ML043200238
| ML043200238 | |
| Person / Time | |
|---|---|
| Site: | Farley  |
| Issue date: | 09/15/2004 |
| From: | Casto C Division of Reactor Safety II |
| To: | Stinson L Southern Nuclear Operating Co |
| References | |
| IR-04-009 | |
| Download: ML043200238 (31) | |
See also: IR 05000348/2004009
Text
November 15, 2004
Southern Nuclear Operating Company
Mr. L. M. Stinson
Vice President - Farley Project
Post Office Box 1295
Birmingham, Alabama 35201
SUBJECT:
J. M. FARLEY NUCLEAR PLANT - INSPECTION REPORT 50-348/2004-009,
50-364/2004-009
Dear Mr. Stinson:
On October 1, 2004, the NRC completed an inspection regarding the application for license
renewal for your Farley facility. The enclosed report documents the inspection findings, which
were discussed on October 1, 2004, with you and members of your staff in an exit meeting
open for public observation at the Houston County Administrative Building, 462 North Oates
Street, Dothan, AL 36303.
The purpose of this inspection was an examination of activities that support the application for a
renewed license for the Farley facility. The inspection consisted of a selected examination of
procedures and representative records, and interviews with personnel regarding implementation
of your aging management programs to support license renewal. For a sample of plant
systems, inspectors performed visual examination of accessible portions of the systems to
observe any effects of equipment aging.
The inspection concluded that your license renewal activities were conducted as described in
your License Renewal Application and that documentation supporting your application is in an
auditable and retrievable form. The inspection also concluded that existing aging management
programs are functioning well and that when all the programs are implemented as described in
your License Renewal Application, there is reasonable assurance that the intended function of
vital plant systems, structures, and components will be maintained through the period of
extended operation.
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 (PARS) component of NRC's 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).
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Should you have any questions concerning this meeting, please contact Caudle A. Julian at
(404) 562-4603.
Sincerely,
/RA/
`
Charles A. Casto, Director
Division of Reactor Safety
Docket Nos:. 50-348, 50-364
Enclosure: NRC Inspection Report Nos.50-348/2004-009, 50-364/2004-009
w/Attachment: Supplemental Information
cc w/encl:
Mr. Randy Johnson
General Manager - Plant Farley
Southern Nuclear Operating Company
Post Office Box 470
Ashford, AL 36312
Mr. B. D. McKinney
Licensing Manager
Southern Nuclear Operating Company
40 Inverness Center Parkway
Post Office Box 1295
Birmingham, AL 35201-1295
Mr. Stanford M. Blanton, esq.
Balch and Bingham Law Firm
Post Office Box 306
1710 Sixth Avenue North
Birmingham, AL 35201
Mr. J. B. Beasley, Jr.
Executive Vice President
Southern Nuclear Operating Company
40 Inverness Center Parkway
Post Office Box 1295
Birmingham, AL 35201-1295
Dr. D. E. Williamson
State Health Officer
Alabama Department of Public Health
The RSA Tower
201 Monroe Street, Suite 1500
Montgomery, AL 36130-1701
Chairman
Houston County Commission
Post Office Box 6406
Dothan, AL 36302
Mr. William D. Oldfield
SAER Supervisor
Southern Nuclear Operating Company
Post Office Box 470
Ashford, AL 36312
Mr. Charles R. Pierce
Manager - License Renewal
Southern Nuclear Operating Company
40 Inverness Center Parkway
Post Office Box 1295
Birmingham, AL 35201-1295
Mr. Fred Emerson
Nuclear Energy Institute
1776 I Street, NW, Suite 400
Washington, DC 20006-3708
Resident Inspector
U.S. Nuclear Regulatory Commission
7388 N. State Highway 95
Columbia, AL 36319
3
Distribution w/encl:
T. Liu, NRR
C. Evans (Part 72 Only)
L. Slack, EICS
RIDSNRRDIPMLIPB
PUBLIC
ROPreport
OFFICE
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RII\\DRS
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SIGNATURE
CAJ\\For
CAJ\\For
CAJ\\For
CAJ
CAJ\\For
NAME
KVanDorn
MScott
RMoore
CJulian
BBonser
DATE
11/10/2004
11/10/2004
11/10/2004
11/10/2004
11/10/2004
E-MAIL COPY?
YES
NO YES
NO YES
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NO YES
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NO YES
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PUBLIC DOCUMENT
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OFFICIAL RECORD COPY DOCUMENT NAME: E:\\Filenet\\ML043200238.wpd
Enclosure
U. S. NUCLEAR REGULATORY COMMISSION
REGION II
Docket Nos.:
50-348, 50-364
License Nos.:
Report Nos.:
05000348/2004009 and 05000364/2004009
Licensee:
Southern Nuclear Operating Company, Inc.
Facility:
Farley Nuclear Plant
Location:
7388 N. State Highway 95
Columbia, AL 36319
Dates:
September 20 - October 1, 2004
Inspectors:
C. Julian, Team Leader
R. Moore, Senior Reactor Inspector
T. Nazario, Reactor Inspector
M. Scott, Senior Reactor Inspector
K. VanDoorn, Senior Reactor Inspector
Approved by:
Charles A. Casto, Director
Division of Reactor Safety
INSPECTION SUMMARY
IR 05000348-04-09,05000364-04-09; 9/20-10/01/2004; Southern Nuclear Operating Company;
J. M. Farley Nuclear Plant; License Renewal Inspection Program, Aging Management
Programs.
This inspection of License Renewal (LR) activities was performed by five regional office
engineering inspectors. The inspection program followed was NRC Manual Chapter 2516 and
NRC Inspection Procedure 71002. This inspection did not identify any findings as defined in
The inspection concluded that LR activities were conducted as described in the License
Renewal Application (LRA) and that documentation supporting the application is in an auditable
and retrievable form. The inspection also concluded that existing aging management programs
(AMPs) are generally functioning well and that when all the programs are implemented as
described in the LRA, there is reasonable assurance that the intended function of vital plant
systems, structures, and components will be maintained through the period of extended
operation.
The applicant had not yet loaded items into the official plant commitment tracking system to
assure implementation of proposed actions to support LR. This was identified as an item for
followup during a future NRC inspection. Several of the LRA committed aging management
programs were new programs yet to be developed at the time of this inspection. NRC will
review the applicants progress on developing these AMPs during a future NRC inspection.
In walking down plant systems and examining plant equipment the inspectors found no
significant adverse conditions and it appears plant equipment was being maintained
adequately.
Attachment 1 to this report contains a partial list of persons contacted and a list of documents
reviewed. The Aging Management Programs selected for review during this inspection are
listed in Attachment 2 to this report. Attachment 3 is a list of acronyms used in this report.
Report Details
I.
Inspection Scope
This inspection was conducted by NRC Region II inspectors to interview applicant
personnel and to examine a sample of documentation which supports the license
renewal application (LRA). This inspection reviewed the implementation of the
applicants Aging Management Programs (AMPs). The inspectors reviewed supporting
documentation to confirm the accuracy of the LRA conclusions. For a sample of plant
systems, inspectors performed visual examination of accessible portions of the systems
to observe any effects of equipment aging. Attachment 1 of this report lists the
applicant personnel contacted and the documents reviewed. The Aging Management
Programs selected for review during this inspection are listed in Attachment 2 to this
report. A list of acronyms used in this report is provided in Attachment 3.
II.
Findings
A.
Visual Observation of Plant Equipment
During this inspection, the inspectors performed walkdown inspections of portions of
plant systems, structures, and components (SSCs) to determine their current condition
and to attempt to observe aging effects. The inspectors noted debris such as pieces of
wire, plastic, and tape in the residual heat removal (RHR) pump rooms left from
previous maintenance. The applicant initiated corrective action by issuing Condition
Report (CR) 2004103286. In addition, the inspector noted many areas of paint on
stainless steel piping in 2B containment spray pump room. Overall the material
condition at Farley was good and no significant aging management issues were
identified. The following SSCs were observed:
Reactor Building Spray System
Spent Fuel Cooling System
Chemical and Volume Control
Spent Fuel Pool Cooling Systems
Component Cooling Water
Diesel Generators
Cranes
Spent Fuel Pool
Fire Water Pumphouse
Service Water Intake Structure
Electrical Transformer Area
B.
