier walls, ceilings,
  and floors; and increased hardness, shrinkage, and loss of strength of fire barrier
                                          - 20 -                                        Enclosure
 
penetration seals. This program was comprised of tests and inspections that followed
the applicable National Fire Protection Association recommendations.
The team reviewed license renewal documents, the aging management program
evaluation report, program enhancements, implementing procedures (including the
proposed changes), program health reports, and corrective actions documents. The
team interviewed fire protection personnel and license renewal project personnel. The
team inspected various fire rated doors, fire barriers, fire dampers, fire penetration seals,
and the halon system to observe the physical condition of the fire protection features and
to assess the effectiveness of the existing program.
The fire protection program managed the effects of aging through visual inspections of
fire rated doors, fire barriers (including walls, coatings, and wraps), fire dampers, fire
penetration seals, and the halon system. The applicant performed visual inspections
and functional tests for the fire doors at least once every 18 months. The applicant
performed visual inspections of the fire barriers within the scope of license renewal every
18 months. The applicant visually inspected at least 10 percent of the fire dampers and
each type of penetration seal every 18 months.
The applicant planned to enhance the program to require visual inspections every six
months of the halon system to inspect for corrosion. Currently, the applicant conducted
a functional test of the halon system every 18 months, in accordance with the approved
fire protection program. The team identified no concerns with this enhancement.
The team identified two concerns with the fire protection program. The first concern
involved a difference between the guidance in the GALL Report and the aging
management program evaluation report associated with the inspection of fire penetration
seals. The GALL Report stated that any sign of degradation detected in the inspection
sample should lead to an increase in inspection scope. The applicants aging
management program provided a conditional statement that allowed an engineering
evaluation prior to an increase in inspection scope. If the engineering evaluation
concluded that the penetration seal was still capable of performing its intended function,
then the inspection scope did not need to be increased. The applicant changed the
aging management program evaluation report to make it fully consistent with the GALL
Report. Further, the applicant tracked these changes under Action Item RI088. The
applicant documented the changes in Letter ULNRC-05923, Enclosure 3.
The second concern involved the procedure for inspecting fire barriers. During the
system walk down, the team noticed that several portions of the Darmat fire barrier were
not easily accessible to inspectors standing on the ground, and ladders or scaffolding
may be necessary for inspectors to observe the effects of aging on the fire barrier. The
team discussed this issue with fire protection personnel and determined that the
program inspected accessible portions of the fire barrier as prescribed by the approved
fire protection program. The applicant documented the need to revise the fire procedure
in Callaway Action Request 2012-07533, which documented the need to inspect the
entire Darmat fire barrier for the presence of aging effects.
The team concluded that, overall, the applicant had performed appropriate evaluations
and considered pertinent industry experience and plant operating history to determine
                                      - 21 -                                      Enclosure
 
  the effects of aging in the affected systems. The team concluded that, if implemented as
  described with the enhancement and changes, the applicant provided guidance to
  appropriately identify and confirm whether aging effects had occurred prior to the period
  of extended operation.
.7 B2.1.14 Fire Water System (XI.M27)
  This program was an existing program, consistent with the GALL Report after
  enhancement, credited with managing loss of material for water-based fire protection
  systems consisting of aboveground, buried, and underground: piping, fittings, valves,
  fire pump casings, sprinklers, nozzles, hydrants, hose stations, standpipes, and water
  storage tanks. This program used periodic fire main and hydrant inspections and
  flushing, sprinkler inspections, function tests, and flow tests in accordance with the
  National Fire Protection Association standards to ensure the systems remained capable
  of performing their intended function. The applicant maintained and monitored the fire
  protection system at the required normal operating pressure such that a loss of system
  pressure would be immediately detected and corrective actions initiated.
  The team reviewed license renewal documents, the aging management program
  evaluation report, program enhancements, program exceptions, implementing
  procedures and procedure markups, program health reports, and corrective action
  documents. The team interviewed fire protection personnel and license renewal project
  personnel. The team walked down portions of the fire water system, including the fire
  pumps and associated piping.
  The applicant identified six enhancements needed to ensure this program was
  consistent with the GALL Report. The applicant planned to enhance the implementing
  procedures to: (1) include non-intrusive pipe wall thickness examinations on fire water
  piping or, as an alternative, perform internal inspections on accessible exposed portions
  of fire water piping during plant maintenance activities; (2) replace sprinkler heads prior
  to 50 years in service or have a recognized testing laboratory field-service test a
  representative sample in accordance with National Fire Protection Association 25,
  Standard for the Inspection, Testing, and Maintenance of Water-Based Fire Protection
  Systems; (3) review and evaluate trends in flow parameters recorded during flow tests;
  (4) perform annual hydrant flow testing in accordance with National Fire Protection
  Association 25; (5) perform annual hydrostatic testing of the fire brigade hoses;
  and (6) recoat the internal surfaces of the fire water storage tanks. The team reviewed
  the procedure markups and confirmed that the applicant had included each of the
  enhancements in the procedures.
  The applicant took two exceptions to the GALL Report. First, the applicant performed
  power block hose station gasket inspections at least every 18 months as specified in the
  approved fire protection program, rather than annually as specified in the GALL Report
  and National Fire Protection Association 25. Second, the GALL Report required annual
  testing of fire hydrant hoses. However, the applicant hydrostatically tested fire hoses at
  interior fire hose stations five years from installation and every three years thereafter, as
  specified in the approved fire protection program. The team identified no concerns with
  these exceptions because this meets the industry standard surveillance frequency and
  meets the requirements in the approved fire protection program.
                                        - 22 -                                      Enclosure
 
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging in the affected systems. The team concluded that, if implemented as
  described with the enhancements and exceptions, the applicant provided guidance to
  appropriately identify and address aging effects during the period of extended operation.
.8 B2.1.16 Fuel Oil Chemistry (XI.M30)
  This was an existing program, consistent with the GALL Report after enhancement,
  credited for managing the loss of material on the internal surface of diesel fuel oil
  storage tanks through monitoring and control of fuel oil quality. The fuel oil tanks
  included the emergency fuel oil storage and fuel oil day tanks for the emergency diesel
  generators, the diesel-driven fire pumps fuel oil day tanks and the security system diesel
  generator fuel oil day tank.
  The team reviewed the aging management program evaluation report, implementing
  procedures and procedure mark-ups, and relevant corrective action documents. The
  team interviewed plant personnel and walked down accessible portions of the diesel
  generators, diesel generator day tanks, diesel-driven fire pump day tanks, and the
  security system diesel day tank. From a review of plant operating experience, the team
  determined that no additional aging effects had occurred that would require modifying
  this aging management program. The team noted that the applicant utilizes other onsite
  fuel oil storage tanks as a holding tank for fuel used to refill the diesel-driven fire pump
  and security system diesel tanks.
  The applicant identified numerous enhancements to procedures to ensure consistency
  with the GALL Report. Specifically, the applicant developed draft procedures that
  included requirements to:
      *    Periodically drain water from the emergency fuel oil storage tank, the two diesel
            fire pump fuel oil day tanks, and the security diesel generator fuel oil day tank;
      *    Add biocide to the two diesel fire pump fuel oil day tanks and the security diesel
            generator fuel oil day tank, if required from sample results;
      *    Include draining, cleaning, and inspection of the emergency fuel oil day tanks;
      *    Sample periodically for water and sediment in the emergency fuel oil day tanks
            and security diesel generator fuel oil day tank;
      *    Evaluate particulate concentrations during the periodic sampling of the
            emergency fuel oil storage tanks, the two diesel fire pump fuel oil day tanks, and
            the security diesel generator fuel oil day tank;
      *    Determine microbial activity concentrations during the periodic sampling of the
            emergency fuel oil storage tanks, emergency fuel oil day tanks, two diesel fire
            pump fuel oil day tanks, and security diesel generator fuel oil day tank;
                                        - 23 -                                          Enclosure
 
    *  Sample new fuel oil for water and sediment prior to introduction into the security
        diesel generator fuel oil day tank and diesel fire pump fuel oil day tanks;
    *  Perform periodic volumetric examination of the emergency fuel oil storage tanks
        and day tanks if evidence of tank degradation is observed during the visual
        inspection;
    *  Perform periodic volumetric examinations on the external surface of the diesel
        fire pump fuel oil day tanks and security diesel generator fuel oil day;
    *  Trend at least quarterly the water, biological activity, and particulate
        concentrations for the emergency fuel oil day tanks, diesel fire pump fuel oil day
        tanks, and security diesel generator fuel oil day tank; and
    *  Remove immediately accumulated water when discovered in the emergency fuel
        oil day tanks, diesel fire pump fuel oil day tanks, and security diesel generator
        fuel oil day tank.
The team reviewed the four procedure markups that included the requirements
described in the previous paragraph. The team determined that the applicant had not
included all the enhancements, as described. During discussions with the applicant, the
applicant agreed with the identified discrepancies in the procedure markups and initiated
corrections. The team verified that the applicant had made appropriate changes to
include the missing requirements in the draft procedures prior to the end of the
inspection.
From review of site-specific operating experience, the team identified that blisters inside
the Train A emergency fuel oil storage tank could have resulted from an aging
mechanism, which would require volumetric examination of the tank. Specifically, the
team questioned the applicant about the cause, location and number of dime-to-nickel
sized blisters inside the Train A emergency fuel oil storage tank. The applicant could not
identify the number or location of the dime-to-nickel sized blisters inside the Train A
emergency fuel oil storage tank. From anecdotal stories, the applicant indicated that the
number and size of the blisters had not changed. However, the inspections indicated
that the coating had good adhesion around the blisters. The team reviewed the
documented inspections of the tank and determined that insufficient information was
recorded other than the existence of the dime-to-nickel sized blisters.
The blisters had been present in the tank since at least 1990 as documented in an
inspection. Because of the lack of information related to the cause of the blisters, the
number of blisters and whether the blisters had increased over time, the team requested
that the applicant remove all the blisters, evaluate the condition of the underlying metal,
remediate the blisters, and implement the appropriate aging management actions. If the
blisters resulted from an adhesion problem without any evidence of aging effects, then a
visual inspection every 10 years would continue to be appropriate. However, if an aging
effect were to be identified, then the applicant would need to volumetrically examine the
tank. The applicant changed the aging management program evaluation report to make
                                    - 24 -                                        Enclosure
 
  it fully consistent with the GALL Report. Further, the applicant tracked these changes
  under Action Item RI178. The applicant documented the changes in
  Letter ULNRC-05923, Enclosure 3. Also, the applicant revised the license renewal
  application to indicate they would inspect and repair the blisters prior to entering the
  period of extended operation. The team confirmed the applicant would perform the
  next 10-year inspection prior to entering the period of extended operation.
  The team concluded that the applicant had, generally, performed appropriate
  evaluations and considered pertinent industry experience and plant operating history to
  determine the effects of aging on internal surfaces in those systems containing diesel
  fuel oil. The team concluded that, if implemented as described including the
  enhancements and corrective actions, the applicant provided guidance to appropriately
  identify and address aging effects during the period of extended operation.
.9 B2.1.24 Lubricating Oil Analysis (XI.M39)
  This was an existing program, consistent with the GALL Report after enhancement,
  credited with managing oil environments in order to prevent loss of material and
  reduction of heat transfer. The program maintained lubricating oil contaminants
  (primarily water and particulates) within acceptable limits, thereby preserving an
  environment that was not conducive to loss of material or reduction of heat transfer. The
  applicant sampled, analyzed, and trended results for numerous systems, as listed in this
  program, to provide an early indication of adverse equipment condition.
  The team reviewed the license renewal application, aging management program
  evaluation report, plant operating experience, program and implementing procedures,
  and relevant condition reports. The team interviewed license renewal and plant
  personnel, and walked down the accessible lubricating oil components of the Train A
  emergency diesel generator and diesel-driven fire pumps. The team sampled oil
  measurement results and trending within the lubricating oil database and reviewed oil
  analysis program reports.
  The applicant identified numerous enhancements to procedures to ensure consistency
  with the GALL Report. Specifically, the applicant described that procedures would be
  enhanced to: (1) indicate that lubricating oil contaminants were maintained within
  acceptable limits, thereby preserving an environment that was not conducive to loss of
  material or reduction of heat transfer; (2) state the testing standards for water content
  and particle count; and (3) state that phase separated water in any amount was not
  acceptable. The team confirmed that the markup for Procedure EDP-ZZ-01126,
  Lubrication Predictive Maintenance Program, Revision 11, incorporated each of these
  enhancements.
  The team concluded that the applicant had performed appropriate evaluations and
  considered pertinent industry experience and plant operating history to determine the
  effects of aging on piping and component surfaces in lubricating and hydraulic oil
  systems. The team concluded that, if implemented as described including
  enhancements, the applicant provided guidance to appropriately identify and address
  aging effects during the period of extended operation.
                                      - 25 -                                        Enclosure
 
