ML18152A503
| ML18152A503 | |
| Person / Time | |
|---|---|
| Site: | Surry  |
| Issue date: | 04/07/1993 |
| From: | Blake J, Crowley B NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | |
| Shared Package | |
| ML18152A504 | List: |
| References | |
| 50-280-93-02, 50-280-93-2, 50-281-93-02, 50-281-93-2, NUDOCS 9304210152 | |
| Download: ML18152A503 (16) | |
See also: IR 05000280/1993002
Text
UNITED STATES
NUCLEAR REGULATORY COMMISSION
REGION 1.1
101 MARIETTA STREET, N.W.
ATLANTA, GEORGIA 30323
APR - 9 lS93.
Report Nos.:
50-280/93-02 and 50-281/93-02
Licensee:
Virginia Electric and Power Company
Glen Allen, VA 23060
Docket Nos.:
50-280 and 50-281
Facility Name:
Surry 1 and 2
License Nos.:
Inspection
22 - 26, 1993
Approved
Scope
Blake, Chief
erials and Processes Section
Engineering Branch
Division of Reactor Safety
SUMMARY
Date Signed
~hA3
Date Signed
This routine, unannounced inspection was conducted in the area of Inservice
Inspection (ISi).
The inspettion included a review of the Unit 2 ISi program
and plan for the current outage, as well as overall programmatic controls;
review of nondestructive examination (NOE) procedures; observation of in-_
process NDE examinations; review of NDE p~rsonnel qualifications; and review
of NOE equipment calibration and material certification documentation.
In*
addition, implementation of the licensee's Flow Assisted Corrosion (FAC)
(Erosion/Corrosion) program was inspected. Also, followup inspections were
performed on previously identified inspection findings.
Results
This inspection indicated that, in general, a good ISi program was in place
with good implementation.
Examination procedures meeting Code requirements
were being used and inspections were being performed by qualified personnel.
The procedures, examinationtechniques used to conduct the examinations, and
documentation of examination results were good .
9304210152 930409
ADOCK 05000290
G
2
In the area of Flow Assisted Corrosion (FAC), the licensee has a strong,
program implemented.
The program has strong corporate and site support with
dedicated resources and is well documented in corporate standards and site
procedures.
Degraded piping is being routinely identified and replaced with
upgraded materials.
In the areas inspected, no violations or deviations were identified .
l.
Persons Contacted
Licensee Employees
-
REPORT DETAILS
W. Benthall, Supervisor, Licensing
- R. Blount, Superintendent, Engineering
- D. Grady, Supervisor, NDE
T. Huber, Supervisor, ISI/NDE and Engineering Programs
L. Humphrey, Senior Inspector
- M. Kansler, Station Manager
D. Phelps, Engineer
- J. Price, Assistant Station Manager,
- R. Saunders, Assistant Vice President, Nuclear Operations
- E. Smtth, Manager, Quality Assurance
D. Woodyard, Senior Inspector
Contractor Personnel
P. McFadden, NDE Supervisor, Virginia Corporation of Richmond (VCR)
J. Sombo, Steam Generator Eddy Current Coordinator,Westinghouse
(li) - Nuclear Services Division (NSD)
Other licensee employees contacted ~uring this inspection included
craftsmen, engineers, quality control personnel, security force members,
technicians, and administrative personnel.
NRC Resident Inspectors*
- J. York, Resident Inspector
S. Tingen, Resident Inspector
- Attended exit interview
- Participated in exit interview via telephone
Acronyms and Initialisms used throughout this report are listed in the
last paragraph.
2.
Inservice Inspection (ISI) (Unit 2)
The tns~ector reviewed documents and records, and observed activities,
as indicated below, to determine whether ISI was being conducted in
accordance with applicable procedures, regulatory requirements, and
licensee commitments.
The applicable Code for ISI (Units~ and 2) is
the American Society of Mechanical Engineers Boiler and Pressure Vessel
(ASME B&PV). Code,Section XI, 1980 Edition, Winter 1980 Addenda .
For Unit 1, the second 10-Year interval started in December 22, 1982,
and ends October 14, 1993.
For Unit 2, the second 10-Year interval
started May 1, 1983, and ends May 10, 1994.
By letters dated July 11,
2
- and October 1, 1991, VEPCO extended the second interval end dates for
both Units based on extended plant outages.
The new end dates are
July 15, 1994, for Unit 1 and May 9, 1995, for Vnit 2.