Review of Mechanical Aging Management Programs
1.
Reactor Vessel Surveillance Program
The Reactor Vessel (RV) Surveillance Program is an existing program credited in the
LRA as a program for managing RV irradiation embrittlement. The applicants program
consists of periodic testing of RV surveillance capsules and updating calculations for
fracture toughness Upper Shelf Energy (USE) and Reference Temperature (RT). The
2
applicant has removed capsules approximating a fluence level of 60 Effective Full Power
Years (EFPY) and plans to remove a final capsule at approximately 80 EFPY. The
applicant also imposes pressure and temperature limits on plant operations. The
applicant has recently performed calculations which showed that USE complies with
requirements of 10 CFR 50 Appendix G and projected RT meets 10 CFR 50.61
screening criteria.
The inspectors reviewed the LR program and other related documentation, the LR
commitment data base, and calculations and held discussions with applicant personnel.
The inspectors concluded that the applicant had continued to comply with the existing
program to manage RV embrittlement and adequate guidance was in place to ensure
aging effects will be appropriately managed for RV embrittlement for the period of
extended operation.
2.
Flow Accelerated Corrosion (FAC) Program
The FAC program is an existing program credited for management of flow accelerated
corrosion which will be enhanced to add the auxiliary feedwater pump turbine exhaust
piping to the scope of the program. The applicants program consists of periodic
inspections and evaluation of the data to detect wall thinning and compare data to
current requirements and historical data values to predict when and if minimum wall
thickness will occur. Piping replacements are planned prior to wall thickness reaching
minimum requirements. Inspection points and inspection periodicity are periodically
adjusted dependant on inspection data, plant operations history, and industry
information.
The inspectors reviewed LR program documentation, the LR commitment data base,
selected plant inspection data, site procedures, and the Program Health Report and also
discussed the program with responsible personnel. The program has functioned well to
assure timely piping replacements and appropriately adjust inspections according to
plant and industry experience. The inspectors concluded that the FAC program is
adequately functioning and there is reasonable assurance that FAC will be adequately
managed through the period of extended operation.
3.
Reactor Vessel Internals Program
The Reactor Vessel Internals Program is a new program intended to supplement the
ongoing internals inspections being performed as required by the American Society of
Mechanical Engineers (ASME) Code. It is credited as a program for managing cracking,
reduction in fracture toughness, thermal embrittlement, void swelling, and changes in
material dimension due to void swelling. The applicant plans to stay involved with the
industry groups, EPRI Materials Reliability Program Reactor Vessel Internals Issue Task
Group and the Westinghouse Owners Group, which are developing the model for the
inspection.
The inspectors reviewed LR program documentation, the LR commitment data base,
and the proposed procedure for this program and held discussion with responsible
applicant personnel. The inspectors concluded that the Reactor Vessel Internals
Program is planned and the applicant is appropriately involved with industry initiatives to
assure an adequate program will be initiated. In addition, the applicant is committed to
3
submit the inspection plan for NRC review at least 24 months prior to entering the
periods of extended operation.
4.
Flux Detector Thimble Inspection Program
The applicant currently inspects flux thimble tubes, in accordance with general plant
procedures, for wear in response to previous industry problems in this equipment. The
applicant plans to formalize this inspection into a specific procedure. The program
includes eddy current testing, trending and evaluating wear rates, repositioning tubes as
necessary, and capping tubes if necessary, such as when the tube cannot be inspected.
In addition, the applicant plans to submit Unit 1 wear information and results of the
upcoming Unit 1 testing to NRC.
The inspectors reviewed LR program documentation, site procedures, the proposed
formal procedure, and plant data and held discussions with applicant personnel. The
inspectors concluded that the applicant had in the past conducted adequate inspections
to manage wear of flux thimble tubes and plans to formalize this program. There is
reasonable assurance that the intended function of the flux thimble tubes will be
maintained through the period of extended operation.
5.
NiCrFe Component Assessment Program
The NiCrFe Component Assessment Program will be a new program developed to
address industry concerns regarding primary water stress corrosion cracking in nickel
alloy components exposed to reactor coolant water. The applicant plans to assess
susceptibility to cracking and perform inspections as necessary. The applicant is active
in the industry group assessing this area. Components containing nickel alloys include
the top and bottom RV penetrations, the RV flange leakage monitoring tube, and butt
welds for piping to the RV, pressurizer and steam generators. It should be noted that a
number of inspections have been performed as required by NRC generic
communications. Inspections to date have included the RV top and bottom heads, six
butt welds on the Unit 2 pressurizer, and one safe end butt weld on Unit 2 RV with no
problems found. The applicant plans to visually inspect all Unit 1 butt welds during the
upcoming 2004 outage. An existing procedure is in place for currently planned
inspections and a new procedure is planned to incorporate any future changes.
The inspectors reviewed LR program documentation, the LR commitment data base, the
existing procedure, the proposed procedure, plant inspection correspondence and
results, and outage ISI plans and discussed this program with responsible applicant
personnel. The inspectors concluded that ongoing inspections were being performed of
nickel based alloys and adequate enhancements were planned for management of
cracking in nickel base alloys. There is reasonable assurance that the intended function
of nickel based alloys components will be maintained through the period of extended
operation.
6.
Fatigue Monitoring Program
The Fatigue Monitoring Program is a new program which will be used to monitor fatigue
of the metal piping and components that form the reactor coolant pressure boundary.
The applicant currently conducts thermal plant equipment cycle counting, as required by
Technical Specifications, manually. The applicant plans to modify the program to use
4
computer software to automatically count monitored cycles using installed plant
equipment and add additional transients including pressurizer heat up, small step load
increase/decrease, and large step load increase. Cycles will be monitored to confirm
these remain below those assumed in the fatigue analysis. In addition, the applicant
plans to monitor stress base fatigue of the pressurizer surge line and lower region as
well as thermal stratification at susceptible locations. For selected locations where
environmental factors indicate that fatigue life may not be maintained, the applicant
plans to conduct further refined analysis or replacement.
The inspectors reviewed LR program documentation, the LR commitment data base,
current site procedures, the proposed procedure, and current plant data and discussed
the program with responsible applicant personnel. The inspectors concluded that the
program had been implemented in accordance with current requirements and
appropriate enhancements were planned. When implemented as described, there is
reasonable assurance that cracking due to fatigue for the reactor coolant pressure
boundary components and piping will be managed through the period of extended
operation.
7.
Inservice Inspection Program
The Inservice Inspection (ISI) Program is an existing program, subject to regular NRC
inspections, which has recently been updated to a risk informed ISI Program and
submitted to NRC. In addition, the applicant plans to enhance inspections or perform
flaw tolerance evaluation for cast austenitic stainless steel piping. The applicant has
also enhanced a maintenance procedure to add controls of RV closure stud lubricant.
The inspectors reviewed the LR program documentation, the LR commitment data base,
and site procedures and discussed the program with applicant personnel. The
inspectors concluded that the ISI Program was in place and included elements
described in the LRA. When implemented as described, there is reasonable assurance
that adequate inspections required by the ASME Code will be performed through the
extended period of operation.
8.
The SW system provides a heat sink or removal capability for safety-related equipment
and heat removal from the reactor during normal operations, normal plant shut downs,
and emergency situations. The local river water is pumped to a retention pond that is
maintained at 30 plus day supply level by non-safety-related equipment. The water is
then pumped into the plant by safety-related pumps for cooling of equipment.
The inspectors previously reviewed the Service Water system during the performance of
a NRC Temporary Instruction Procedure 159, Review of Generic Letter 89-13: Service
Water System Problems Affecting Safety-Related Equipment, inspection during the
week of September 6, 2004. This activity was documented in inspection report 500348,
364/2004-004. During the current inspection, the inspectors continued walk down
inspections and reviewed the license renewal implementation effort on the SW system.
Very few physical problems were observed on the SW system passive components.
The licensee corrective action program contained actions to evaluate known passive
problems with the SW system. The majority of these problems had been addressed.