.10 B2.1.30 Masonry Walls (XI.S5)
    This was an existing program, consistent with the GALL Report, credited with managing
    cracking of masonry walls through visual inspections. This program was integrated into
    and administered as part of the structures monitoring program, which implements the
    maintenance rule structures inspections. The applicant had based this program on
    guidance provided in Inspection and Enforcement Bulletin 80-11, Masonry Wall
    Design, and Information Notice 87-67, Lessons Learned from Regional Inspections of
    Licensee Actions in Response to NRC IE Bulletin 80-11. The team confirmed that the
    applicant had masonry walls in the turbine building, auxiliary building, control building,
    and essential service water pump house. The applicant performed the masonry wall
    inspections at intervals of no more than five years.
    The team reviewed license renewal documents, the aging management program
    evaluation report, program procedures, corrective action documents, and masonry wall
    drawings. The team discussed the program with civil engineers and visually examined
    accessible masonry block walls to assess their condition. The team determined that the
    applicant used the guidance for masonry walls from the maintenance rule structures
    monitoring program to perform the visual inspections. The team verified that the
    applicant had safety-related masonry block walls. The team concluded that the masonry
    walls were in good condition and had been constructed in accordance with the design
    drawings.
    The team concluded that the applicant had performed appropriate evaluations and
    considered pertinent industry experience and plant operating history to determine the
    effects of aging in the affected systems. The team concluded that, if implemented as
    described, the applicant provided guidance to appropriately identify and address aging
    effects during the period of extended operation.
.11 B2.1.31 Structures Monitoring (XI.S6)
    This was an existing program, consistent with the GALL Report after enhancement,
    credited with managing loss of material, cracking, and change in material properties of
    structures and structural components, including structural bolting, through visual
    inspections. The applicant implemented the structures monitoring requirements of
    10 CFR 50.65, Maintenance Rule, and used guidance provided in the American
    Concrete Institute Standards 201.1R, Guide for Conducting a Visual Inspection of
    Concrete in Service, and 349.3R, Evaluation of Existing Nuclear Safety-Related
    Concrete Structures. This program provided inspection guidelines for concrete
    elements, structural steel, roof systems, masonry walls and metal siding, including all
    masonry walls and water control structures within the scope of license renewal. The
    program monitored settlement for each major structure and inspects non-code
    mechanical and electrical supports. The inspection of all structural components,
    including masonry walls and water-control structures, were performed at intervals of no
    more than five years.
    The team reviewed license renewal documents, the aging management program
    evaluation report, procedures, corrective action documents, work orders, and
    engineering requests. The team interviewed the program engineers and discussed
                                        - 26 -                                        Enclosure
 
program enhancements, existing program procedures, and qualifications of inspection
personnel. The team performed walk downs with civil engineers involved with
performing the inspections and visually examined a sample of structures and structural
components in the control and auxiliary buildings. The team independently walked down
areas in the auxiliary and control buildings. The team verified that the applicant
maintained records and recorded structural indications and deficiencies in a manner
such that future inspectors could compare the inspection results.
This program required numerous enhancements to be consistent with the GALL Report.
Specifically, the applicant identified enhancements to:
    *  Inspect penetrations, transmission towers, electrical conduits, raceways, cable
        trays, electrical cabinets/enclosures, and associated anchorages, and to
        complete a baseline inspection of these components prior to December 31, 2017;
    *  Include the main access facility into the program scope;
    *  Monitor groundwater for pH, chlorides and sulfates, and every five years test at
        least two samples and evaluate the results to assess the impact on below grade
        structures;
    *  Specify, for replacement bolts, that the bolt material, installation torque/tension,
        and use of lubricants and sealants met required industry guidelines;
    *  Specify preventive actions for storage, lubrication, and stress corrosion cracking
        potential discussed in specified industry standards;
    *  Specify inspections of penetrations;
    *  Require that inspectors meet the qualifications listed in American Concrete
        Institute 349.3R-96;
    *  Quantify acceptance criteria and critical parameters for monitoring degradation,
        including guidance for unacceptable conditions;
    *  Incorporate applicable industry codes, standards and guidelines for acceptance
        criteria; and
    *  Require an engineer familiar with the seismic design of the plant, including the
        evaluation of the seismic isolation function, to evaluate degradation, obstruction
        or questionable material and determine the corrective actions.
The team confirmed that the mark-up for Procedure ESP-ZZ-01013, Maintenance Rule
Structures Inspection, Revision 6 included the enhancements.
The team concluded that the applicant had performed appropriate evaluations and
considered pertinent industry experience and plant operating history to determine the
effects of aging in the affected systems. The team concluded that, if implemented as
                                    - 27 -                                        Enclosure
 
    described with enhancements, the applicant provided guidance to appropriately identify
    and address aging effects during the period of extended operation.
.12 B2.1.32 RG 1.127, Inspection of Water-Control Structures Associated with Nuclear
    Power Plants (XI.S7)
    This was an existing program, consistent with the GALL Report, credited with managing
    loss of bond, loss of material (spalling), cracking, increase in porosity and permeability,
    loss of strength, change in material properties, and loss of form in water-control
    structures through visual inspections. The existing program was developed based on
    guidance provided in Regulatory Guide 1.127, Inspection of Water-Control Structures
    Associated with Nuclear Power Plants, Revision 1. This program also included
    structural steel and structural bolting associated with water-control structures. The
    applicant included these program requirements in their structures monitoring program,
    which implements the maintenance rule structures inspections. Water-control structures
    within the scope of the program included the essential service water pump house, the
    essential service water supply lines yard vault, the ultimate heat sink cooling tower and
    retention pond, and the submerged discharge structure.
    The team reviewed license renewal documents, the aging management program
    evaluation report, program procedures, corrective action documents, and engineering
    requests. The team interviewed the program engineers and discussed the results of the
    most recent inspection, existing program procedures, and qualifications of inspection
    personnel. The team performed walk downs with engineers involved with performing the
    inspections and visually examined a sample of structures and structural components
    including the essential service water system pump house, the ultimate heat sink cooling
    tower, and the ultimate heat sink retention pond.
    The applicant performed in-service and structural inspections of the ultimate heat sink
    retention pond and its associated structures to evaluate their structural safety and
    operational adequacy at five year intervals. The applicant performed algae treatment
    and riprap inspections along the ultimate heat sink retention pond and monitored
    underwater benchmarks for settlement of the Category 1 structures. During walk downs,
    the team did not see any algae, misplaced riprap, or problems with the structures.
    The team concluded that the applicant had performed appropriate evaluations and
    considered pertinent industry experience and plant operating history to determine the
    effects of aging in the affected systems. The team concluded that, if implemented as
    described, the applicant provided guidance to appropriately identify and address aging
    effects during the period of extended operation.
.13 B2.1.33 Protective Coating Monitoring and Maintenance Program (XI.S8)
    This was an existing program, consistent with the GALL Report after enhancement,
    credited with managing loss of coating integrity of Service Level I coatings inside
    containment. The program included visual inspections of accessible coatings that
    covered steel and concrete surfaces inside containment (e.g., steel liner, steel shell,
    supports, concrete surfaces, and penetrations).
                                        - 28 -                                      Enclosure
 
    The team reviewed license renewal documents, the aging management program
    evaluation report, implementing procedures and procedure mark-ups, corrective action
    documents, plant operating experience, and inspection results. The team searched the
    corrective action program database for relevant corrective action requests. The team
    interviewed the program owner and license renewal project personnel.
    The program will be enhanced to revise program documents prior to entering the period
    of extended operation to specify: (1) monitoring or inspecting for visible defects, such as
    blistering, cracking, flaking, peeling, rusting, and physical damage; (2) meeting the
    requirements of American Society of Testing Materials Standard D5163-08,
    Establishing a Program for Condition Assessment of Coating Service Level I Coating
    Systems in Nuclear Power Plants, for inspection frequencies, plans and methods,
    personnel qualifications, and inspection equipment; (3) reviewing the previous two
    monitoring reports to prioritize areas for repair or to allow postponing to a future outage
    with surveillance in the interim period; (4) characterizing, documenting, and testing
    consistent with American Society of Testing Materials Standard D5163-08, Sections 10.2
    through 10.4; (5) evaluating inspection results by a coating specialist who summarizes
    the findings and recommendations for future surveillance or repair; and (6) requiring that
    inspection reports prioritize repair areas as either needing repair during the same outage
    or postponing to future outages with surveillance in the interim period.
    The applicant took an exception to the GALL Report so that they only implemented
    those activities associated with Service Level I coatings specified in Regulatory
    Guide 1.54, Service Level I, II, and III Protective Coatings Applied to Nuclear Power
    Plants, Revision 2. The team confirmed that the applicant implemented their program
    consistent with the requirements of American Society of Testing Materials
    Standard D5163-08. Further, the team confirmed that the applicant had included these
    inspection requirements, as well as the enhancements in the mark-up of
    Procedure EDP-ZZ-03000, Containment Building Coatings, Revision 17.
    The team concluded that the applicant had performed appropriate evaluations and
    considered pertinent industry experience and plant operating history to determine the
    effects of aging in the affected systems. The team concluded that, if implemented as
    described with the enhancements and exceptions, the applicant provided guidance to
    appropriately identify and address aging effects during the period of extended operation.
.14 B2.1.34 Insulation Materials for Electrical Cables and Connections Not Subject to
    10 CFR 50.49 Environmental Qualification Requirements (XI.E1)
    This was an existing program, consistent with the GALL Report after enhancement,
    credited with managing reduced insulation resistance in non-environmentally qualified
    electrical cables, connections and terminal blocks in adverse localized environments.
    Visual inspections would look for embrittlement, melting, cracking, swelling, surface
    contamination, or discoloration that could indicate incipient conductor insulation aging
    from temperature, radiation, or moisture. The applicant will complete the first inspection
    prior to entering the period of extended operation and at least once every ten years
    thereafter.
    The team reviewed license renewal documents, the aging management program
                                        - 29 -                                        Enclosure
 