The current Unit
2 outage is the first outage of the third period.
Revision O for the Unit 1 second interval program plan and relief
requests was submitted to the NRC by VEPCO letter dated September 21,
1982.
Revision 1 to the Unit 1 plan and revision O of the Unit 2 plan
were submitted on
December 27, 1982. * NRC Safety Evaluation Reports
(SERs) dated January 24, 1984, (Unit 1), and January 24, 1986, (Unit 2),
were issued. Additional submittals, including revision 2 to the Unit l
plan were dated November 26, 1985, and April 17, April 24, May 22,
June 23, and September 30, 1986.
Revision 3 for Unit 1 and Revision 1
for Unit 2 plans were submitted on April 16, 1987.
Additional
-information was provided by VEPCO letters dated June 22, and
September 30, 1988, and February 15, and May 15, 1989.
The NRC SER
covering both units was issued March 14, 1991. * The program plans
. included 14 NDE relief requests. All 14 relief requests were granted,
granted with conditions, or determined to not need approv~l.
Revision 4
to the Unit 1 program and revision 2 to the Unit 2 program were issued
on March 3, 1993, to make administrative changes, incorporate SER
changes, and add additional relief requests (SR-015, 016, 017, 018 and
- 019).
The licensee's corporate and site ISi organizations are responsible for
the nondestructive examination (NDE) program.
~ontractors furnish NOE
.
examiners and a NDE supervisor with ovefall coordination and supervision
provided by the VEPCO site ISi organization.
For the current outage,
Virginia Corporation of Richmond (VCR) is performing the majority of NDE
examinations.
Westinghouse is performing Eddy Current {ET) examinations
of steam generator tubing.
a.
ISi Program Review (73051) (Unit 2)
The inspector reviewed the following documents related to the ISi
program to determine whether relief requests had been approved by
NRR, the services of an Authorized Nuclear Inservice Inspector
(ANII) had*been procured and was involved. in ISi activities, the
pl an had been approved by the licensee. and to assure that
procedures and plans had been established (written, reviewed,
approved and issued) to control and accomplish the following
applicable activities: program organization including
identification of commitments and regulatory requirements,
preparing plans and schedules, and qualification, training,
responsibilities, and duties of personnel responsible for ISi; *
repair and replacement program requirements; personnel
qualification requirements; and guidance for identifying and
processing relief requests.
Surry Power Station Unit 2 Inservice Inspection Program -
Interval 2 - May 01, 1983 - May 10, 1994
3
Surry Power Station Unit 2 Inservice Inspection Plan For
The Second Inspection Interval Volume 2 - Revision 1 -
February 1991 For Components and Component Supports - May 1,
1983 - May 10, 1994
Inservice Inspection Manual, Revision 36
Augmented Inspection Manual, Revision 6
Surry Unit 2, Interval 2, Period 3, Items Remaining to be
Examined, Revision 3
Work Order (WO) 359816, ISI NOE Inspections (Outage Plan)
SUADM-M-23, dated 6/8/89, Disposition of ASME Section XI
Inspection and Testing Discrepancies
SUADM-M-25,- Revision 0, ASME Documentation Control and
Reporting Requirements
SUADM-M-26, Revision 1, ASME Section XI Inspection and
Examination Control
VPAP-307, Revision 2, Repair and Replacement of ASME Section
XI Components
VPAP-0502, Revision 3, Procedure Process Control
SSES-1.05, Revision 3, Controlling Procedure For Engineering
Assignment Schedule
SSES-6.01, Revision 1, Controlling Procedure For ISi
Engineering
SSES-6.02A, Revision 1, Controlling Procedure For Repair and
Replacement Follower
SSES-6.02B, Revision 1, Controlling Procedure For Logging
ASME XI Reports
SSES-6.06, Revision 0, Controlling Procedure For The Review
of ISi Related Issues/Checklists Prior to Unit Startup
Following A Refueling Outage
SSES-7.01, Revision 1, Controlling Procedure For Surry NOE
Services
SSES-7.02, Revision 0, Controlling Procedure For the Review
& Routing of Completed NOE Reports
NDE-3.1, Revision 6, Preparation, Issue and Control of
Nondestructive Examination Procedures
4
NOE-4.1, Revision 11, Virginia Power Written Practice For
Certification of Nondestructive Examination Personnel
NOE-6.2, Revision 2, Review of Contractor Nondestructive
Examination Interpretation By Virginia Power Personnel
NOE-6.3, Revision 1, Storage and Control of NOE Calibrated
Equipment, Calibration Standards & Consumable NOE Materials
NOE-6.4, Revision 0, Selection of Calibration Blocks For PSI
and ISI Ultrasonic Examination
NOE-7.2, Revision 5, General Requirements For ISi
Many of the documents and procedures listed above and in paragraph
b. below were reviewed during the inspection documented in NRC
Report 50-280, 281/92-09.