Although most had been addressed, there were potential pipe wall degradation
5
problems in a pair of in-ground pipe expansion boxes. Rain water had partially filled the
boxes on occasions and rusted the exterior of two 42 inch pipes. This condition had not
been evaluated since the problem was placed in the corrective action program (8/31/04).
Due to the NRC teams re-inspection efforts and new system insights, site management
was placing a higher priority on the problem evaluation. A new action item was added
9/22/04 to evaluate the exterior wall thinning. In the long term, the pipe exterior
problems would be captured in the future by a new license renewal program, External
Surfaces Monitoring Program, that has yet to be fully developed.
The licensee did have available an incomplete proposed AMP document to highlight the
existing SW maintenance program and to link this program to LR activities and
commitments. The proposed procedure tied together program elements that are based
on the Generic Letter 89-13, Service Water System Problems Affecting Safety-Related
Equipment, recommendations. With the exceptions documented in the above-
mentioned report, the existing SW program appears to be maintaining the system
integrity.
9.
Electrical Equipment Environmental Qualification(EQ)
The EQ program includes electrical equipment relied upon to remain functional during
and following design basis events to ensure the integrity of the reactor coolant pressure
boundary, ensure the capability to shut down the reactor and maintain it in a safe
shutdown condition, or to ensure the capability to prevent or mitigate the consequences
of accidents that could result in offsite exposures beyond specific guidelines. The
applicant is to maintain equipment in this program and as the equipment approaches
loss of qualification due to aging, repair or replace it with qualified equipment.
The inspectors reviewed the proposed AMP for the existing EQ program. Additionally,
the inspector looked at a program overview document that was being written by
corporate personnel. The proposed documents did contain the elements found in the
applicable NRC documents: NUREG-1801, Generic Aging Lessons Learned Report;
NUREG-0588, Revision 1, Interim Staff Position on Environmental Qualification of
Safety-Related Electrical Equipment, and 10 CFR 50.49, Environmental Qualification of
Electric Equipment Important to Safety for Nuclear Power Plants. The inspectors
discussed program details utilizing existing procedures with corporate and site
personnel. Specific equipment types were discussed as examples. The applicant
planned to review the qualified equipment types against the proposed plant life
extension on a case by case basis. Based on the inspection review, it appears that the
applicant has an existing program that will address EQ life extension.
10.
Overhead and Refueling Crane Inspection Program (ORCI)
The application submittal and NUREG-1801 (Section XI.M23, Inspection of Overhead
Heavy Load and Light Load (Related to Refueling) Handling System) discuss ORCI.
The selected license renewal in-scope cranes handle reactor fuel. The existing site
crane program maintains the selected cranes to limit fuel accidents.
The inspectors reviewed the proposed AMP that highlights the existing program and link
this program to LR activities and commitments. The inspectors reviewed the existing
crane inspection procedures that will be used over the long term for crane maintenance
activities. The crane components aging effects that are in the program are general
6
corrosion of structural girders, bolting, and rails. The items are routinely visually
inspected for degradation. The inspectors walked down the available cranes at the time
of the inspection (spent cask and spent fuel bridge crane) with engineering and
maintenance personnel. The other cranes in the applicants program are the reactor
polar crane and the reactor cavity manipulator crane, which are inside the containments
and inaccessible with the reactors in power operation. The applicants program is
dependent on vendor inspections and vendor oversight. Based on the inspection
review, it appears that the applicant has an existing program that will assure proper
crane maintenance and operation.
11.
External Surfaces Monitoring Program
This is a new condition monitoring program that will be implemented through periodic
inspections of external surfaces of carbon steel, low alloy steel and other materials
susceptible to material loss in components requiring aging management for license
renewal. The program will use visual inspection to identify potentially unacceptable
conditions where degradation of protective coating or corrosion of the underlying base
metal could result in an inability of the component to perform its intended function. The
inspectors reviewed the program documentation, discussed the program with
responsible applicant personnel, and reviewed proposed procedures which implemented
the scope and actions of this program. The inspectors performed field walk downs of a
sample of equipment within the program scope to assess the present material
condition. The aging management program scope, inspection attributes, and
acceptance criteria are described in FNP-IMP-AMP-18, External Surfaces Monitoring
Program License Renewal Implementation Package, dated 9/9/04.
As mentioned in paragraph 8 above, during the field walk downs of equipment within the
program scope the inspectors identified significant exterior rust on service water piping
within underground service water distribution valve box enclosures. These valve boxes
were not specifically included in the detailed scope description of program inspection
areas. The inspectors discussed this issue with the applicant and learned that a
Condition Report (CR) had been recently written on the conditions in the valve boxes,
however it did not address the rusted pipe and potential for pipe wall thinning. The
applicant wrote additional CRs and maintenance work orders to correct the problems.
Additionally, the applicant recognized that these service water valve boxes and several
others similar should have been included in the External Surfaces Monitoring Program.
The applicant amended the proposed External Surfaces Monitoring Program Manual,
FNP-O-M-TMD, Version A, Table 2, Plant Areas Required to be Inspected by the
External Surfaces Monitoring Program, to include these valve box enclosures.
The inspectors concluded that the applicant had conducted adequate historic reviews of
plant specific and industry experience to determine aging effects. The applicant had
provided adequate guidance to ensure aging effects will be appropriately assessed and
managed. When implemented, there is reasonable assurance that the intended
function of the SSCs will be maintained through the period of extended operation.
12.
One Time Inspection Program
This is a new program which performs one time inspections to verify that an aging effect
is not occurring or that the aging mechanism is so slow that it will not effect the
component of interest before the end of the extended period of operation. The
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inspections will be performed within a window of five years immediately preceding the
extended period of operation. The aging effect to be assessed is selective leaching in
cast iron, bronze, brass, and other alloys. The inspectors reviewed the program
documentation, discussed the program with responsible applicant personnel, and
reviewed proposed procedures which implemented the scope and actions of this
program. The aging management program scope, inspection attributes, and
acceptance criteria are described in FNP-IMP-AMP-20, One Time Inspection Program
License Renewal Implementation Package, dated 9/9/04.
The inspectors concluded that the applicant had conducted adequate historic reviews of
plant specific and industry experience to determine aging effects. The applicant had
provided adequate guidance to ensure aging effects will be appropriately assessed and
managed. When implemented, there is reasonable assurance that the intended
function of the SSCs will be maintained through the period of extended operation.
13.
Borated Water Leakage Assessment and Evaluation Program
This is an existing program that manages the aging effect of loss of material due to
borated water leakage onto carbon steel and low alloy steel structures and components
or electrical components. The program was developed in response to NRC Generic Letter (GL) 88-05, Boric Acid Corrosion of Carbon Steel Reactor Pressure Boundary
Components in PWR Plants. The inspectors reviewed the program documentation,
discussed the program with responsible station personnel, and reviewed procedures
which implemented the program. Additionally, the inspectors reviewed station actions
for identification, trending and correction of previous and existing boric acid leaks. The
aging management program scope, inspection attributes, and acceptance criteria are
described in FNP-IMP-AMP-07, Boric Acid Corrosion Control Program License Renewal
Implementation Package, dated 9/9/04.
The inspectors concluded that the applicant had conducted adequate historic reviews of
plant specific and industry experience to determine aging effects. The applicant had
provided adequate guidance to ensure aging effects will be appropriately assessed and
managed. As implemented, there is reasonable assurance that the intended function of
the SSCs will be maintained through the period of extended operation.
14.
Buried Piping and Tanks Inspection Program
This is a new inspection activity credited for aging management of external surfaces on
buried carbon steel piping and tanks. Buried components will be visually inspected
when they are excavated for any reason. Preventive measures were originally
implemented during installation in accordance with standard industry practices for
external coating and wrappings. The inspections will verify the adequacy of the
protection. This new program will be implemented prior to the period of extended
operation. The inspectors reviewed the program documentation, discussed the program
with responsible applicant personnel, and reviewed existing and proposed procedures
which implemented the scope and actions of this program. The aging management
program scope, inspection attributes, and acceptance criteria are described in FNP-
IMP-AMP-19, Buried Piping and Tank Inspection Program License Renewal
Implementation Package, dated 9/9/04.