    evaluation report, corrective action documents, plant operating experience and draft
    Procedure EDP-ZZ-07001, Cable Management Program, Revision 0. The applicant
    defined adverse localized environments as a limited plant area that had conditions
    where temperature, radiation, or moisture may exceed the design conditions. The team
    walked down selected plant areas and looked for adverse localized environments. The
    team interviewed design engineers and project personnel to determine their plans for
    conducting these aging effects evaluations. The applicant identified the plant areas for
    evaluation of adverse localized environments in the aging management program
    evaluation report for this program and draft Procedure EDP-ZZ-07001.
    The program required two enhancements to be consistent with the GALL Report. The
    applicant included information in their draft procedure that specified (1) including all
    accessible in-scope cables in any adverse localized environment and (2) conducting an
    engineering evaluation for any visual indications of cable insulation surface anomalies.
    The applicant used technical information contained within SAND 96-0344, Aging
    Management Guideline for Commercial Nuclear Projects - Electrical Cable and
    Terminations, and Electric Power Research Institute TR-1013475, Plant Support
    Engineering: License Renewal Electrical Handbook, to determine the service limitations
    of the cable, connection and terminal block insulating materials. The applicant used
    SAND 96-0344 and Electric Power Research Institute TR-109619, Guideline for the
    Management of Adverse Localized Equipment Environments, to develop guidance for
    visual inspection techniques of cables, connections and terminal blocks for aging.
    The team concluded that the applicant performed appropriate evaluations and
    considered pertinent industry experience and plant operating history to determine the
    effects of aging in cables exposed to adverse localized environments. The team
    concluded that, if implemented as described including the enhancements, the applicant
    provided guidance to appropriately identify and address aging effects during the period
    of extended operation.
.15 B2.1.35 Insulation Materials for Electrical Cables and Connections Not Subject to
    10 CFR 50.49 Environmental Qualification Requirements Used in Instrumentation
    Circuits (XI.E2)
    This was an existing program, consistent with the GALL Report after enhancement,
    credited with managing reduced insulation resistance for cables and connections used in
    sensitive instrumentation circuits within the ex-core neutron monitoring system. This
    program would provide reasonable assurance that the intended function of
    instrumentation circuit cables and connections exposed to adverse localized
    environments caused by temperature, radiation, or moisture were maintained consistent
    with the current licensing basis. When instruments were found out of calibration, the
    applicant performed troubleshooting on the loop, including the instrumentation cable and
    connections. The applicant committed to complete a review of surveillance results prior
    to the period of extended operation and every ten years thereafter.
    The team reviewed license renewal documents, the aging management program
    evaluation report, corrective action documents, industry operating experience, and
    surveillance test results. The team walked down accessible in-scope cables and
    interviewed the responsible system engineer and license renewal personnel. The
                                        - 30 -                                        Enclosure
 
    program required three enhancements to be consistent with the GALL Report. The
    applicant planned to: (1) identify the scope of cables requiring aging management,
    (2) require engineering review of surveillance results every ten years, and (3) ensure
    corrective actions were initiated when surveillance results did not meet acceptance
    criteria, which included performing an engineering evaluation and assessing whether the
    cable testing frequency needed to be increased. The team verified that draft
    Procedure EDP-ZZ-07001 included each of these enhancements. However, the team
    determined the procedure was difficult to follow and discern the requirements specifically
    related to each of the electrical aging management programs. The applicant indicated
    that the planned revisions to the cable management procedure included clarifying the
    requirements associated with each of the aging management programs.
    The team concluded that the applicant performed appropriate evaluations and
    considered pertinent industry experience and plant operating history to determine the
    effects of aging. The team concluded that, if implemented as described with the
    enhancements, the applicant provided guidance to appropriately identify and address
    aging effects during the period of extended operation.
.16 B2.1.36 Inaccessible Power Cables Not Subject to 10 CFR 50.49 Environmental
    Qualification Requirements (XI.E3)
    This was an existing program, consistent with the GALL Report after enhancement,
    credited with managing aging caused by reduced insulation resistance. This reduced
    insulation resistance could lead to electrical failure of in-scope inaccessible power
    cables (greater than or equal to 400 volts) exposed to wetting or submergence caused
    by significant moisture. Significant moisture was defined as periodic exposures to
    moisture that lasted more than a few days. The applicant planned to manage the aging
    effects by periodically inspecting for water in cable manholes and conduits and by
    testing the inaccessible medium-voltage electrical cables. The applicant would test the
    cables prior to the period of extended operations and once every 6 years.
    The team reviewed license renewal documents, the aging management program
    evaluation report, the draft implementing procedure, corrective action documents, plant
    operating experience, and work orders. The team interviewed plant personnel and
    walked down several underground cable manholes. The team also reviewed the
    dewatering program for performing annual inspection of the in-scope cables and duct
    banks for water intrusion. During the review of draft Procedure EDP-ZZ-07001, the team
    identified an apparent conflict in the cables identified as underground and the assigned
    aging management program. The applicant included this apparent conflict in their list of
    improvements required for this draft aging management program procedure. The team
    concluded this was an appropriate planned corrective action.
    The applicant identified numerous enhancements required to ensure consistency with
    the GALL Report. Specifically, the applicant developed draft procedures that included
    requirements to: (1) identify the inaccessible medium voltage power cables (greater
    than or equal to 400 volts); (2) inspect periodically manholes, pits, and duct banks to
    confirm cables were not submerged, cables/splices and cable support structures were
    intact, and dewatering/drainage systems and alarms operated properly; (3) inspect at
    least annually based on water accumulation and after event driven occurrences (e.g.,
                                        - 31 -                                      Enclosure
 
    heavy rain or flooding); (4) test in-scope power cables at least once every six years and
    adjust based on test results and operating experience; (5) require comparing test results
    to previous test results to identify the rate of cable degradation; (6) define acceptance
    criteria for cable testing prior to each test; and (7) require an engineering evaluation
    when the acceptance criteria were not met.
    The team verified that the applicant incorporated these enhancements into draft
    Procedure EDP-ZZ-07001. The team determined that the applicant conducted the
    inspections using preventive maintenance activities. Whenever plant personnel found
    water in manholes, they measured and sampled the water prior to pumping the water
    from the manhole. The applicant described that testing could be a mix of proven testing
    methods such as dielectric loss (dissipation factor/power factor), AC voltage withstand,
    partial discharge, step voltage, time domain reflectometry, insulation resistance and
    polarization index, line resonance analysis, or other state-of-the-art testing. If the
    applicant identified anomalies during the testing, they would take actions in accordance
    with the corrective action program to correct the condition and adjust the frequency of
    testing.
    The applicant had determined that safety-related cables in Manhole MH-01 were
    submerged while completing inspections in response to Generic Letter 2007-01,
    Inaccessible or Underground Power Cable Failures that Disable Accident Mitigation
    Systems or Cause Plant Transients, dated February 7, 2007. The applicant had had no
    failures of medium-voltage cables because of water treeing; however, the applicant
    increased the frequency of inspection of Manhole MH-01 for water intrusion from
    36 to 6 months after the repairs and modification of the manhole, as specified in
    Callaway Action Request 201101616. The applicant was establishing a dewatering
    program that would install sump pumps in the manholes. The applicant had developed
    preventive maintenance requirements to monitor, inspect and repair the dewatering
    systems. The team did not identify any water in the manholes that had been identified
    as susceptible to water intrusion.
    The team concluded that the applicant had performed appropriate evaluations and
    considered pertinent industry experience and plant operating history to determine the
    effects of aging for inaccessible cables. The team concluded that, if implemented as
    described with enhancements, the applicant provided guidance to appropriately identify
    and address aging effects during the period of extended operation.
b.4 System Reviews
    The team performed a vertical slice review of selected in-scope systems to assess the
    applicants scoping, screening, and aging management reviews of selected components
    to confirm whether the applicant accurately determined the appropriate material and
    environment and correctly assigned the appropriate aging management programs.
    The team selected the following systems for review:
        *  Auxiliary feedwater
        *  Compressed air
        *  Emergency diesel generator subsystems
                                          - 32 -                                        Enclosure
 
The team interviewed the license renewal staff members and the responsible system
engineers. The team: (1) selected components and verified material specifications;
(2) walked down the systems to confirm that the applicant had properly identified
scoping boundaries (including structural and spatial interactions); (3) identified the
environments affecting the systems and had properly identified aging management
programs to manage the effects of aging for these systems; and (4) evaluated the
physical condition of the sampled systems. The team met with license renewal staff to
determine how the applicant identified the applicable aging effects and assigned the
applicable aging management program for each structure, system, or component.
The aging effects requiring management for the auxiliary feedwater system included
cracking, hardening and loss of strength, loss of material, loss of preload, reduction of
heat transfer, and wall thinning. The applicant credited the following aging management
programs for managing the identified aging effects: Bolting Integrity, Buried and
Underground Piping and Tanks, External Surfaces Monitoring of Mechanical
Components, Flow-Accelerated Corrosion, Inspection of Internal Surfaces in
Miscellaneous Piping and Ducting Components, Lubricating Oil Analysis, One-Time
Inspection, and Water Chemistry programs. The team identified no concerns related to
the boundaries, materials, environments, or aging management programs assigned for
this system.
The compressed air system provides air to the main feedwater valves, atmospheric
dump valves, and auxiliary feedwater injection valves. The aging effects requiring
management for the compressed air system include loss of material and loss of preload.
The applicant credited the following aging management programs for managing the
identified aging effects: External Surfaces Monitoring, Bolting Integrity, and Inspection of
Internal Surfaces in Miscellaneous Piping and Ducting Components programs. The
team identified no concerns related to the boundaries, materials, environments, or aging
management programs assigned for this system.
The emergency diesel generator engine system contains the following subsystems:
cooling water, starting, lubrication, and combustion air intake and exhaust. The aging
effects requiring management for the emergency diesel generator subsystems included
cracking, hardening and loss of strength, loss of material, loss of preload, and reduction
of heat transfer. The applicant credited the following aging management programs for
managing the identified aging effects: Bolting Integrity, Closed Treated Water Systems,
External Surfaces Monitoring of Mechanical Components, Fuel Oil Chemistry, Inspection
of Internal Surfaces in Miscellaneous Piping and Ducting Components, Lubricating Oil
Analysis, One-Time Inspection, and Open-Cycle Cooling Water System programs. The
team identified no concerns related to the boundaries, materials, environments, or aging
management programs assigned for this system.
For these systems, the team concluded that the physical condition of the system and the
results of tests and inspections of the various existing aging management programs
demonstrated that materials, environments, and aging effects on the selected systems
had been appropriately identified and addressed. The team concluded that the applicant
appropriately addressed the aging effects for these systems with the identified aging
management programs.
                                    - 33 -                                        Enclosure
 
  c. Overall Conclusion
    Overall based on the samples reviewed by the team, the inspection results supported a
    conclusion that there is reasonable assurance that actions have been identified and
    have been taken or will be taken to manage the effects of aging in the SSCs identified in
    the application and that the intended functions of these SSCs will be maintained in the
    period of extended operation.
40A6 Meetings, Including Exit
    The team presented inspection results to Mr. C. Reasoner, Vice President Engineering,
    and other members of the applicants staff during a preliminary exit meeting conducted
    on September 28, 2012. The applicant acknowledged the NRC inspection observations.
    The team returned all proprietary information reviewed during this inspection.
    The team presented inspection results to Ms. S. Kovaleski, Supervising Engineer, and
    other members of the applicants staff during a telephonic exit meeting conducted on
    November 7, 2012. The applicant acknowledged the NRC inspection observations.
ATTACHMENT: SUPPLEMENTAL INFORMATION
                                        - 34 -                                      Enclosure
 