Only changes since that inspection were
reviewed.
As noted in report 92-09, procedures did not clearly
iterate the controls required for the inspection plans provided by
corporate.
The above review revealed that the plans are now
formally issued and controlled.
b.
Review of NOE Procedures (73052) (Units 1 and 2)
The inspector reviewed the procedures listed below to determine
whether these procedures were consistent with regulatory
requirements and licensee commitments.
The procedures were
reviewed in the areas of procedure approval, requirements for
qualification of NOE personnel, compilation of required records,
and division of responsibility between the licensee and contractor
personnel.
In addition, the procedures were reviewed for
technical adequacy and conformance with ASME, Sections V and XI,
and other licensee commitments/requirements.
NOE-PT-201, Revision 2, Liquid Penetrant Examination
NDE-MT-202, Revision 2, Magnetic Particle Examination of
Bolting
NDE-UT-201, Revision 3, Manual Ultrasonic Examination Of
Piping Welds
NOE-UT-204, Revision 2~ Inservice Ultrasonic Examination of
Cla~s 1 Bolting.
SUAOM-M-20, Revision 2, ASME Section XI Visual Examination
Program (VT-1, 2, and 3)
MRS 2.4.2 VEP-1, Revision 5, Eddy Current Inspection of
Preservice and Inservice Heat Exchanger Tubing at Surry
Power Plant
I
,
5
SGPMS-002, Revision 2, Plant Specific Guidelines Eddy
Current Data Analysis, Training, and Testing
DAT-GYP-001, Revision 6, Data Analysis
c.
Observation of Work and Work Activities {73753) {Unit 2)
The inspector observed work activities, reviewe~ NDE personnel
qualification records, and reviewed certification records of NDE
equipment/materials, as detailed below.
During the examinations,
the inspector verified: availability of and compliance with
approved NDE procedures, use of knowledgeable NDE personnel, and
use of NDE personnel qualified to the proper level.
{1)
Liquid Penetrant Examination {PT)
{2)
The inspector observed the in-process PT examinations as
indicated below.
The observations were compared with the
inspection attributes of the applicable procedure and the
ASME B&PV Code to verify the performance of acceptable
examinations.
Examinations Observed
Drawing
Item
Welds/Component
11548-WMKS-0127G2
MC-112
w.:1-WF
11548-WMKS-0127G2*
MC-113
W-1-VF
11548-WMKS-0127C2
MC-079
W-4-KS
Magnetic Particle Examination {MT)
The inspector observed in-process MT inspection of the
following weld and compared the inspection with the
applicable procedure and the ASME code to verify performance
of an acceptable examination:
Drawing 11548-WMKS-RC-R-1.2 - Weld W-1-01 {Item MC-252) {RV
.Head to Flange Weld, 358" to 537")
- *
(3)
Ultrasonic Examination (UT)*
The inspector observed calibration activities and portions
of the in-process UT examination for the weld indicated
below:
The weld was inspected using 0°, 45°, and 60°
transducers. The inspector compared the examination with
the applicable procedures and the ASME B&PV Code to verify
that an acceptable examination.was performed.
Drawing 11548-WMKS-RC-R-1.2 - Weld W-1-01 {Item MC-252) {RV
6
(4)
Visual Examinations (VT)
The inspector observed the in-process VT examination of the
pipe supports noted below.
The observations were compared
with the applicable procedure and the ASME B&PV Code to
verify performance of acceptable inspections.
Examinations Observed
Drawing
11548-WMKS-OlOlGl
11548-WMKS-OlOlGl
(5)
Eddy Current Examination (ET)
HG-303
HG-304
Welds/Component
HOOlA
HOOlB
For the current outage, only tubes in steam generator (S/G)
B were being examined.
All tubes in the S/G were being
inspected full length using a 720BPRMS BOBBIN coil probe.
BOBBIN coil data was being collected at 400, 200, 100, and
10 KHz.
In addition, Rotating Pancake Coil (RPC)
inspections will be performed in the low flow area for 301
tubes and for evaluating BOBBIN coil inspection results as
needed.