8
The inspectors reviewed the proposed changes to the existing General Excavating and
Trenching Guidelines, FNP-0-GMP-81.0, Version 8, for this program to verify that
adequate reference was included to assure the inspections were performed. It was
noted and discussed with the applicant that the Excavation Permit Data Sheet and
Instructions, of this procedure did not include a reference to assure the aging
management program inspection was performed. The applicant amended the proposed
procedure to include this reference on the Excavation Permit Data Sheet.
The inspectors concluded that the applicant had conducted adequate historic reviews of
plant specific and industry experience to determine aging effects. The applicant had
provided adequate guidance to ensure aging effects will be appropriately assessed and
managed. When implemented, there is reasonable assurance that the intended
function of the SSCs will be maintained through the period of extended operation.
15.
Water Chemistry Control Program
This is an existing program which will manage loss of material and cracking within
system components and structures. The program includes monitoring of detrimental
species and addition of chemical additives and is subdivided into primary, secondary
and closed cooling water chemistry sections. There were no program changes required
for license renewal. The inspectors reviewed the program documentation, discussed
the program with responsible applicant personnel, and reviewed existing procedures
which implemented the scope and actions of this program. The inspectors reviewed
trending of chemistry parameters, actions taken for identified conditions in which
parameter limits were exceeded, and applicant self-assessments of the program.. The
aging management program scope, inspection attributes, and acceptance criteria are
described in FNP-IMP-AMP-02, Water Chemistry Control Program License Renewal
Implementation Package, dated 9/9/04.
The inspectors concluded that the applicant had conducted adequate historic reviews of
plant specific and industry experience to determine aging effects. The applicant had
provided adequate guidance to ensure aging effects will be appropriately assessed and
managed. As implemented, there is reasonable assurance that the intended function of
the SSCs will be maintained through the period of extended operation.
16.
Fuel Oil Chemistry Program
This enhanced program is credited for managing the aging effects due to loss of
material on Fuel Oil system components for the Emergency Diesel Generators and the
diesel driven fire pump. The program is governed by Technical Specifications and
includes surveillance procedures to mitigate corrosion and actions to minimize exposure
to fuel oil contaminants by verifying the quality of new oil. The program enhancement
includes revision to existing procedures to ensure adequate monitoring and
maintenance of the diesel driven fire pump fuel oil system. The inspectors reviewed the
program documentation, discussed the program with responsible applicant personnel,
and reviewed existing and proposed procedures which implemented the scope and
actions of this program. The inspectors reviewed documentation which established the
current material condition of the fuel oil storage tanks. During the inspection, the
applicant performed an ultra-sonic examination of the diesel driven fire pump fuel oil
storage tank to verify the current material condition (wall thickness) of this tank. The
aging management program scope, inspection attributes, and acceptance criteria are
9
described in FNP-IMP-AMP-12, Fuel Oil Chemistry Control Program License Renewal
Implementation Package, dated 9/9/04.
The inspectors concluded that the applicant had conducted adequate historic reviews of
plant specific and industry experience to determine aging effects. The applicant had
provided adequate guidance to ensure aging effects will be appropriately assessed and
managed. As implemented, there is reasonable assurance that the intended function of
the SSCs will be maintained through the period of extended operation.
17.
Periodic Surveillance and Preventive Maintenance Program
This new program is a conditioning monitoring program credited for managing the aging
effects applicable to the components included in the program, that are not managed by
other aging management programs, by performance of repetitive tasks or surveillance.
The components included in this program are the tank diaphragms for the Boric Acid
Tanks, Reactor Makeup Water Storage Tanks, and Condensate Storage tanks.
Additionally, the High Head Safety Injection (HHSI) Pumps casings were added to the
scope of this program to monitor loss of material due to clad cracking and subsequent
corrosion of the carbon steel base metal. The inspectors reviewed the program
documentation, discussed the program with responsible applicant personnel, and
reviewed existing and proposed procedures which implemented the scope and actions
of this program. Additionally, the inspectors reviewed documentation of past
performances of periodic ultra-sonic and visual examinations of the HHSI pump casings.
The aging management program scope, inspection attributes, and acceptance criteria
are described in FNP-IMP-AMP-24, Periodic Surveillance and Preventive Maintenance
Activities License Renewal Implementation Package, dated 9/9/04
The inspectors concluded that the applicant had conducted adequate historic reviews of
plant specific and industry experience to determine aging effects. The applicant had
provided adequate guidance to ensure aging effects will be appropriately assessed and
managed. As implemented, there is reasonable assurance that the intended function of
the SSCs will be maintained through the period of extended operation.
18.
Steam Generator Program
The inspectors reviewed the document FNP-IMP-AMP-10 Steam Generator Program
License Renewal Implementation Package. The steam generator inspection program is
a well established program which is being credited as an AMP for license renewal. The
document specified the following three enhancements. The steam generator program in
accordance with the technical Specifications will be continued during the period of
extended operation. The program will be based upon NEI 97-06, Steam Generator
Program Guideline or its successors. And the program will include monitoring of
secondary side internal components whose failure could prevent the steam generator
from fulfilling its intended safety-related function.
The inspectors reviewed proposed changes to existing procedures Farley Steam
Generator Strategic Plan and NMP-ES-004, SNC Steam Generator Program (FNP,
VEGP).
10
19.
Fire Protection
The inspectors reviewed the document FNP-IMP-AMP-15 Fire Protection Program
License Renewal Implementation Package, 9/9/2004. It described that the fire
protection (FP) program is a long established plant program and that of the many
existing FP surveillances only some are being credited for license renewal. The
inspector reviewed a proposed revision to plant procedure FNP-0-M-32 Farley Nuclear
Plant Master List of Fire Surveillance, Version 21.0. That document had attachment
tables listing all the FP surveillances and the ones to be credited for LR were marked in
the margin as LR commitments. The inspectors selected ten credited surveillances and
asked the applicant to retrieve the records of the last two performances of those tests.
The applicant retrieved the records and after review the inspectors concluded that eight
of the tests were being accomplished successfully, but there were problems with two
test.
The applicant told the inspectors that the surveillance FNP-0-FSP-2 Fire Pump
Functional Test, had been voided and was being replaced by three other procedures
FNP-0-FSP-203.4, 203.5, and 203.6 which test the fire pumps. The inspectors reviewed
the records of the last two performances of the latter three procedures and found them
satisfactory. The inspectors inquired of the applicant if there were other inaccuracies in
procedure 32, the Master List of Surveillances. The inspectors were shown an Action
Item number 2004204686 initiated 9/30/04 which directed to replace procedure 2 with
the latter three, correct another typographical error, and add six other surveillance
procedures to the Master List of Surveillances. The applicant subsequently concluded
that under their corrective action system a Condition Report (CR) should have also been
written to address these discrepancies and CR 2004204573 was initiated.
Procedures FNP-1-FSP-7 and FNP-2-FSP-7 Halon System, are semi annual
surveillances to confirm system operability of the Halon fire suppression system in six
rooms of the auxiliary building. The inspectors reviewed the last two performances of
each procedure and observed that the test results are marked as unsatisfactory
because several of the Halon bottles have lost pressure over time and are not being
recharged by management decision. Halons are bromofluorocarbons and because
Halons destroy the atmospheric ozone layer, their production has been phased out.
Depressurized tanks would have to be sent off site at great expense to be recharged
and the decision was made in late 2000 to abandon the system in place and discontinue
surveillance testing. However surveillance testing continues with the results being
routinely marked unsatisfactory and the procedure changed to direct that no corrective
action document be initiated for the under pressure bottles.