                                SUPPLEMENTAL INFORMATION
                                  KEY POINTS OF CONTACT
Applicant
S. Abraham, NSSS Systems Engineer
A. Alley, Civil Design Engineer
R. Andreasen, Civil Design Engineer
A. Burgess, Lead Mechanical Engineer
S. Cantrell, Balance of Plant Systems Engineer
E. Dorge, Chemistry Engineer
N. Fisher, Electrical Systems Engineer
G. Forster, Engineering Programs Engineer
J. Howard, Chemistry Supervisor
J. Imhoff, NSSS Systems Engineer
L. Kanuckel, Manager Engineering Design
B. Kelley, Chemistry Supervisor
S. Kovaleski, Supervising Engineer
G. Kremer, Manager Engineering Programs
D. Martin, Electrical Engineer
D. Maschler, Chemistry Engineer
J. McLaughlin, NSSS Systems Engineer
S. Merciel, Site License Renewal Project Manager
S. Morris, Engineering Programs Engineer
W. Muskopf, Mechanical Engineering Projects
T. Parashar, NSSS Systems Engineer
L. Ptasznik, Engineering Programs Engineer
C. Reasoner, Vice President Engineering
B. Richardson, Safety Analysis Engineer
J. Small, Chemistry Superintendent
C. Stundebeck, Civil Design Engineer
E. Vaughn, Civil Design Engineer
STARS Center of Business
E. Blocher, License Renewal Project Manager
K. Bryant, Mechanical Lead
R. Davis, Utility Representative
J. Johnson, Structural Lead
J. Knust, Mechanical Lead
A. Saunders, Utility Representative
Division of License Renewal
J. Gavula, Senior Mechanical Engineer
R. Kalikian, Materials Engineer
E. Wong, Chemical Engineer
                                            A-1        Attachment
 
                                    DOCUMENTS REVIEWED
General
Callaway Action Requests:
201205800*              201206520*            201206557*        201206824*
*identified as a result of the inspection
Letters:
    NUMBER                                        TITLE                            DATE
                    Scoping and Screening Methodology Report Regarding the        08/06/2012
                    Callaway Plant, Unit 1, License Renewal Application
                    Aging Management Programs Audit Report Regarding the          08/09/2012
                    Callaway Plant, Unit 1, License Renewal Application
ULNRC-05877        Responses to RAI Set #1 and Amendment 4 to the Callaway      07/12/2012
                    License Renewal Application
ULNRC-05891        Responses to RAI Set #4 and Amendment 6 to the Callaway      08/09/2012
                    License Renewal Application
ULNRC-05892        Responses to RAI Set #5 and Amendment 7 to the Callaway      08/21/2012
                    License Renewal Application (with Updates to Previous RAI
                    Responses)
ULNRC-05903        Responses to RAI Set #6 and Amendment 8 to the Callaway      08/21/2012
                    License Renewal Application
ULNRC-5903          Responses To RAI Set #13 & #14 and Amendment 14 to the        10/31/2012
                    Callaway License Renewal Application
Scoping
Callaway Action Requests:
200306363              200404991              200607446          201102830
201202922              201204288
Drawings:
  NUMBER                                        TITLE                            REVISION
                                                A-2                          Attachment
 
Drawings:
  NUMBER                                        TITLE                            REVISION
M-25AE01      Hanger Location Drawing - Main Feedwater - Turbine Building          4
M-25AE03      Hanger Location Drawing - Main Feedwater - Turbine Building          1
M-25AE06      Hanger Location Drawing - Feedwater Minimum Flow to                  4
              Condenser - Turbine Building
M-25KA01      Hanger Location Drawing - Compressed Air - Auxiliary Building        0
M-29KA21      Hanger Location Drawing - Small Pipe Instrument Air System -        14
              Auxiliary Building El. 2000
M-29KA46      Hanger Location Drawing - Small Pipe N2 Backup Gas Supply -          12
              Auxiliary & Turbine Buildings
              Complete set of license renewal drawings
License Renewal:
      NUMBER                                        TITLE                      REVISION
Topical Report TR-6CW      Criterion 54.4 (a)(2)                                    3
Topical Report TR-9CW      Plant Systems and Aging Management Programs              3
New Aging Management Programs
B2.1.15 Aboveground Metallic Tanks (XI.M29)
Drawings:
NUMBER                                        TITLE                              REVISION
C-2C0901    Condensate Storage & Demineralized Water Tanks. Concrete Line &          0
            Reinforcing Sections and Details
C-2C0241    Condensate Storage & Demineralized Water Tanks. Concrete Line &          0
            Reinforcing Sections and Details, Sheet 1
                                              A-3                          Attachment
 
License Renewal:
    NUMBER                                      TITLE                            REVISION
                    License Renewal Component List for AMP XI.M29,
                    Aboveground Metallic Tanks
                    Operating Experience Summary Report, AMP XI.M29,
                    Aboveground Metallic Tanks
CW-AMP-B2.1.15      Aboveground Metallic Tanks Aging Management Program                3
                    Evaluation Report
Miscellaneous:
  NUMBER                                  TITLE                            REVISION/DATE
                Maintenance Rule Walk Down Report Structure -                  08/10/2009
                Condensate Storage Tank Foundation and Building
                Enclosure
MS-25C          Small Pipe Standard Support                                        0
Procedure        Inspections of Aboveground Metallic Tanks                          0
EDP-ZZ-XXXXX
B2.1.18 One-Time Inspection (XI.M32)
License Renewal:
    NUMBER                                      TITLE                              REVISION
                  Draft list of Callaway Material/Environment Combinations in
                  the Scope of One Time Inspection
                  License Renewal Component List for AMP XI.M32, One-Time
                  Inspection
                  Operating Experience Summary Report, AMP XI.M32, One-
                  Time Inspection
CW-AMP-B2.1.18    One-Time Inspection Aging Management Program Evaluation              2
                  Report
                                              A-4                              Attachment
 
B2.1.19 Selective Leaching (XI.M33)
Callaway Action Requests:
200909091            201009835
License Renewal:
    NUMBER                                        TITLE                            REVISION
                    License Renewal Component List for AMP XI.M33, Selective
                    Leaching
                    Operating Experience Summary Report, AMP XI.M33,
                    Selective Leaching
CW-AMP-B2.1.19      Selective Leaching Aging Management Program Evaluation              5
                    Report
Procedures:
  NUMBER                                      TITLE                              REVISION
APA-ZZ-00703      Fire Protection Operability Criteria and Surveillance                20
                  Requirements
TBD              Draft One-Time Inspection for Selective Leaching Degradation        Draft
                  of Components Program
B2.1.21 External Surfaces Monitoring of Mechanical Components (XI.M36)
Callaway Action Requests:
200803465            200803472              200810025
License Renewal:
    NUMBER                                        TITLE                            REVISION
                    License Renewal Component List for AMP XI.M36, External
                    Surfaces Monitoring of Mechanical Components
                    Operating Experience Summary Report, AMP XI.M36,
                    External Surfaces Monitoring of Mechanical Components
                                              A-5                            Attachment
 
License Renewal:
    NUMBER                                    TITLE                                REVISION
CW-AMP-B2.1.21    External Surfaces Monitoring of Mechanical Components                2
                  Aging Management Program Evaluation Report
Procedures:
    NUMBER                                    TITLE                                REVISION
EDP-ZZ-01131      Plant Health and Performance Monitoring Program                      21
EDP-ZZ-01131,    Engineering System Walkdowns                                        1
Appendix K
B2.1.25 Buried and Underground Piping and Tanks (XI.M41)
Callaway Action Requests:
200207386        200605969          200606030          200607749          200608647
200702384        200702484          200703899          200704465          200707760
200711546        200800871          200803345          200808781          200904086
200909892        201000931          201006741          201010950          201204441
201206525        201206616          201206868
Drawings:
NUMBER                                    TITLE                                  REVISION
CU2C1        Essential Service Water System - Unit 1 yard Pipelines & Electrical      10
            Duct Banks Plan & Schedule
C-U206      Essential Service Water System Replacement Yard Piping Plan              0
License Renewal:
    NUMBER                                    TITLE                                REVISION
                  License Renewal Component List for AMP XI.M41, Buried
                  and Underground Piping and Tanks
                  Callaway Action Request Operating Experience Report for
                  AMP XI.M41, Buried and Underground Piping and Tanks
                                            A-6                                Attachment
 
License Renewal:
    NUMBER                                      TITLE                            REVISION
CW-AMP-B2.1.25    Buried and Underground Piping and Tanks Aging                        5
                  Management Program Evaluation Report
Miscellaneous:
  NUMBER                                    TITLE                                  DATE
                Request for Additional Information for the Review of the          10/01/2012
                Callaway Plant, Unit 1, License Renewal Application, Set 13
                Soil Sample Request                                                07/27/2009
                Soil Lab Results - Near Discharge Monitoring Tanks in the          07/23/2012
                Radioactive Waste Yard
                Soil Lab Results - Intake Lube Water, Next to Pipe                04/02/2010
                Draft Cathodic Protection Monitoring Procedure
E-1026-00012    Cathodic Protection Design Report - Harco                          08/02/1992
410049          2005 Cathodic Protection Survey and Assessment Report              05/05/2006
83470351        CC Technologies Final Report - Indirect Inspections ESW            05/02/2007
                Supply, Return, Discharge and Strainer Backwash Pipelines
83475171        Close-Interval Survey and Direct Current Voltage Gradient          05/07/2008
                (Survey Buried Fire Water Protection Piping
10513410-500    Annual Cathodic Protection System Survey                          08/29/2011
Procedures:
  NUMBER                                      TITLE                              REVISION
APA-ZZ-00703    Fire Protection Operability Criteria and Surveillance Results        20
                (markup)
EDP-ZZ-01011    Buried and Underground Piping and Tanks Inspection Program            3
                                              A-7                              Attachment
 
Procedures:
  NUMBER                                        TITLE                              REVISION
EDP-ZZ-02002      Backfill/Material Selection, Preparation, Placement , &              4
                  Compaction
MTT-ZZ-1003        Coatings and Wrapping of Piping                                      6
Specifications:
  NUMBER                                    TITLE                            REVISION/DATE
4645-23A        Technical Specification for Fire Protection System                    20
4645-P23-6      Procurement Specification for Pipe and Fittings Fire                  3
                Protection System
4645-P23-7      Procurement Specification for Post Indicator Valves Fire              3
                Protection System
4645-P23-16    Procurement Specification for Shutoff Valves, Valve Bodies            1
                and Wrenches Fire Protection System
S-1080          Technical Specification for the Installation of Replacement      10/02/2008
                ASME Section III Buried Essential Service Water System
                Piping
Excavations and Pipe Evaluation:
  NUMBER                                        TITLE                                DATE
Job Order        As Found Buried Piping Visual Inspection Form,- Water            08/04/2009
09003490          Treatment Bypass Line
Job Order        Ultrasonic Thickness Report,                                      05/05/2010
09000264-535
Job Order        As Found Buried Piping Visual Inspection Form, Near CW/SW        05/06/2010
10000810          Near Intake Deep Well
Job Order        As Found Buried Piping Inspection Form, Fire Protection Piping    02/10/2011
11000318.460
Job Order        As Found Buried Piping Inspection Form, Fire Protection Piping    09/19/2011
11002092.460
                                                A-8                            Attachment
 