As of March 24, 1993, the BOBBIN coil inspection
had been completed for approximately 40% of the tubes.
Seventeen (17) indications
(5 hot leg and 12 cold leg) of
tube wall degradation of 20-29% of wall thickness had been
identified. Three (3) indications (2 hot leg and 1 cold
leg) of tube wall degradation of 30-39% of wall thickness
had been identified.
No indication greater than 40% wall
degradation had been identified.
The inspector observed data acquisition for the following
tubes:
ROW
COLUMN
ROW
COLUMN
11
64
3
52
14
64
3
51
9
64
3
50
8
64
3
49
(6)
7
In addition, the analysis process was observed for the
following tubes:
ROW
COLUMN
ROW
COLUMN
19
13
11
46
18
13
12
46
17
13
13
46
16
13
14
46
15
13
9
13
8
13
Personnel Qualifications
The inspector reviewed personnel qualification documentation
as indicated below for examiners who performed the
examinations detailed in paragraphs (1), (2), (3), (4), and
(5) above.
These personnel qualifications were reviewed in
the following areas: employer's name; person certified;
activity qualified to perform; current period of
certification; signature of employer's designated
representative; basis used for certification; and, annual
visual acuity, color vision examination, and periodic
recertification.
Method
Examiner Records Reviewed
Level
Employer
I I
VCR
I I
VCR
I I
VCR
I I
VCR
I I
.kl
!{Trainee) .W
I II
.kl
I I
I I
II
Number
6
6
6
1
2
1
2
2
2
2
In addition, qualification records for one VEPCO level III
(PT, MT, VT, ET, RT, and UT) examiner was reviewed.
(7)
Equipment Certification Records
Equipment certification records as listed below, for
equipment used in the inspections detailed in paragraphs
(1), (2), (3) and (5) above, were reviewed to ensure
compliance with all applicable requirements.
RESULTS
Equipment Type
Penetrant Cleaner
Penetrant
Penetrant
Penetrant Developer*
UT Couplant
UT Transducer
UT Transducer
UT Transducer
UT Instrument
MT Particles
ET MIZ-18A RDAU
ET MIZ-18A RDAU
ET Cal Standard
ET Cal Standard
ET Cal Standard
ET Cal Standard
8
Equipment
Identification
Batch 36A4
Batch 130A47
Batch 919Y47
Batch 216K6
Batch 092031
Serial M02103
Serial J29303
Serial Ll9134
Serial 9286704
Batch 9ID016
Serial W03101
Serial W05052
MGT-012-92
MGT-016-90
AD-021-89
AB-010-91
In the areas inspected, no violations, or deviations were identified.
In ~eneral, a good lSI program was in place with good implementation.
Examination procedures meeting code requirements were being used and
inspections were being performed in a conscientious manner by qualified
personnel.
3.
Flow Assisted Corrosion (FAC) (Erosion/Corrosion) Program (49001)
The inspector performed a review of the licensee's FAC piping inspection
program.
The program is detailed in the following documents:
General-Nuclear Standard STD-GN-0033, Revision 3, Secondary Piping
and Component Inspection Program
VPAP-0807, Revision O, Secondary Piping and Component Inspection
Program.
Mechanical Engineering Implementing Procedure ME-022, Revision 3,
Engineering Evaluation Procedure for UT Inspected Components
Mechanical Engineering Implementing Procedure ME-023, *Revision 0,
Change Notice 1, CHEC-NDE Software Control
SSES-2.12, Revision 0, Controlling Procedure for Design
Engineering Evaluation of UT Inspected Components
NDE-UT-104, Revision 1, Ultrasonic Thickness Examination
a.
9
The following describes various aspects of the licensee's program:
A long term FAC program has been implemented at Surry.
The
licensee's method of predicting which systems are most
susceptible to FAC is EPRI CHECMATE Codes.
The licensee's FAC program includes the systems that have
been predicted to be susceptible to FAC.
The model ranks
each system's components according to their FAC
susceptibility.
The licensee's primary basis for selecting components for UT
inspection at the next outage is the results from the
predictive analysis.
Engineering judgement, results of
predictive analysis, industry experience and results from
previous UT inspections are used to select supplemental
inspection locations.