These Halon systems protect rooms 201 and 2201 (computer rooms), 202 and 2202
(communications rooms), and 235 and 2235 (switchgear rooms) which are designated
as fire areas 1-14, 2-14, 1-15, 2-15, 1-23, and 2-23 respectively. The inspectors
reviewed document ABN 99-0-1491 which contains a 10 CFR 50.59 evaluation of the
acceptability of modifying the FSAR description of the Halon system to delete it as a
regulatory requirement. The document states that the NRC in its Fire Protection Safety
Evaluation Report (SER) of February 12, 1979 discussed the existence and acceptability
of these Halon systems and indicated that the fire protection features present in these
rooms would satisfy the provisions of the NRCs Appendix a to the Branch Technical
Position (BTP) APCSB 9.5-1. The document further states that the applicant reviewed
BTP 9.5-1 and determined that a Halon suppression system, or any type of a fixed
11
suppression system is not required in these rooms and that the intent of the positions as
stipulated in the BTP 9.5-1 will be met with or without a fixed automatic fire suppression
system present in these rooms.
The inspectors observed that the revised wording that was placed in the FSAR was not
clear that the Halon system is being abandoned. It stated typically for the six entries
There is an automatically acting Halon fire suppression system installed in the room,
however, there is a manual CO2 hose station in the adjacent area that fulfills the intent
of (BTP) APCSB 9.5-1". The inspectors commented that this wording seems to say that
the Halon system is still installed and fully operable when in fact it is degraded and
gradually losing capacity as the bottles depressurize with age.
The inspectors further asked for the last two records of the surveillances that test fire
loop piping flow capacity. The inspectors reviewed the last two performance records for
FNP-0-FSP-53 performed every three years. This test installs a test pressure gauge
and a hose on two hydrants at the remote ends of the fire water piping loop. It
measures pressure with no flow and then at pressure at two different flow rates. The
data is plotted on a graph and the results compared to ones from previous tests. The
acceptance criteria is that flow capability has not decreased more than 20% from the
original base line tests performed in 1986.
The test performed on March 25, 1999, found acceptable results for hydrants located
near the diesel building and near the low voltage switchyard, but unacceptable results
for hydrants located near the Service Water Intake Structure (SWIS). The test
performed on June 3, 2002, concluded with unsatisfactory results saying the data was
anomalous and did not fit the expected curve. The inspectors inquired what was being
done about these two successive tests with unsatisfactory results. The inspector was
shown a document RER 03-0209 which was a request for engineering review initiated in
2003 requesting the corporate engineering staff to review the unsatisfactory test results
and propose a course of action. The completed RER was actually being approved
during the inspection and the proposed actions were not certain. The document stated
that it was thought that the hydrants may have been mislabeled in the procedure and/or
in the field causing inconsistent test methods and there had been reports of a loop
piping leak that could have effected test results.
The inspectors concluded that the fire protection program was being implemented but
there has not always been timely resolution of unsatisfactory test results. These matters
will be reviewed further during future inspections focused on fire protection. This issue
will be identified as Unresolved Item 50-348,50-364/2004-009-001.
C.
Review of Electrical Aging Management Programs
The Farley LRA concluded that the only electrical components that require an aging
management program are electrical cables and connectors. Electrical equipment,
including cables, that are already subject to the 10 CFR 50.49 environmental
qualification (EQ) program are aging managed by that program. The applicant
considers the EQ program subject to a Time Limited Aging Analysis (TLAA) to
demonstrate that EQ components qualified life can be extended an additional 20 years
or ensure that they will be replaced at the appropriate time.
12
At Farley there is an electrical cable system called Oil-Static Cables which are in the
scope of license renewal. It is a pressurized oil insulated buried electrical cable system
that provides power from the switchyard to the auxiliary startup transformers. The
buried portion of system is included in the Buried Piping and Tank Inspection AMP and
the exposed ends are included in the External Surfaces Monitoring Program. The
applicant concluded that the oil immersed conductors require no AMP and the
inspectors agreed with that conclusion.
The Non-EQ Cable program is the only cable program credited for license renewal.
This is a new AMP to be established prior to the period of extended operation and it
consists of three parts.
For Non-EQ cables accessible for visual observation a representative sample of in-
scope cables exposed to adverse localized environments caused by heat and/or
radiation will be visually inspected at least once every 10 years. Cables and
connections i.e. connectors, splices, terminal blocks, fuse holders and electrical
penetration assembly pigtail leads will be inspected for evidence of surface
embrittlement, discoloration, cracking or surface contamination.
The inspectors reviewed the Non-EQ Cables Program Implementation Package FNP-
IMP-AMP-21. The document contained two proposed procedures. FNP-0-EMP-
1372.01 Adverse Localized Equipment Environments Inspection directs the applicant to
survey the entire plant to identify locations of adverse localized environment for heat
and/or radiation which contain in-scope cables. These identified locations are to be
included in the second procedure FNP-0-EMP-1372.02 Cables and Connections
Inspection. This procedure directs the applicant to periodically inspect cables in the
identified adverse environment locations for surface anomalies and to evaluate the
significance of any anomalies found.
The second part of the AMP specifies that all in-scope instrumentation circuit cables
with high voltage, low signal levels which are installed in adverse environments will be
tested at least once every ten years. The applicant has identified a contractor to provide
this service but has not yet determined the test method to be employed.
The third part of the AMP concerns inaccessible medium voltage cables which may be
water submerged while energized. The AMP specifies that periodic actions will be taken
such as inspection for and removal of water collection in cable manholes and conduits.
The inspectors reviewed proposed procedures FNP-0-GMP-60.1 General Inspection
Outdoor Electrical Duct Run Pull Boxes and FNP-0-GMP-60.2 General Inspection
Outdoor Electrical Duct Run Pull Boxes (Non-Safety Related). These procedures had
been recently approved and there were no records of past inspections to be reviewed.
The inspector was told that in support of the LRA most electrical pull boxes on site had
been opened and inspected. Only a few were found to have a water accumulation.
Several had been reinspected as a repetitive task, but it was decided to establish the
above referenced procedures to do rotating periodic inspections of pull boxes, record as
found water level and pump any water from the boxes. For several boxes that were
found during the LRA inspections to have significant amounts of water, inspections will
be done every three months to establish a trend and to determine if box modifications
are needed.
13
For inaccessible in-scope medium voltage cables exposed to significant moisture the
cables will be tested at least once every 10 years to provide an indication of the
condition of the insulation. The specific type of test and acceptance criteria has yet to
be determined.
The inspectors concluded the proposed program was acceptable. The proposed
program agrees with the GALL recommendations and is comparable to those of past
applicants.
D.
Review of Structural Aging Management Programs
1.
Structural Monitoring Program
FNP-IMP-AMP-13, Structural Monitoring Program License Renewal Implementation
Package provides basis information, program commitments and procedural
implementation for the license renewal aging management program. Section 3.0
contains a Program Commitment Cross Reference Table which identifies the new or
existing commitment, the commitment source and the procedural implementation. FNP-
0-SYP-18, Maintenance Rule Structure Monitoring Program, Version 3 monitors the
conditions of structures and structural components by conducting periodic walkdowns
and visual inspections in accordance with the requirements and guidance in the
maintenance rule, 10 CFR 50.65 and Regulatory Guide (RG) 1.160, Rev. 2. The FNP
Structural Monitoring Program (SMP) assesses the conditions of the buildings and
structures, including accessible areas that may be below ground. Items identified during
the SMP inspections are entered into an observation database. The acceptance criteria
contained in FNP-0-SYP-18 is in accordance with ACI-349-3R, Evaluation of Existing
Nuclear Safety Related Concrete Structures. The applicant will continue to address
masonry wall considerations consistent with NRC IE Bulletin (IEB) 80-11 and NRC
Information Notice (IN) 87-67 as stated in FNP-IMP-AMP-13. The FNP SMP will also
include provisions to monitor buried commodities, inaccessible areas during opportune
soil excavations, submerged portions of the Service Water Intake Structure (SWIS),
structural portions of the Oil Static Pump House, and in-scope support features for
ATWS, SBO, and fire protection safe shutdown equipment in the Turbine Building.
Structures are inspected every 5 years based on FNP-0-SYP-18 which is similar to NEI 96-03, Industry Guidelines for Monitoring the Condition of Structures at Nuclear Power
Plants.