Excavations and Pipe Evaluation:
  NUMBER                                      TITLE                                  DATE
Job Order        As Found Buried Piping Inspection Form, - Near Discharge          06/11/2012
12000962-500      Monitoring Tanks in the Radioactive Waste Yard
Job Order        Ultrasonic Thickness Report                                      06/21/2012
12000962-510
B2.1.37 Electrical Cable Connections Not Subject to 10 CFR 50.49 Environmental
        Qualification Requirements (XI.E6)
Callaway Action Requests:
200000569          200102076          200506953        200507313          200708150
200709539          200810789          200900024        201104380
License Renewal:
    NUMBER                                      TITLE                              REVISION
                      License Renewal Component List for AMP XI.E6, Electrical
                      Cable Connections Not Subject to 10 CFR 50.49
                      Environmental Qualification Requirements
                      Callaway Action Request Operating Experience Report for
                      AMP XI.E6, Electrical Cable Connections Not Subject to 10
                      CFR 50.49 Environmental Qualification Requirements
CW-AMP-B2.1.37        Electrical Cable Connections Not Subject to 10 CFR 50.49          4
                      Environmental Qualification Requirements Aging
                      Management Program Evaluation Report
Miscellaneous:
    NUMBER                                      TITLE                                DATE
Information Notice    Inadequate Electrical Connection                              11/17/2010
2010-25
NG02BAF2              Preventive Maintenance Inspection Report for NG02BAF2        02/01/2012
PG13QER5              Thermography Preventive Maintenance Inspection Report        02/01/2012
                                              A-9                              Attachment
 
Miscellaneous:
    NUMBER                                      TITLE                            DATE
PG14RFF2            Thermography Preventive Maintenance Inspection Report for  06/25/2012
                    FDR Bkr to QA01 TB Lighting PNL VIA XFMR XQA01
Procedures:
    NUMBER                                      TITLE                          REVISION
EDP-ZZ-07001      Cable Management Program                                          0
EDP-ZZ-01113      Electrical Equipment Predictive Performance Manual                7
MTT-ZZ-01004      General Guidelines for Cable Terminations                        14
MTT-ZZ-01004B      Taping Instructions for Cables                                    7
MTT-ZZ-01013      Motor Program Guide                                              1
Work Orders:
09512582-500          09512582-510          11500083-501        11500083-510
B2.1.39 Metal-Enclosed Bus Program (XI.E4)
Callaway Action Requests:
200508906            200909297            201008436          201010873
201109870            201206491*            201206807*
Drawings:
  NUMBER                                      TITLE                            REVISION
8600-X-88554    Schematic Diagram Main Circuit Breaker 152PB12101,                  8
                Transformer XPB121, Circ. & Serv. Water Pumphouse
8600-X-88555    Schematic Diagram Main Circuit Breaker 152PB122101,                9
                Transformer XPB122, Circ. & Serv. Water Pumphouse
8600-X-88556    Schematic Diagram Main Circuit Breaker 152PB12301,                  8
                Transformer XPB123, Circ. & Serv. Water Pumphouse
                                            A-10                          Attachment
 
Drawings:
  NUMBER                                      TITLE                            REVISION
Elec-E-21001    Main Single line Diagram                                          17
(E-21001(Q))
C1515-6          Unit 3 Bus Duct 5KV Metal Switchgear Circ & Service Water          2
                Pumphouse
C1515-7          Unit 11 Bus Duct 5KV Metal Switchgear Circ & Service Water          2
                Pumphouse
C1515-8          Unit 7 Bus Duct 5KV Metal Switchgear Circ & Service Water          2
                Pumphouse
License Renewal:
    NUMBER                                    TITLE                          REVISION
                  License Renewal Component List for AMP XI.E4, Metal-
                  Enclosed Bus Program
                  Operating Experience Report for AMP XI.E4, Metal-Enclosed
                  Bus Program
CW-AMP-B2.1.39    Metal-Enclosed Bus Program Aging Management Program              3
                  Evaluation Report
Miscellaneous:
    NUMBER                                      TITLE                          REVISION
097739            General Electric Company Instruction Manual Metal-Clad
                  Switchgear
RFR-19619        Termination Instruction for XMA01A, B, C                          D
Operating Experience:
    NUMBER                                      TITLE                            DATE
Information      Electrical Bus Bar Failure                                    09/07/1989
Notice 1989-64
                                            A-11                          Attachment
 
Operating Experience:
    NUMBER                                    TITLE                              DATE
Information        Inadequate Electrical Connection                            09/17/2010
Notice 2010-25
Procedures:
    NUMBER                                      TITLE                            REVISION
EDP-XX-NNNNN      Metal Enclosed Bus Clean and Inspect                              D
MPE-ZZ-QS004      General Electric 13.8KV Switchgear PM                            17
MPE-ZZ-QS014      General Electric 4.16KV Switchgear PM                            10
Existing Aging Management Programs
B2.1.2 Water Chemistry (XI.M2)
Audits/Self Assessments:
    NUMBER                                    TITLE                                DATE
AP09-002          Quality Assurance Audit of Plant Operations and Chemistry      04/23/2009
SA08-CH-S01      Raw Water Self-Assessment                                      09/22/2008
SA10-CH-S01      Chemistry Fundamentals and Conduct of Operation                02/12/2010
SA10-CH-S04      SGFW Iron Transport                                            10/18/2010
SA10-CH-S05      Demineralizer Water System                                    12/15/2010
License Renewal:
    NUMBER                                      TITLE                          REVISION
                    Component List for Aging Management Program XI.M2,
                    Water Chemistry
                    Operating Experience Summary Report XI.M2, Water
                    Chemistry
                                            A-12                          Attachment
 
License Renewal:
    NUMBER                                    TITLE                            REVISION
CW-AMP-B2.1.32      Water Chemistry Aging Management Program Evaluation              3
                    Report
Miscellaneous:
                                          TITLE
Callaway Action Request 201109890
Chemistry Department Health Report - December 2011
Chemistry Department Health Report - June 2012
Chemistry Department Health Report - August 2012
Primary Chemistry Trend Data
Miscellaneous:
  NUMBER                                  TITLE                              REVISION
EPRI 1016555    Pressurized Water Reactor Secondary Water Chemistry                7
                Guidelines
EPRI 1014986    Pressurized Water Reactor Primary Water Chemistry Guidelines      6
Procedures:
  NUMBER                                  TITLE                              REVISION
APA-ZZ-01020    Primary Chemistry Program                                        21
APA-ZZ-01021    Secondary Chemistry Program                                      30
CDP-ZZ-00110    Chemistry Data Trending Program                                    4
CDP-ZZ-00200    Chemistry Schedule and Water Specs                                92
CTO-ZZ-01020    Off Normal Primary Chemistry Corrective Actions                    7
                                          A-13                            Attachment
 
Procedures:
  NUMBER                                    TITLE                                REVISION
CTO-ZZ-01021    Off Normal Secondary Chemistry Corrective Actions                  13
B2.1.3 Reactor Head Closure Stud Bolting (XI.M3)
Callaway Action Requests:
199601632
Calculations:
  NUMBER                                    TITLE                              REVISION
BB-131          Review of Decreased Thread Engagement For Reactor Vessel            0
                Head Stud #18
DEI-260          Flange Thread Degradation - Callaway Unit 1 Reactor Vessel          0
Drawings:
    NUMBER                                    TITLE                              REVISION
E-11173-121-005    Upper Vessel Machining - Westinghouse Electric                  3
                    Corporation 173 ID PWR
E-11173-179-001    Stud, Nut, and Washer - Westinghouse Electric Corporation        2
                    173 ID PWR
License Renewal:
    NUMBER                                    TITLE                              REVISION
                  Component List for Aging Management Program XI.M3,
                  Reactor Head Closure Stud Bolting
                  Operating Experience Summary Report XI.M3, Reactor Head
                  Closure Stud Bolting
CW-AMP-B2.1.3      Reactor Head Closure Stud Bolting Aging Management                2
                  Program Evaluation Report
                                            A-14                              Attachment
 
Miscellaneous:
  NUMBER                                    TITLE                            REVISION/DATE
                  Certified material test report for reactor vessel head studs
                  for Callaway Plant
                  Photographs of Stud 18 protective can and reactor vessel
                  head with secured with stuck stud
M-706-00068      Westinghouse Instruction Manual for Reactor Vessel                10
                  Assembly for SNUPPS Callaway Nuclear Power Plant
                  Unit 1
NMR 92-I00263    Thread Damage in Stud Holes 9, 13, 25, 39, and 54              04/28/1992
NUREG-1339        Resolution of Generic Safety Issue 29: Bolting                  06/1990
                  Degradation or Failure in Nuclear Power Plants
Procedure        Ultrasonic Examination of Bolts/Studs Greater than 2 in            0
AE-UT-98-5        Diameter
Procedure        Reactor Vessel Head Stud Removal                                  12
ETP-BB-03165
Regulatory        Materials and Inspections for Reactor Vessel Closure                1
Guide 1.65        Studs
RFR 18432A        Evaluating Leaving Stuck Stud in Place During                  01/27/1998
                  Refueling 9
RFR 18432B        Update for Stud Can Change - Refueling Outage 12              09/09/2002
Table            Examination Categories, Examination Category B-G-1,              1998
IWB-2500-1        Pressure Retaining Bolting Greater Than 2 in. (50 mm) in
                  Diameter
Stud Repair Plans:
    NUMBER                                        TITLE                              DATE
NMR89-I00145        Stud Hole No. 4 Repair Plan                                  04/18/1989
NMR89-I00164        Stud Hole No. 5 Repair Plan                                  04/19/1989
NMR89-I00165        Stud Hole No. 9 Repair Plan                                  04/18/1989
                                              A-15                            Attachment
 
Stud Repair Plans:
    NUMBER                                  TITLE                            DATE
NMR89-I00171      Stud Hole No. 7 Repair Plan                              04/18/1989
NMR89-I00173      Stud Hole No. 53 Repair Plan                            04/21/1989
NMR89-I00176      Stud Hole No. 1 Repair Plan                              04/20/1989
Work Orders:
08511749-550                10506686-550              10508687-550
B2.1.7 Flow-Accelerated Corrosion (XI.M17)
Callaway Action Requests:
200604618            200711756            200811208            200811225
201109374            201206822*
Calculations:
NUMBER                                    TITLE                              REVISION
4501-01      Callaway Nuclear Plant FAC System Susceptibility Evaluation        0
              (SSE)
4501-02      Callaway Nuclear Plant FAC Susceptible Non-Modeled (SNM)            0
              Program
4501.101-01  Callaway Energy Center CHECWORKS SFA Verification &                0
              Validation
Drawings:
  NUMBER                                    TITLE                            REVISION
M-22AB01(Q)    Main Steam System                                                16
M-22AB02(Q)    Main Steam System                                                15
M-22AB03        Main Steam System                                                20
M-22AC01        Main Turbine                                                    14
                                          A-16                          Attachment
 
Drawings:
  NUMBER                                TITLE                  REVISION
M-22AC02    Main Turbine                                          17
M-22AC03    Main Turbine                                          22
M-22AC04    Main Turbine                                          14
M-22AD01    Condensate System                                      17
M-22AD02    Condensate System                                      31
M-22AD06    Condensate System                                      16
M-22AE01(Q) Feedwater System                                      44
M-22AE02(Q) Feedwater System                                      28
M-22AF01    Feedwater Heater Extraction Drains and Vents          33
M-22AF02    Feedwater Heater Extraction Drains and Vents          41
M-22AF03    Feedwater Heater Extraction Drains and Vents          20
M-22AF04    Feedwater Heater Extraction Drains and Vents          10
M-22AN01    Demineralized Water Storage and Transfer System        36
M-22AP01    Condensate Storage and Transfer System                25
M-22BL01(Q) Reactor Make-up Water System                          22
M-22BM01(Q) Steam Generator Blowdown System                        34
M-22BM02    Steam Generator Blowdown System                        16
M-22BN01(Q) Borated Refueling Water Storage System                25
M-22CA01    Steam Seal System                                      5
M-22FA01    Auxiliary Boiler System                                16
M-22FB01    Auxiliary Steam System                                19
M-22FB02    Auxiliary Steam System                                11
                                      A-17                Attachment
 