The following systems are included in the licens~e's FAC
program:
Condensate
Feedwater Heater Drains
Moisture Separator Drafns
_
Moisture Separator Reheater Drains
,
Steam Generator- Slowdown
Main Steam Drains
Auxiliary Steam
Auxiliary Feedwater Pump Steam Supply
Crossover and Crossunder Piping
The following components are included in the E/C program:
Control Valves/Check Valves
Tees and Branches
Expanders and Reducers
Flow Nozzles and Orifices
Exit Nozzles
Elbows and Reducing Elbows
Strai~ht Pipe Sections
Heater Drain Tanks
Reheater Drain Tanks
Pump Casings (heater drain and condensate pumps)
Main condenser (internal sparger, expansion joints)
UT thickness measurement procedures are approved in
accordance with the licensee QA program.
Procedures define
methods for: performing UT measurements, grid spacing
criteria, ensuring that followup inspections are taken at
I
I
10
the same locations as the previous inspections, ensuring the
use of certified inspection personnel, analYzing the results
of UT measurements, and establishing acceptance criteria.
Minimum wall thickness (tmin) requirements for safety-
related and non-safety related piping are based on code
allowable minimum wall thickness.
The licensee's method of analyzing UT data includes:
calculating the wear rate (wr) based on point to point
measurements, .band method, area method, and average method;
predicting the thickness (t) at the next refueling outage
based on tpredicted = tmeasured - wr X current operating eye le
time; determination of current acceptance based on tmeasured >
tminimum and tpredicted > tminimum; and calculation of remaining
life based on remaining life= (tmeasured - tminimum) divided by
the wr.
Repair and replacement of safety-related and balance of
plant eroded components is covered by the licensee's R&R
program meeting ASME Section XI.
Welding and NDE of repairs
and replacements are accomplished by qualified personnel and
suitable procedures for safety-related and balance of plant
piping.
Corporate
program.
program.
Committee
Engineering has responsibility for the FAC
The program is covered by the licensee's QA
The licensee's Management Safety and Review
(MSRC) reviews the FAC program.
b.
In addition to review of the program, as detailed in the documents
listed above, and discussion of the program with the responsible
engineer,- the inspector reviewed the fo 11 owing outage documents:
Seconda~y Piping and Component Inspection Program dated
October 2, 1992 and updated on March 3, 1993
Design Change Number 92-67-2, MI Secondary Piping
Replacements Surry Unit 2, including Field Changes 1
through 5
The Inspection Program (Outage Plan) included 80 piping components
from l" to 24" in diameter.
In addition the plan included a
number of other* components such as, mairi condenser, crossunder
piping, valves, steam generator "B" feedring, etc. The Design
Change was for replacement of a number of piping runs and
components in the Feedwater, Condensate, Steam Drains, and
Extraction Steam systems because of FAC.~ The piping was being
upgraded to Chromium - Molybdenum (CR-MO) steel.
11
The inspector also observed the following field activities to
verify inspection grid layout and UT wall thickness measurements
were being accomplished in accordance witb procedures:
Results
UT inspection of Component 2-CN-PPS-110 on drawing 11548-
WFPD-12 *
UT inspection and grid layout of components 2-SD-PSF2-284
and 2-SD-PPS-605 on drawing 11548-WFPD-104
Grid layout of components 2-SD-PSF2-299 and 2-SD-PPS-623 on
drawing 11548-WFPD-106
Personnel certification records were reviewed for NOE
examiners performing the above activities.*
The licensee has a very strong, pro-active FAC program with strong
corporate and site support and dedicated resources.
EPRI developed
computerized programs CHECMATE and CHEC-NDE are used for in the
selection of susceptible components and evaluation of inspection
results. Over SOOO_components per unit are included in the program.
FAC degraded piping components are being routinely identifi~d and
replaced with upgraded CR-MO steel.
In the areas inspected, np violations or deviations were identified.
4.
Steam Generator (S/G) Feedwater Nozzle Inspections
See NRC Report 50-280, 281/92-09 for documentation of a previous
inspection of this area.
A number of PWR plants have identified thermal fatigue cracking of
piping at the S/G Feedwater nozzle.
The tracking was attributed to
thermally induced fatigue caused by introducing relatively cold
feedwater into the main feedwater pipe upstream of the S/G.
This
cracking problem was identified in 1979 and NRC Bulletin 79-13 was
issued to require inspection and replacement of defective feedwater
piping components.
B~~ed on the currently identified cracking, the pipi~g components at
North Anna steam generator nozzles were inspected and cracks were found
in loops "A" and "C".