The inspectors performed a walkdown of the Unit 1 tendon access gallery to assess the
conditions of the concrete walls. The inspectors observed leaching in areas along the
concrete wall and approximately 1/2" of water at some locations which had filtered
through the concrete walls. Electrical wiring conduits which are no longer in use remain
in the Unit 1 tendon gallery and the applicant noted this as a housekeeping issue. The
tendon cans in the Unit 1 tendon gallery were properly aligned and some humidity was
observed around the cans due to the existing conditions of the gallery. The foam-like
material was missing in some gaps between the bottom of the containment basemat
and beams that extend along the tendon gallery. The inspectors concluded that the
overall structural condition of the tendon gallery was adequate with no signs of structural
deterioration.
A number of tendon grease stains were observed around the exterior of the
containments; based on observations from a distance. The grease leakage appears to
14
be inactive or progressing very slowly. The applicant indicated that these areas had
been previously identified under the SMP and are being monitored.
Section 7.2.1 of FNP-0-GMP-81.0, General Excavating and Trenching Guidelines,
specifies the inspection of exposed concrete structures due to excavation by a qualified
engineer. This addresses the aging mechanisms applicable to below-grade concrete
structures and attachments that may be exposed to groundwater or other adverse
conditions such as settlement. The inspectors questioned whether deterioration of
concrete structures exposed during an excavation may be considered representative of
the inaccessible concrete surfaces. The applicant indicated that most of the buried
concrete structures at FNP are designed independent of each other and that FNP-0-
GMP-81.0 has been modified to require that whenever a structure is excavated it will be
inspected for deterioration . The inspectors considered this approach acceptable.
The inspectors reviewed Maintenance Rule Structural Monitoring 1997 Baseline
Inspections Report which documents structures and structural components which are
monitored under the 10 CFR 50.65 scope. FNP stated in the report that These
structures remain capable of performing their intended functions. The inspectors did
not identify any significant items in the report which required additional assessment for
license renewal purposes.
The inspectors conducted a walkdown of the Service Water Intake Structure (SWIS)
which is also monitored under the SMP. During the walkdown, the inspectors identified
some minor ponding on the roof of the SWIS. The inspectors also observed
approximately 2"-4" of standing water in valve boxes (VB) 1 and 2 adjacent to the SWIS
which has caused corrosion of anchor bolts associated with the service water main pipe
supports. Condition Report 200300128 was written to address this issue and Work
Order M200176301 to perform the work. Prior flooding of the valve boxes was
evidenced by water marks along the concrete wall. This could possibly lead to long term
aging management issues if not corrected adequately. The sealant material between
the service water 42" piping and the wall in VB-2 appeared to be degraded causing a
gap in the area specified. The applicant identified the issues during the 1st 5-year
Periodic Maintenance Rule Structural inspections and indicated that additional measures
such as repainting of the components will be taken to minimize corrosion and the
infiltration of water into the valve boxes by resealing the entrances to the valve boxes.
The applicant specifies submerged portions of the SWIS to be inspected within the
scope of license renewal.
During the 1st 5-year Periodic Maintenance Rule Structural inspections which took place
between April 2000 and October 2001, the applicant identified 10 areas which could
become a degradation problem. Deficiency Reports were written to address 7 of the 10
identified areas and are documented in Farley Condition Report 2001001490. One of
the areas included groundwater in auxiliary building room 194 from the joint between the
auxiliary building and containment. Work order 2002298 was written to address this
issue. The inspectors toured auxiliary building room 2175 which also had the same
problem and identified no visible leakage. There were no apparent signs of significant
degradation of the hydrophilic grout between the auxiliary building and Unit 2
containment.
The inspectors performed a walkdown of the Diesel Cable Tunnel and observed no
visible groundwater leakage. No unusual conditions were observed along the cable
15
ducts, bolts or concrete walls. Water had collected in the sump which indicated that the
system was functioning properly by pumping water out of the tunnel. The Diesel
Generator Building supports, skid pads, bolts and concrete walls appeared to be in
acceptable conditions for license renewal purposes.
2.
Integrated Leak Rate Test (ILRT) Program
Procedure FNP-1-STP-167, Containment Integrity Examination, Revision 1 identifies
Containment Type A testing which is required once every 10 years in accordance with
Option B, 10 CFR Part 50 Appendix J requirements. NRC Regulatory Guide 1.163
requires a general visual examination during two other refueling outages, approximately
40 months apart. The acceptance criteria is defined as no evidence of containment
damage or deterioration which could affect containment leakage or structural response
to internal pressure.
The inspectors reviewed the Farley Unit 1 Fifth Periodic ILRT final report issued June
1995 and the Unit 2 Fourth Periodic ILRT final report issued July 1994. Both reports
indicated leakage test rates below the acceptance limit of 0.1125 wt %/day; however,
Unit 2 final leakage rate was 0.1112 wt %/day which is within 1 % of the acceptance
limit. The value continues to be below the acceptance limit and includes penalties
associated with localized leak rate tests performed, therefore the program is adequately
testing the integrity and leak rate of the containment.
3.
ASME Section XI, Subsection IWE/IWL/IWF Inservice Inspection Program
The FNP ASME Section XI, Subsection IWE/IWL/IWF Inservice Inspection (ISI)
Program was developed considering the requirements of 10 CFR 50.55a, and the ASME
Code (1992 Edition and Addenda). FNP-IMP-AMP-01b,ISI Program (IWE,IWL,IWF)
License Renewal Implementation Package, provides basis information, program
commitments and procedural implementation for the license renewal aging management
program. Section 3.0 contains a Program Commitment Cross Reference Table which
identifies the new or existing commitment, the commitment source and the procedural
implementation.
The inspectors reviewed FNP ASME Section XI, Subsection IWE ISI 2003 report and
noted that the applicant identified bowing of the Unit 1 liner plate. Liner thickness
measurements were performed and the results of the area where the bowing exists was
within the acceptance criteria. This could be a potential aging management concern
due to a potential for corrosion in the void between the liner plate and the containment
wall. The applicant is aware of the issue and is monitoring the liner under the IWE
inspections.
The inspectors reviewed the most recent FNP containment inservice inspection results.
In general, the inspections found the containment structures acceptable. FNP-0-NDE-
100.25, Visual Examination VT-3 for IWE Components and FNP-0-NDE-100.24,
Visual Examination VT-1 for IWE Components provides requirements for performing
general and detailed visual examination of Class MC pressure retaining components
and their integral attachments. The inspectors concluded that the applicants ISI/IWE
Program is an adequate aging management program to provide reasonable assurance
that the intended function(s) of the containment steel components will be maintained
during the extended period of operation.
16
4.
Service Water Pond Dam Inspection Program
Procedure FNP-IMP-AMP-05, Service Water Pond Dam Inspection Program License
Renewal implementation Package, provides basis information, program commitments
and procedural implementation for the license renewal aging management program.
The applicant has included the service water pond dam and spill way to be inspected in
accordance with NRC RG 1.127, Revision 1, Inspection of Water-Control Structures
Associated with Nuclear Power Plants. Procedure FNP-0-ETP-4389, Service Water
Storage Pond Dam Biennial Inspection, describes the regular biennial inspection of the
service water pond dam at FNP. The service water pond dam inspection includes the
earthen dam, the service water pond embankments and the spillway slopes.
The inspectors reviewed the regular biennial inspection reports of the FNP Service
Water Storage Pond Dam and related facilities conducted on August 22, 2002 and
another in 2000. The 2000 inspection identified 8" settlement of the slab at the end of
the discharge flume. The inspectors conducted a walkdown of the area mentioned and
verified that the slabs had been fixed appropriately. There were no signs of abnormal
seepage, erosion, unusual settlement or displacement of the dam or dike structures.
Some small trees were observed growing at various locations along the slope of the
embankment which could possibly result in long term aging management concerns if not
corrected due to seepage of the earthen dam. The applicant has identified these issues
in their inspection reports and plans to eliminate the vegetation identified surrounding
the dam. During the walkdown of the spillway structure, the inspectors observed that
the spillway structure was free of debris and the retaining walls were performing their
intended function with no visible deformation.
The inspectors reviewed the October 8, 1998, FNP Cooling Water Storage Pond Dam
audit conducted by Federal Energy Regulatory Commission (FERC) and the NRC. The
report states , ...no conditions were found that should adversely affect the immediate
safety and permanence of the project structures. The edges along the embankment of
the dam did not present any significant visible soil erosion. The inspectors concluded
that the service water storage pond dam is capable of maintaining its integrity.