Drawings:
  NUMBER                                      TITLE                          REVISION
M-22FC02(Q)    Auxiliary Feedwater Pump Turbine                                    20
M-22FC03        SGFP Turbine A                                                    17
M-22FC04        SGFP Turbine B                                                    19
M-22GA01        Plant Heating System                                                9
M-22HC01        Solid Radwaste System                                              32
M-22HD01        Decontamination System                                              9
Miscellaneous:
                                      TITLE                                      DATE
Flow-Accelerated Corrosion Health Report - December 2011                        12/02/2011
Flow-Accelerated Corrosion Health Report - January 2012                        01/25/2012
Flow-Accelerated Corrosion Health Report - April 2012                          04/27/2012
Flow-Accelerated Corrosion Health Report - July 2012                            07/25/2012
Miscellaneous:
    NUMBER                                    TITLE                        REVISION/DATE
                    Specification for Evaluation and Acceptance of Local    07/28/1993
                    Areas of Material, Parts, and Components that are Less
                    than the Specified Thickness
                    Component List for Aging Management Program
                    XI.M17, Flow-Accelerated Corrosion
                    Operating Experience Summary Report XI.M17, Flow-
                    Accelerated Corrosion
CW-AMP-B2.1.7      Flow-Accelerated Corrosion Aging Management                  4
                    Program Evaluation Report
                                              A-18                          Attachment
 
Miscellaneous:
    NUMBER                                  TITLE                      REVISION/DATE
NSAC-202L-R3        Recommendations for an Effective Flow-Accelerated      05/2006
                    Corrosion Program
Outage Reports:
    NUMBER                                    TITLE                            DATE
NET 08-0070        Refuel 16 Flow Accelerated Corrosion Report              11/07/2008
NET 10-0026        Refuel 17 Flow Accelerated Corrosion Report              05/15/2010
NET 11-0104        Refuel 18 Flow Accelerated Corrosion Report              11/21/2011
Procedures:
  NUMBER                                      TITLE                          REVISION
DTI-E-00004      Flow-Accelerated Corrosion Program Desktop Instruction          1
EDP-ZZ-01115    Flow-Accelerated Corrosion of Piping and Components            23
                Predictive Performance Manual
ME-004          Engineering Design Guide - Material Selection                  1
ME-013          Engineering Design Guide - Pipewall Thickness                  1
QCP-ZZ-05019    Ultrasonic Thickness Measurement                                13
B2.1.10 Open-Cycle Cooling Water Systems (XI.M20)
Callaway Action Requests:
200608992          200703776          200811088          200902969    200903703
200909455          201011236          201011505          201103465    201205800
201206831
                                            A-19                        Attachment
 
Drawings:
    NUMBER                                      TITLE                              REVISION
                Elevation Drawings for Piping from the Cooling Tower to the
                Power Block
C-U206          Essential Service Water System Replacement Yard Piping Plan            1
CAD-0576        Essential Service Water System - FSAR Figure 9.2-2, Sheet 1
CAD-0577        Essential Service Water System - FSAR Figure 9.2-2, Sheet 2
CAD-0578        Essential Service Water System - FSAR Figure 9.2-2, Sheet 3
M-22GK02 (Q)    Control Building Heating, Ventilation, and Air Conditioning          17
M-072-00001      Setting Plan for Component Cooling Water Heat Exchangers              18
                76 ID X 370 Tube Length
M-1089-00097A    Type R Coil 31 Tube Face - Carrier Replacement 6 Row -              1
                4 Pass (11/2 Circuit) Right & Left Hand
8600-X-88195    Piping Plan - Circulating Water System                                5
8600-X-88202    Piping Plans - Circulating Water Trifurcation & Service Water          4
                Manifold, Circulating and Service Water Pumphouse
8600-X-88726    Piping Installation Details - Water Plan, Profile & Sections          2
                Service Water System
License Renewal:
    NUMBER                                      TITLE                              REVISION
                  Component List for Aging Management Program XI.M20,
                  Open-Cycle Cooling Water System
                  Operating Experience Summary Report XI.M20, Open-Cycle
                  Cooling Water System
CW-AMP-B2.1.10    Open-Cycle Cooling Water System Aging Management                    2
                  Program Evaluation Report
                                            A-20                              Attachment
 
Miscellaneous:
  NUMBER                                  TITLE                        REVISION/DATE
              Chemistry data for service water system and the ultimate
              heat sink
              Generic Letter 89-13 Room Coolers Long Term Asset          05/2012
              Management Plan
              Tube plugging limits for heat exchangers serviced by
              essential service water system
CA-1259        Aerofin Corporation Instruction Manual for R. P. Adams          0
              26/30 HDWS-80 Essential Service Water Strainer
Letter        Cycle 15 Commitment Change Summary Report                  07/16/2007
ULNRC-05425
M-1180-00001  Manual for Adams HWS and VWS Single Backwash                    0
              Automatic Poro-Edge Strainers
NPS-Proc 007  Examination for the Detection and Sizing of Pitting,            4
              Corrosion, and Wall Loss Using Low Frequency
              Electromagnetic Techniques
PD041150.02    Record of Eddy Current Inspection of Component Cooling      04/2010
              Water (CCW) Heat Exchanger - B at Callaway Nuclear
              Plant
PM 0818570    Clean and Inspect EKJ03A Intercooler Heat Exchanger            6
              and Expansion Joints
RP0502-2002    National Society of Corrosion Engineers (NACE) Pipeline      2002
              External Corrosion Direct Assessment Methodology
RFR 022364B    Document Generic Letter 89-13 Compliance                        0
T-11231-LF    Low Frequency Electromagnetic Technique Inspection        12/20/2011
              Report of the Essential Service Water Containment Piping
              at Callaway
                                            A-21                        Attachment
 
Procedures:
  NUMBER                                  TITLE                            REVISION
APA-ZZ-01025  Raw Water Systems Control Program                                0
CDP-ZZ-00200  Chemistry Schedule and Water Specs                              92
CDP-ZZ-00940  Auxiliary Water Systems Chemistry Optimization Plan              6
EDP-ZZ-01112  Heat Exchanger Predictive Performance Manual                    17
EDP-ZZ-01112  Heat Exchanger Predictive Performance Manual                    17
EDP-ZZ-01121, Non-Trended Monitored Locations for Raw Water Program            2
Appendix 2
EDP-ZZ-01128  Maintenance Rule Program                                        17
EDP-ZZ-01131  Plant Health and Performance Monitoring Program                  21
EDP-ZZ-01131, Engineering System Walkdowns                                      1
Appendix K
ESP-EF-0002A  Essential Service Water Train A Flow Verification                12
ESP-EF-0002B  Essential Service Water Train B Flow Verification                16
ETP-EG-00003  Thermal Performance Test of the 'A' CCW Heat Exchanger            0
ETP-EG-00004  Thermal Performance Test of the 'B' CCW Heat Exchanger            0
ETP-ZZ-03001  GL 89-13 Heat Exchanger Inspection                              9
QCP-ZZ-05047  Nondestructive Examination Procedure Using Low Frequency          0
              Electromagnetic Techniques
OTS-AL-00001  ESW Train "A" to TDAFP Flush (High Flow)                        21
OTS-AL-00002  ESW Train "B" to TDAFP Flush (High Flow)                        21
OTS-AL-00003  "A" MDAFP Flush (High Flow)                                      19
OTS-AL-00004  "B" MDAFP Flush (High Flow)                                      19
                                        A-22                          Attachment
 
Work Orders:
08512698-500      08512900-500        08512901-500      08513322-500      08513323-520
09500848-500      09510848-580        09512842-500      10510385-500      10511510-580
10511630-500      10512857-500        10513220-580      10513276-580
B2.1.11 Closed Treated Water Systems (XI.M21A)
Callaway Action Requests:
200000281          200700441              200805013
Drawings:
    NUMBER                                      TITLE                              REVISION
M-22GB01          Central Chilled Water System                                        18
M-22GK02 (Q)      Control Building Heating, Ventilation, and Air Conditioning          17
M-072-00001      Setting Plan for Component Cooling Water Heat Exchangers            18
                  76 ID X 370 Tube Length
M-612-00006      Room Coolers                                                          9
Lesson Plans:
    NUMBER                                      TITLE                            REVISION
T61.016D.6            Component Cooling Water
T61.016C.6            Central Chilled Water
License Renewal:
    NUMBER                                      TITLE                              REVISION
                    Component List for Aging Management Program XI.M21A,
                    Closed Treated Water Systems
                    Operating Experience Summary Report XI.M21A, Closed
                    Treated Water Systems
                                            A-23                              Attachment
 
License Renewal:
    NUMBER                                    TITLE                          REVISION
CW-AMP-B2.1.21A      Closed Treated Water Systems Aging Management Program      2 and 3
                    Evaluation Report
Miscellaneous:
    NUMBER                                TITLE                        REVISION/DATE
                    Chemistry Parameter Trend Graphs for Component
                    Cooling Water, Diesel Generator Jacket Water, Closed
                    Cooling Water, and Central Chilled Water
EPRI 1007820        Closed Cooling Water Chemistry Guideline                    1
Health Report      Component Cooling Water
Letter              Response to Generic Letter 89-13, Service Water      01/29/1990
ULNRC-2146          Problems Affecting Safety- Related Equipment
Procedure          Non-Chemistry Inspections of Closed Treated Water          0
EDP-ZZ-XXXXX        Systems Markup
Procedures:
  NUMBER                                    TITLE                            REVISION
APA-ZZ-01025    Raw Water Systems Control Program                                  0
CDP-ZZ-00110    Chemistry Data Trending Program                                  4
CDP-ZZ-00200    Chemistry Schedule and Water Specs                                92
CDP-ZZ-00200,    Closed Cooling Systems Tables                                    11
Appendix D
CDP-ZZ-00940    Auxiliary Water Systems Chemistry Optimization Plan              6
EDP-ZZ-01112    Heat Exchanger Predictive Performance Manual                      17
EDP-ZZ-01128    Maintenance Rule Program                                          17
EDP-ZZ-01131    Plant Health and Performance Monitoring Program                  21
                                          A-24                          Attachment
 
Procedures:
    NUMBER                                      TITLE                          REVISION
EDP-ZZ-01131,      Engineering System Walkdowns                                    1
Appendix K
ETP-EG-00002      Component Cooling Water System Flow Verification                14
ETP-EG-00003      Thermal Performance Test of the 'A' CCW Heat Exchanger          0
ETP-EG-00004      Thermal Performance Test of the 'B' CCW Heat Exchanger          0
OTN-EG-00001      Component Cooling Water System                                  50
B2.1.13 Fire Protection (XI.M26)
Callaway Action Requests:
200401401            200402661            201202582          201203013
License Renewal:
    NUMBER                                      TITLE                          REVISION
                    Component List for Aging Management Program XI.M26, Fire
                    Protection
                    Operating Experience Summary Report XI.M26, Fire
                    Protection
CW-AMP-B2.1.13      Fire Protection Aging Management Program Evaluation Report    4
Miscellaneous:
                                            TITLE
Fire Protection (Appendix R) Health Report - December 2011
Fire Protection (Appendix R) Health Report - January 2012
Fire Protection (Appendix R) Health Report - April 2012
Fire Protection (Appendix R) Health Report - July 2012
                                            A-25                          Attachment
 