The following actions were performed by the
licensee:
Other utilities were surveyed to determine industry experience.
A history" of inspections and pipe replacement activities, since
issue of NRC Bulletin 79-13, for the affected piping was compiled
for North Anna and Surry.
12
A metallurgical analysis was performed on the cracks found at
North Anna.
Based on the track depth at North Anna, a crack growth rate was
established.
Based on a projected crack growth rate and the previous
replacements of the affected piping at Surry, a scheduled
augmented inspection was developed for Surry and North Anna.
Licensee Report, Thermal Fatigue Cracking of Feedwater Piping North Anna
Power Station- Unit 1, dated February 12, 1993, documents the above
actions.
The inspector reviewed the report and found it to be a very
thorough appraisal of the problem with realistic future inspection
schedules recommended.
In the areas inspected, no violations or deviations were identified.
5.
Safety Related Pipe Welding (55050)
The applicable code for safety-related pipe welding observed is USA
Power Piping Code 831.1.0 - 1967.
The inspector observed in-process
welding and reviewed in-process records as indicated below to determine
whether these activities were being performed in accordance with
applicable codes, standards and regulatory requirements.
The inspector observed fitup, in-process welding, and the final weld
surface for welds 1, 2, 3, 4, 5, 9, 11, 13, 14, and 16 on drawing
DCP-12-E237.
In add.ition, final weld surfaces were observed for non-
safety-related welds 3, 4, 5, 7, 8, and 10 on drawing DCP-67-E210.
For
these welds, the inspector reviewed in-process weld records and examined
weld appearance, weld material control, use of correct weld material,
use of correct welding procedure, and welder qualification and general
knowledge and ability.
In the areas inspected, no violations or deviations were identified.
6.
Licensee Action on Previous Inspection Findings
(Closed) Violation 280/92-09-01, Failure to Follow Procedures and
Instructions for NDE of Piping
This violation involved failure to perform ISI (VT and PT) inspections
of a Recirculation Spray Ring in accordance with Technical Specification
and procedure requirements.
Only 9" bands around the header, in lieu of
100% of the surface, were VT inspected.
In addition, PT testing was
being performed without removing blotches of paint and other foreign
material .
13
The licensee's letter of response, dated June 8, 1992, was reviewed and
found to be acceptable.
The inspector discussed the corrective-actions
with responsible licensee personnel and reviewed documentation of the
following corrective actions:
All examinations on the ring header were re-performed.
The NOE examiner who performed the PT inspections without removal
of foreign materials was re-trained and re-tested.
All. contract NOE personnel were instructed on the importance of
following procedures and were required to re-review the
requirements of the surface examination NOE procedures.
All inspections performed by the individual were reviewed and a
random sample of his inspections were re-performed by licensee
qualifted NOE examiners ~ith no problems being identified.
Records for the Spray Ring VT inspection performed during the last
outage were reviewed and no problems were identified.
In
addition, a licensee NDE examiner recalled observing part of that
inspection and indicated the inspections were performed correctly.
Based on review of the above corrective actions, this item is closed.
7 .. Exit Interview
The inspection scope and results were summarized on March 26, 1993, with
those persons indicated* in paragraph 1.
The inspector described the
areas inspected and discussed in detail the inspection results.
Proprietary information is not contained in this report.
Dissenting
comments were not received from the licensee.
8.
Acronyms and Initialisms
ANII
CR-MO
-
MS
MSRC
NRC
Authorized Nuclear Inservice Inspector
American Society of Mechanical Engineers
Boiler and Pressure Vessel
Condensate System
Electric Power Research Institute
Flow Assisted Corrosion
Inservice Inspection
Main Steam System
Management Safety and Review Committee
Magnetic Particle Testing
Nuclear Regulatory Commission
Nuclear Reactor Regulation
Preservice Inspection
Liquid Penetrant Testing
.,
RC
. RDAU
RII
RPC
_R&R
RV
S/G
SUADM
-
VCR
-
VPAP
-
tl
Pressurized Water Reactor
Quality Assurance
Quality Control
Remote Data Acquisition Unit
Region 2
Rotating Pancake Coil
Repair and Replacement
Reactor Vessel
Steam Drains
Safety Evaluation Report
Surry Site Engineering Services
Surry Administrative Procedure
Ultrasonic Testing
Visual Testing
Virginia Corporation of Richmond
Virginia Electric and Power Company-
Virginia Power Station Administrative Procedure
Work Order
Wear Rate