III.
Conclusions
The inspection concluded that LR activities were conducted as described in the License
Renewal Application (LRA) and that documentation supporting the application is in an
auditable and retrievable form. The inspection also concluded that existing aging
management programs are generally functioning well and that when all the programs
are implemented as described in the LRA, there is reasonable assurance that the
intended function of vital plant systems, structures, and components will be maintained
through the period of extended operation.
Exit Meeting Summary
The results of this inspection were discussed on October 1, 2004, with members of the
applicant staff in an exit meeting open for public observation at the Houston County
Administrative Building, 462 North Oates Street, Dothan, AL 36303. The applicant
acknowledged the results presented and presented no dissenting comments. The inspectors
asked if any of the applicant materials reviewed were proprietary and were told none were
proprietary.
Attachment 1
PARTIAL LIST OF PERSONS CONTACTED
Applicant
B. Badham, Security Manager
R. Bayne, Performance Analysis supervisor
L. Bohn, Consultant
S. Chesnut, Engineering Manager
M. Crisler, Senior Engineer
J. Fridrichsen, Project Manager License Renewal
R. Fucich, Work Controls, Supt.
P. Ghosal, Senior Engineer
P. Harlos, Health Physics Manager
J. Hornbuckle, Senior Engineer
R. Johnson, Asst. Gen. Manager Operations
J. Kale, Performance Analysis
D. Lisenby, Engineering Support
T. Livingston, Chemistry Manager
W. Lunceford, Consultant
M. MacFarlane, Project Manager License Renewal
M. Maddox, Sr. Emergency Preparedness Spec.
R. Martin, Operations Manager
J. Mulvehill, Senior Engineer
C. Pierce, License Renewal Services Manager
D. Stephens, Senior Engineer
M. Stinson, Vice President, Farley Project
B. Thomas, Corp. Communications
R. Tyler, Engineering Support Manager
R. Vanderbye, Emergency Preparedness Coordinator
R. Vierkandt, Health Physics
NRC
H. Christensen, Deputy Division Director, DRS, RII
R. Fanner, Resident Inspector
R. Hannah, RII Office of Public Affairs
T. Liu, Project Manager
C. Patterson, Senior Resident Inspector
2
LIST OF DOCUMENTS REVIEWED
Licensing Documents
Joseph M. Farley Nuclear Plant License Renewal Application dated September 2003 and
related NRC Requests for Information and applicant answers
Farley Updated Final Safety Analysis Report
License Renewal Documents
LR AMP Commitment Cross Reference Table Report
Existing Plant Procedures and Programs
NMP-ES-011, Flow Accelerated Corrosion for Plant Piping, Version 1
NMP-ES-011-GL01, FAC Program Guideline, Version 1
FNP-0-AP-63, Conduct of Operations-Engineering Support Department, Version 15.0
FNP-0-M-73, FNP Trending Manual, Version 9.0
FNP-0-ETP-4494, RPV Alloy 600 Material Inspections and Reports, Version 2.0
FNP-0-ETP-4325, Thermal Cycle/Stratification Monitoring, Rev. 3
FNP-1-STP-165, Component Cyclic or Transient Limits, Rev. 10
FNP-0-AP-57, Inservice Inspection and Testing of ASME Class 1, 2, and 3 Systems, Version 8
ES-MIS-311, ISI Program-Including Relief Requests, Version 1.0
ES-MIS-311, Inservice Inspection Plans, Version 1.0
FNP-1-MP-1.0, Independent Inspection Procedure, Version 39.0
FNP-0-ETP-4108, FNP Environmental Qualification Program Implementation
FNP-0-M-60, Environmental Qualification Program Description, Version 5
ES-CEEQ-001, Environmental Qualification Evaluation for Farley Nuclear Plant, Version 2.0
FNP-0-ETP-4385, Service Water Storage Pond Volume Survey Evaluation, Revision 0
SCEW No. 0009E, System Component Evaluation Worksheet, Containment Penetrations, Tab
C.2, Rev. 12, Sht 1 of 6,
FNP-O-STP-24.6, Surveillance Test Procedure, Service Water Buried Pipe Inspection, Version
10, 8/8/03
FNP-0-M-101, Boric Acid Corrosion Control Program, Version 10, 7/27/04
FNP-0-BGP-2, Diesel Generator Fuel Oil Storage Tank Cleaning, Version 6, 3/5/03
FNP-0-CCP-1112, Diesel Fuel Oil Storage Tank Sampling, Version 18, 3/12/03
FNP-0-STP-423, Analysis of a Diesel Fuel Storage Tank Contents, Version 24, 9/18/03
FNP-0-ETP-4496, Engineering Technical Procedure, Corrosion Assessment, Version
FNP-0-SYP-18, Maintenance Rule Structure Monitoring Program, Version 3
FNP-0-GMP-81.0, General Excavating and Trenching Guidelines
FNP-1-STP-167, Containment Integrity Examination, Revision 1
FNP-0-NDE-100.25, Visual Examination VT-3 for IWE Components
FNP-0-NDE-100.24, Visual Examination VT-1 for IWE Components
FNP-0-ETP-4389, Service Water Storage Pond Dam Biennial Inspection
FNP-0-M-32 Farley Nuclear Plant Master List of Fire Surveillance, Version 21.0
Proposed Procedures
FNP-IMP-AMP-06, Reactor Vessel Surveillance Program License Renewal Implementation
Package dated 09/09/2004
3
FNP-IMP-AMP-11, Flow Accelerated Corrosion Program Implementation Package dated
09/09/2004
FNP-IMP-AMP-16, Reactor Vessel Internals Program License Renewal Implementation
Package dated 09/09/2004
FNP-IMP-AMP-17, Flux Detector Thimble Inspection Program Implementation Package dated
09/09/2004
FNP-IMP-AMP-23, NiCrFe Component Assessment Program License Renewal Implementation
Package dated 09/09/2004
FNP-IMP-AMP-22, Fatigue Monitoring Program License Renewal Implementation Package
dated 09/09/2004
FNP-IMP-AMP-01A, Inservice Inspection Program (IWB, IWC, IWD) License Renewal
Implementation Package dated 09/09/2004
NMP-EP-999, SNC Reactor Vessel Internals Program
FNP-0-SYP-TBD, Flux Detector Thimble Inspection Program
NMP-ES-998, SNC NiCrFe Component Assessment Program
FNP-0-SYP-XX.0, Fatigue and Cycle Monitoring Program
FNP-IMP-AMP-08, Overhead and Refueling Crane Inspection Program
FNP-IMP-AMP-09, EQ Program Implementation Package
FNP-IMP-AMP-14, Service Water Program License Renewal Implementation Package
NMP-ES-016, Environmental Qualification Program, Version 1.0
FNP-IMP-AMP-20-BD-01, One Time Inspection Program Basis Document, 9/9/04
NMP-ES-019-GL01, Boric Acid Corrosion Control Implementation Guideline, version 1, August
2004
FNP-IMP-AMP-12, Fuel Oil Chemistry Program, 9/9/04
FNP-IMP-AMP-18, External Surfaces Monitoring Program, 9/9/04
FNP-IMP-AMP-24, Periodic Surveillance and Preventive Maintenance Activities, 9/9/04
FNP-IMP-AMP-19, Buried Piping and Tank Inspection Program, 9/9/04
FNP-IMP-AMP-20, One Time Inspection Program, 9/9/04
FNP-IMP-AMP-07, Boric Acid Corrosion Control Program, 9/9/04
FNP-IMP-AMP-02, Water Chemistry Control Program, 9/9/04
FNP-O-GMP-0.0, Farley Nuclear Plant, General Maintenance Procedure, Mechanical
Maintenance Precautions & Limitations, Version 23, 6/25/04
FNP-O-GMP-81.0, General Excavating and Trenching Guidelines, Version 8, 6/25/05