Procedures:
    NUMBER                                      TITLE                            REVISION
APA-ZZ-00703      Fire Protection Operability Criteria and Surveillance              20
                  Requirements
MSM-KC-FQ001      Function Test - Halon Systems Protecting Safety Related Areas      27
MSM-KC-FT001      Halon Fire Protection Cylinder Inspection                          27
MSM-ZZ-FG002      Fire Damper Inspection and Drop Test                              12
OSP-KC-00015      Fire Door Inspections                                              13
QSP-ZZ-65045      Fire Barrier Seal Visual Inspection                                8
QSP-ZZ-65046      Fire Barrier Inspection                                            13
B2.1.14 Fire Water Systems (XI.M27)
Callaway Action Requests:
200711546            201102974              201206538*
Miscellaneous:
                                              TITLE
Fire Main Flow Test, dated November 17, 2009
Fire Main Flow Test, dated December 3, 2009
Fire Main Flow Test, dated April 11, 2011
Fire Main Flow Test, dated April 12, 2011
Fire Water System Health Report - December 2011
Fire Water System Health Report - January 2012
Fire Water System Health Report - April 2012
Fire Water System Health Report - July 2012
Work Order 12000569
                                              A-26                            Attachment
 
Procedures:
    NUMBER                                      TITLE                            REVISION
CTP-ZZ-02038        Microbiologically Influenced Corrosion Monitoring Program        16
EDP-ZZ-01121        Raw Water Systems Predictive Performance Program                  15
MSM-KC-FW002        Water Spray Flow Test for Turbine Driven Aux Feedpump            15
APA-ZZ-00703        Fire Protection Operability Criteria and Surveillance            20
                    Requirements
CTP-KC-06001        Fire Protection System Chemical Addition                          6
MPM-KC-FW004        Fire Hose Station Inspection Outside Areas                        9
MSM-KC-FW003        Fire Hose Station Inspection Inside RCA                          19
MSM-KC-FW004        Fire Hose Hydrostatic Testing                                    19
MSM-KC-FW007        Yard Loop Flush                                                  18
MSM-KC-FW008        Fire Hose Hydrostatic Testing in Potentially Contaminated        11
                    Areas
MSM-KC-FW009        Fire Hose Station Inspection Outside RCA                          7
OSP-KC-00008        Sprinkler System Discharge Head Inspection                        10
OSP-KC-03003        Fire Main Flow Test                                                5
B2.1.16 Fuel Oil Chemistry (XI.M30)
Callaway Action Requests:
201004307
Drawings:
  NUMBER                                      TITLE                              REVISION
8600-X-89634    Diesel Driven Fire Pump PKC1002A Fire Protection System              6
                (KC1)
                                            A-27                            Attachment
 
Drawings:
  NUMBER                                    TITLE                                  REVISION
8600-X-89888    Security Diesel Generator System - Security Diesel Generator            17
                Building
95645          Tank - Diesel Fuel 250 Gallon TKC100B, Fire Protection System            2
104283          275A SFT (Security Fuel Tank) Assembly                                  4
FEG-8600-X-    Auxiliary Fuel Oil Unloading Station Storage & Transfer (JA1) -        B
89642          Auxiliary Fuel Oil Storage & Transfer System
FEG-8600-X-    Auxiliary Fuel Oil Unloading Station Storage & Transfer (JA1) -        A
89643          Auxiliary Fuel Oil Storage & Transfer System
M-105A-00015    Emergency Fuel Oil Day Tank TJE01A/TJE01B                              10
M-109-00013    Emergency Fuel Oil Storage Tank - SNUPPS                                8
License Renewal:
    NUMBER                                      TITLE                                REVISION
                    License Renewal Component List for AMP XI.M30, Fuel Oil
                    Chemistry
                    Callaway Action Request Operating Experience Report for
                    AMP XI.M30, Fuel Oil Chemistry
CW-AMP-B2.1.16      Fuel Oil Chemistry Aging Management Program Evaluation              2
                    Report
Miscellaneous:
    NUMBER                                      TITLE                                DATE
D 1796 - 83          Standard Test Method for Water and Sediment in Fuel Oils
                    by the Centrifuge Method (Laboratory Procedure)
D 2276 - 73          Standard Test Method for Particulate Contamination in
                    Aviation Turbine Fuels
04503148-500        2008 Train B Emergency Fuel Oil Storage Tank Inspection
                                            A-28                                Attachment
 
Miscellaneous:
    NUMBER                                          TITLE                              DATE
RFR 09606A              Diesel Generator Oil Equivalent Tank Cleaning                  09/30/1991
Specification 10466    Coating Repair Procedure                                      04/30/1979
-M-109-049-02
Table 9.5.4.3          Comparison of The Design to Regulatory Positions of
                        Regulatory Guide 1.137, Revision 0, Fuel-Oil Systems for
                        Standby Diesel Generators
Technical              Diesel Fuel Oil, Lube Oil, and Starting Air
Specification 3.8.3
Technical              Diesel Fuel Oil, Lube Oil, and Starting Air
Specification
Bases 3.8.3
Procedures:
  NUMBER                                          TITLE                              REVISION
APA-ZZ-00703      Fire Protection Operability Criteria and Surveillance Requirements      20
CTP-ZZ-02135      Specific Gravity Determination                                          14
CTP-ZZ-02145      Flash Point Determination                                                10
CTP-ZZ-02233      Biodiesel Determination                                                  0
CTP-ZZ-02350      Viscosity Determination                                                  9
CTP-ZZ-02360      Water and Sediment Determination                                          8
OTS-JE-00002      Filtration of Emergency Diesel Generator Fuel Oil                        9
Procedure Markups:
  NUMBER                                          TITLE                              REVISION
MSM-KJ-QT001        10 Year Emergency Diesel Generator Fuel Oil Storage Tank              11
                    Cleaning
                                              A-29                              Attachment
 
Procedure Markups:
    NUMBER                                    TITLE                            REVISION
CSP-ZZ-07350      Diesel Fuel Oil Testing Program                                  23
CTP-JE-01230      Diesel Fuel Oil Water Removal and Sampling                      43
CTP-JE-01235      Diesel Fuel Oil Skid Sampling and Chemical Addition              5
Work Orders:
S503345            W129881                04503148-500
B2.1.24 Lubricating Oil Analysis (XI.M39)
Callaway Action Requests:
200906391          200907931              201004714            201101042
Miscellaneous:
    NUMBER                                TITLE                        REVISION/DATE
CW-AMP-B2.1.24    Lubricating Oil Analysis Aging Management Program            2
                  Evaluation Report
NET 12-0019        Vibration/Oil Analysis Report - February 2012            03/06/2012
NET 12-0024        Vibration/Oil Analysis Report - March 2012              04/10/2012
R&G Laboratories  Oil Analysis Data Sheet Reports
Procedures:
  NUMBER                                      TITLE                            REVISION
EDP-ZZ-01126    Lubrication Predictive Maintenance Program                        11
EDP-ZZ-01131    Plant Health and Performance Monitoring Program                  21
MDP-ZZ-L0001    Lubrication Program                                              17
                                            A-30                          Attachment
 
B2.1.30 Masonry Walls (XI.S5)
Drawings:
NUMBER                                        TITLE                              REVISION
A-2301      Auxiliary and Reactor Building Floor Plan, El. 1974-0                  5
A-2325      Control & Diesel Gen. Buildings & Communication Corridor Floor          3
            Plans @ El. 2000-0 & El 2016-0
A-2326      Control & Diesel Gen. Buildings & Communication Corridor Floor          9
            Plans @ El. 2032-0 & El 2047-6
A-2337      Computer Room & Control Room Detailed Floor Plans @ El 2047-6        12
A-2341      CMU Wall Penetrations Control Bldg.& Communication Corridor              1
A-2342      CMU Wall Penetrations Control Bldg.& Communication Corridor              0
A-2905      Architectural General Masonry Details                                    0
A-2904      General Masonry Details                                                  0
C-2031      Civil Structural Standard Details Sheet No. 20                          0
License Renewal:
    NUMBER                                      TITLE                          REVISION
                    License Renewal Component List for AMP XI.S5, Masonry
                    Walls
                    Callaway Action Request Operating Experience Report for
                    AMP XI.S5, Masonry Walls
CW-AMP-B2.1.30      Masonry Walls Aging Management Program Evaluation Report        2
B2.1.31 Structures Monitoring (XI.S6)
Callaway Action Requests:
200105924            200200983            200403475
                                              A-31                          Attachment
 
Drawings:
NUMBER                                  TITLE                                  REVISION
C-2C1910  Auxiliary Building Conc. Neat Lines & Reinforcing Wall Elevation          5
          Sheet-10
C-2L2902  Reactor Building Liner Plate Developed Elevations                          0
C-2L2908  Reactor Building Liner Plate Floor and Wall Details                        0
M-2G026  Equipment Location Reactor and Auxiliary Building Section A              10
M-2G027  Equipment Location Reactor and Auxiliary Building Section B                4
M-2G028  Equipment Location Reactor and Auxiliary Building Section C                7
M-2G029  Equipment Location Reactor and Auxiliary Building Section D                7
M-2G030  Equipment Location Reactor and Auxiliary Building Sections E, F, &        7
          G
M-2G040  Equipment Location Fuel Building Plan Elevation 2000'-0", 2026'-0",      30
          2047'-6"
M-2G041  Equipment Location Fuel Building Sections A, B, & C                        2
M-2G042  Equipment Location Fuel Building Sections D, E, & F                        2
M-2G050  Equipment Location Control Building & Communication Corridor Plan        29
          Elevation 1974'-0" & 1984'-0"
M-2G051  Equipment Location Control Diesel Generator Buildings &                  35
          Communication Corridor Plan Elevation 2000'-0" & 2016'-0"
M-2G052  Equipment Location Control Diesel Generator Buildings &                  30
          Communication Corridor Plan Elevation 2032'-0" & 2047'-6"
M-2G053  Equipment Location Control Diesel Generator Buildings & Corridor          15
          Plan Elevation 2061'-6", 2066'-0" & 2073'-6" & Section D
M-2G054  Equipment Location Control Diesel Generator Building &                    7
          Communication Corridor Section A
M-2G055  Equipment Location Control Diesel Generator Building Sections B            5
          &C
                                        A-32                              Attachment
 
Drawings:
NUMBER                                        TITLE                                REVISION
M-2GO21        Equipment Location Auxiliary Building Partial Plan El. 1988'-0"          10
              & 2013'-6"
M-2GO22        Equipment Location Reactor and Auxiliary Building Plan Ground Floor      56
              Elevation 2000'-0"
M-2X1902      Auxiliary Building Penetration Closure Wall Elevations Sheet -2            3
M-2Y1902C      Penetration Closure Schedule Aux Bldg                                      5
License Renewal:
    NUMBER                                        TITLE                              REVISION
                    License Renewal Component List for AMP XI.S6, Structures
                    Monitoring
                    Operating Experience Summary Report, AMP XI.S6, Structures
                    Monitoring
CW-AMP-B2.1.31      Structures Monitoring Aging Management Program Evaluation            5
                    Report
Miscellaneous:
    NUMBER                                        TITLE                                DATE
                  Maintenance Rule Walkdown Report Structure Reactor Building      05/02/2001
                  Maintenance Rule Walkdown Report Structure Control Building      10/05/2004
                  Maintenance Rule Walkdown Report Structure Reactor Building        09/2005
                  Interior
                  Maintenance Rule Walkdown Report Structure Control Building      03/25/2009
                  Maintenance Rule Walkdown Report Structure Reactor Building      04/26/2010
                  Interior
                  Maintenance Rule Structures Walkdown Schedule
                                              A-33                            Attachment
 