FNP-O-MP-54.1, Maintenance Procedure, Visual Inspection of Underground Pipes and Tanks,
Version 1, 6/17/04
FNP-O-M-999-LR, One Time Inspection Program Manual, Version 1, 9/7/04
FNP-O-MP-54.2-LR, One Time Examination of Gray Cast Iron and Brass Components for De-
Alloying Corrosion (selective leaching), Version 1, 8/17/04
FNP-O-MP-54.3-LR, One Time Examination of Jacketed Service Water System Piping External
Surfaces, Version 1, 8/17/04
FNP-O-MP-54.5-LR, One Time Examination of TDAFW Pump Turbine Lubricating Oil Cooler,
(lube oil side), Version 1, 8/17/04
FNP-1-SPP-999-LR, One Time Ultra-sonic Examination of the Unit 1 CST Bottom, Version 1,
8/17/04
NMP-ES-019, Nuclear Management Procedure, Boric Acid Corrosion Control Program, Version
1, 9/30/04
FNP-0-CCP-332, Chemical Addition to the Diesel Fuel Oil Storage Tanks, Version 11, 5/20/04
FNP-0-FSP-62, Analysis of a Fire Diesel Fuel Storage Tank contents, Version 4, 5/20/04
FNP-0-FSP-62.1, Fire Diesel Fuel Oil Bottom Sample Quality Appearance Test, Version 1,
4/27/04
FNP-0-M-TBD, External Surfaces Monitoring Program, Version A, 9/7/04
4
FNP-IMP-AMP-15 Fire Protection Program License Renewal Implementation Package,
9/9/2004
FNP-IMP-AMP-21 Non-EQ Cables Program Implementation Package
FNP-0-EMP-1372.01 Adverse Localized Equipment Environments Inspection
FNP-0-EMP-1372.02 Cables and Connections Inspection
FNP-0-GMP-60.1 General Inspection Outdoor Electrical Duct Run Pull Boxes
FNP-0-GMP-60.2 General Inspection Outdoor Electrical Duct Run Pull Boxes (Non-Safety
Related)
FNP-0-AP-63, Conduct of Operations - Engineering Support Department, version 15, 8/18/04
FNP-IMP-AMP-13, Structural Monitoring Program License Renewal Implementation Package
FNP-IMP-AMP-01b, ISI Program (IWE,IWL,IWF) License Renewal Implementation Package
FNP-IMP-AMP-05, Service Water Pond Dam Inspection Program License Renewal
implementation Package
Plant Data/Test Results
Pressure Temperature Limits Report, Unit 1, Rev. 1
Pressure Temperature Limits Report, Unit 2, Rev. 2
WCAP-16221-NP, Analysis of Capsule V from Farley Unit 1 Reactor Vessel Radiation
Surveillance Program, Rev. 0
Inspection results for RV weld APR1-4100-14DM dated 04/09/2004; pressurizer top head butt
welds dated 04/18/2004; and surge line butt weld dated 03/31/2004
Surveillance data for FNP-1-STP-165 dated 01/26/2004
Surveillance data for FNP-0-ETP-4325 dated 07/03/2004 and 08/27/2004
Data table for Unit 1 and Unit 2 RTDs (FNP-0-ETP-4325) covering dates 09/06/2001 through
06/11/2004
Visual Examination Record VT-1, 1B Charging/HHSI Pump, 9/21/04
Visual Examination Record VT-1, 1C Charging/HHSI Pump,9/28/98
Visual Examination Record VT-1, 1A Charging/HHSI Pump, 3/25/03
Visual Examination Record VT-1, 2A Charging/HHSI Pump, 2/19/01
Visual Examination Record VT-1, 2C Charging/HHSI Pump, 4/5/04
Work Order (WO) 0693034, 1A Charging/HHSI Pump Casing NDE-UT, 4/16/03
WO 0693035, 1B Charging/HHSI Pump Casing NDE-UT, 4/16/03
WO 0693036, 1C Charging/HHSI Pump Casing NDE-UT, 4/16/03
WO 0707686, 2A Charging/HHSI Pump Casing NDE-UT, 4/16/03
WO 0693098, 2B Charging/HHSI Pump Casing NDE-UT, 4/16/03
WO 0693099, 2C Charging/HHSI Pump Casing NDE-UT, 4/16/03
Maintenance Rule Structural Monitoring 1997 Baseline Inspections Report
Farley Unit 1 Fifth Periodic ILRT final report issued June 1995 and the Unit 2 Fourth Periodic
ILRT final report issued July 1994
FNP ASME Section XI, Subsection IWE ISI 2003 report
October 8, 1998 FNP Cooling Water Storage Pond Dam Audit
Plant Drawings
D-170976, Piping - Service Water Return to Wet Pit, Revision 0
D-181900, Installation Details for Environmentally Qualified CTMT Penetration Assembly,
Revision 0
5
Miscellaneous Documents
Letter NEL-99-0125, Southern Company to USNRC, Unit 2 Reactor Vessel Surveillance
Capsule Z Results
Letter USNRC to L. M. Stinson; Joseph M. Farley Nuclear Plant, Units 2 and 2 Re: Specimen
Capsule Withdrawal Schedule Revisions dated 03/15/2004
Letter NL-04-0372, Specimen Capsule Withdrawal Schedule Revisions-Additional Information
dated 03/05/2004
Letter NL-04-0264, Standby Specimen Capsule Withdrawal Plans dated 02/23/2004
Flow Accelerated Corrosion Program Health Report through 12/31/2003
Letter ALA-03-7, Flux Thimble Current Data Evaluation for Unit 2 Cycle 15 dated 02/04/2003
Letter ALA-00-015, Transmittal of Corrected Flux Thimble Wear Evaluation Report - 2R13
dated 03/24/2000
Farley Unit 1 RF19 ISI Plans
RER 03-282, Joseph M. Farley Nuclear Plant Units 1 and 2 Alloy 600/82/182 Material
MRP 2003-039, Recommendation for Inspection of Alloy 600/82/182 Pressure Boundary
Components dated 01/20/2004
Letter NL-04-0910, Results of Reactor Pressure Vessel Head Inspections Required by First
Revised NRC Order EA-03-009 dated 05/26/2004
Letter NL-03-1387, Results of Reactor Pressure Vessel Head Inspections Required by Order
EA-03-009 dated 06/30/2003
Letter NL-04-1150; Response to NRC Bulletin 2004-01, Inspection of Alloy 82/182/600
Materials Used in the Fabrication of Pressurizer Penetrations and Steam Space Piping
Connections at Pressurized Water Reactors dated 07/26/2004
Condition Reports
2003000969, License Renewal Auxiliary Building Walkdown Findings the week of 4/14/03
2004102505, Findings in the SW Expansion Valve Boxes 1 and 2
Attachment 2
JOSEPH M. FARLEY NUCLEAR PLANT
AGING MANAGEMENT PROGRAMS SELECTED FOR INSPECTION
Water Chemistry Control Program
Borated Water Leakage Assessment and Evaluation Program
Fuel Oil Chemistry Control Program
External Surfaces Monitoring Program
Buried Piping and Tank Inspection Program
One Time Inspection Program
Periodic Surveillance and Preventive Maintenance Activities
Reactor Vessel Surveillance Program
Flow Accelerated Corrosion Program
Reactor Vessel Internals Program
Flux Detector Thimble Inspection Program
Nicrfe Component Assessment Program
Fatigue Monitoring Program
Service Water Program
Overhead and Refueling Crane Inspection Program
Environmental Qualification Program
Service Water Pond Dam Inspection Program
Structural Monitoring Program
Non-Eq Cables Program
Inservice Inspection Program
Steam Generator Program
Attachment 3
LIST OF ACRONYMS USED
Auxiliary Feedwater System
Aging Management Program
Component Cooling Water System
Condensate Storage Tank
Chemical and Volume Control System
Emergency Core Cooling Systems
Environmental Qualification Program
Farley Nuclear Plant
Fire Protection
LR
NRC Office of Nuclear Reactor Regulation
Request for Additional Information
Residual Heat Removal System
RWMS
Reactor Water Makeup System
Refueling Water Storage Tank
Station Blackout Event
Spent Fuel Pool
SR
Safety Related
Systems, Structures, and Components
Service Water System
Service Water Intake Structure