Miscellaneous:
    NUMBER                                        TITLE                                DATE
ACI 349.3R-96      Evaluation of Existing Nuclear Safety-Related Concrete              1996
                  Structures
ACI 201.1R-08      Guide for Conducting a Visual Inspection of Concrete in Service      1996
Calculation        Auxiliary Building Shielding Block Walls                            2003
C-03-134-F(2)
Procedures:
  NUMBER                                        TITLE                                REVISION
EDP-ZZ-01128      Maintenance Rule Program                                              18
ESP-ZZ-01013      Maintenance Rule Structures Inspection (markup)                        6
B2.1.32 RG 1.127, Inspection of Water-Control Structures Associated with Nuclear Power
        Plants (XI.S7)
Callaway Action Requests:
200609956            200900096              201206557
Drawings:
NUMBER                                        TITLE                                  REVISION
M-UGO80      Essential Service Water Pumphouse Equipment Locations - Plans              14
M-UGO81      Essential Service Water Pumphouse Equipment Locations - Sections            5
M-UGO82      Ultimate Heat Sink Cooling Tower Arrangement                                7
License Renewal:
    NUMBER                                        TITLE                              REVISION
                    License Renewal Component List for AMP XI.S7, Inspection of
                    Water-Control Structures Associated with Nuclear Power
                    Plants
                                              A-34                              Attachment
 
License Renewal:
    NUMBER                                      TITLE                              REVISION
                    Operating Experience Summary Report, AMP XI.S7, Inspection
                    of Water-Control Structures Associated with Nuclear Power
                    Plants
CW-AMP-B2.1.32      Inspection of Water-Control Structures Associated with Nuclear      2
                    Power Plants Aging Management Program Evaluation Report
Miscellaneous:
  NUMBER                                      TITLE                                REVISION
Design Input    Train A Essential Service Water Support Modification and              C
Report          Penetrations Seal Change
Procedures:
  NUMBER                                      TITLE                                REVISION
ESP-EF-03002    Ultimate Heat Sink Retention Pond Inservice Inspection                  6
ESP-ZZ-03907    Settlement Monitoring Program                                          5
B2.1.33 Protective Coating Monitoring and Maintenance (XI.S8)
License Renewal:
    NUMBER                                      TITLE                              REVISION
                    License Renewal Component List for AMP XI.S8, Protective
                    Coating Monitoring and Maintenance
                    Operating Experience Summary Report, AMP XI.S8, Protective
                    Coating Monitoring and Maintenance
CW-AMP-B2.1.33      Protective Coating Monitoring and Maintenance Aging                  1
                    Management Program Evaluation Report
                                            A-35                              Attachment
 
Miscellaneous:
    NUMBER                                        TITLE                              REVISION
ASTM D5163-08      Establishing a Program for Condition Assessment of Coating
                  Service Level I Coating Systems in Nuclear Power Plants
Procedure          Containment Building Coatings (markup)                                  17
EDP-ZZ-3000
B2.1.34 Insulation Material for Electrical Cables and Connections Not Subject to 10 CFR
        50.49 Environmental Qualification Requirements (XI.E1)
Callaway Action Requests:
200708150            201206824*
License Renewal:
    NUMBER                                        TITLE                              REVISION
                    Component List for Aging Management Program XI.E1,
                    Insulation Material for Electrical Cables and Connections Not
                    Subject to 10 CFR 50.49 Environmental Qualification
                    Requirements
                    Operating Experience Summary Report XI.E1, Insulation
                    Material for Electrical Cables and Connections Not Subject to
                    10 CFR 50.49 Environmental Qualification Requirements
CW-AMP-B2.1.34      Insulation Material for Electrical Cables and Connections Not          3
                    Subject to 10 CFR 50.49 Environmental Qualification
                    Requirements Aging Management Program Evaluation Report
Miscellaneous:
    NUMBER                                      TITLE                            REVISION/DATE
EPRI TR-109619      Guideline for Management of Adverse Localized                    09/1999
                    Environments
Procedure          Cable Management program                                            0
EDP-ZZ-07001
SAND 96-0344        Aging Management Guidelines for Commercial Nuclear                09/1996
                    Projects- Electrical Cables and terminations
                                              A-36                              Attachment
 
Operating Experience:
    NUMBER                                      TITLE                                DATE
Generic Letter      Certificate of Compliance to 10CFR50.49: EQ of Electrical        12/27/1984
1984-24            Equipment Importance to Safety for NPPs
Information Notice  Degradation of Kapton Electrical Insulation                      11/21/1988
1988-89
Information Notice  High Temperature Environment at Nuclear Power Plants            03/15/1989
1989-30
B2.1.35 Insulation Material for Electrical Cables and Connections Not Subject to 10 CFR
        50.49 Environmental Qualification Requirements Used in Instrumentation Circuits
        (XI.E2)
Callaway Action Request:
200404746
License Renewal:
    NUMBER                                      TITLE                              REVISION
                    Component List for Aging Management Program XI.E2,
                    Insulation Material for Electrical Cables and Connections Not
                    Subject to 10 CFR 50.49 Environmental Qualification
                    Requirements
                    Operating Experience Summary Report XI.E2, Insulation
                    Material for Electrical Cables and Connections Not Subject to
                    10 CFR 50.49 Environmental Qualification Requirements
CW-AMP-B2.1.34      Insulation Material for Electrical Cables and Connections Not        3
                    Subject to 10 CFR 50.49 Environmental Qualification
                    Requirements Aging Management Program Evaluation Report
Miscellaneous:
    NUMBER                                      TITLE                                  DATE
ISES01BA          Cable Routing data Sheet for Power block Electrical Cable
                                              A-37                              Attachment
 
Miscellaneous:
    NUMBER                                    TITLE                                  DATE
ISES01BE          Cable Routing data Sheet for Power block Electrical Cable
M-762-00412-03    Imaging and Sensing Technology Corporation Document for          09/1990
(NY-10044)        Qualified Class 1E BF3 Proportional Counter Assembly
M-762-00412-03    Imaging and Sensing Technology Corporation Document for          09/1990
(NY-10043)        Qualified Class 1E Compensated Ionization Chamber
M-762-00412-03    Imaging and Sensing Technology Corporation Document for          05/1993
(NY-10338)        Qualified Class 1E Uncompensated Ionization Chamber
                  Minutes of EPRI Kapton Information Meeting                      11/18/1988
Operating Experience:
      NUMBER                                      TITLE                              DATE
Information Notice      High Temperature Environment at Nuclear Power Plant        05/26/1989
1989-30
Information Notice      Environmental Qualification Deficiency for Cables and      07/02/1997
1997-45                Containment Penetration Pigtails
Licensee Event Report  SONGS Kapton Insulation Damage on Containment              06/02/1987
05000206-87-008        Penetration Cables
Procedures:
    NUMBER                                    TITLE                              REVISION
EDP-ZZ-07001        Cable Management Program                                          0
ISL-SE-00N31        Source Range N31 Channel Calibration                              30
ISL-SE-00N32        Source Range N32 Channel Calibration                              35
ISL-SE-OON35        INTMD RNG N35 A Train Loop Cal                                  27
ISL-SE-OON36        INTMD RNG N36 B Train Loop Cal                                  29
ISL-SE-ON41A        Loop-NU; PR N41 Detector Plateau                                  11
                                            A-38                              Attachment
 
Procedures:
    NUMBER                                        TITLE                          REVISION
ISL-SE-ON42A        Loop-NU; PR N42 Detector Plateau                                11
ISL-SE-ON43A        Loop-NU; PR N43 Detector Plateau                                11
ISL-SE-ON44A        Loop-NU; PR N44 Detector Plateau                                13
RFR 06770A          Field Installation NIS Triaxial Cables                            7
ITM-ZZ-00009        Triax Cable Maintenance and Testing                              9
B2.1.36 Inaccessible Power Cables Not Subject to 10 CFR 50.49 Environmental
        Qualification Requirements (XI.E3)
Callaway Action Requests:
200701041          200708150            200905490          201008000      201008001
201011217          201101616            201107892
Drawings:
  NUMBER                                      TITLE                            REVISION
8600-X-88859    Duct banks and Manholes Site Plan-Key, On site Elec. Power        24
                Distribution, Comm. Signal and Control System
8600-X-89139    Duct banks and Manholes MH59-8 On site Elec. Power                3
                Distribution
License Renewal:
    NUMBER                                        TITLE                          REVISION
                    Component List for Aging Management Program XI.E3,
                    Inaccessible Power Cables Not Subject to 10 CFR 50.49
                    Environmental Qualification Requirements
                    Operating Experience Summary Report XI.E3, Inaccessible
                    Power Cables Not Subject to 10 CFR 50.49 Environmental
                    Qualification Requirements
CW-AMP-B2.1.36      Inaccessible Power Cables Not Subject to 10 CFR 50.49            5
                    Environmental Qualification Requirements Aging
                                              A-39                          Attachment
 
License Renewal:
    NUMBER                                      TITLE                        REVISION
                    Management Program Evaluation Report
Miscellaneous:
    NUMBER                                      TITLE                        REVISION
Design Change        Change package for design of sump pumps in Man Holes          2
MP-11-0011          MH 59-04. MH 59-05, MH 59-08A&B, MH 59-10
Procedure            Cable Management Program                                      0
EDP-ZZ-07001
White paper          Man Hole Pump MP 11-0011
Vendor Manual        BJM submersible Pumps Technical Data Model JXA00SS
0813
Vendor Manual        Zoeller Pump Product Information
FM0493-1109
Operating Experience:
    NUMBER                                      TITLE                          DATE
Generic Letter        Inaccessible or Underground Power Cable Failure That    02/07/2007
2007-01              Disable Accident Mitigation Systems Or Cause Plant
                      Transients
Information Notice    Submerged Electrical Cables                              02/02/2010
2010-26
SYSTEM REVIEWS
License Renewal:
  NUMBER                                      TITLE                          REVISION
CW-AER-AL        Callaway Plant License Renewal Aging Evaluation Report -          3
                Auxiliary Feedwater System
                                              A-40                        Attachment
 
License Renewal:
  NUMBER                                  TITLE                            REVISION
CW-SCO-AL    Callaway Plant License Renewal System and Structure Scoping        1
              Report - Auxiliary Feedwater System
CW-SCR-AL    Callaway Plant License Renewal Component Summary                    4
              Screening Report - Auxiliary Feedwater System
Drawings:
      NUMBER                                    TITLE                        REVISION
LR-CW-AL-M-22AL01    Auxiliary Feedwater System                                0B
LR-CW-AL-M-22FC02    Auxiliary Feedwater Pump Turbine                          0A
LR-CW-KJ-M-22KJ01    Standby Diesel Generator A - Cooling Water System          21
LR-CW-KJ-M-22KJ02    Standby Diesel Generator A - Intake Exhaust. F.O &        20
                      Starting Air System
LR-CW-KJ-M-22KJ04    Standby Diesel Generator B - Cooling Water System          19
LR-CW-KJ-M-22KJ05    Standby Diesel Generator B - Intake Exhaust, F.O &        24
                      Starting Air System
                                          A-41                            Attachment
}}

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